Halliburton Energy Services, Inc.

Ankit Purohit

Bhargav Gajji

Rahul Ramchandra Gaikwad

Ratish Kadam

Anand Bhagwat Kedare

Ratish Suhas Kadam

Sandip Satish Sonar

Abhay Bodake

Sanjay Sawant

Ganesh Shriniwas Pangu

Steven Park

Mukesh Bhaskar Kshirsagar

Geir Gjelstad

Keshav Parashuram Pujeri

A downhole packer ring apparatus for use in a wellbore, comprising a first ring member and a second ring member. The first ring member has an end with a plurality of separated end tabs. The first ring member has an opening with an inner diameter sized to encircle a basepipe of the wellbore. The second ring member has a tapered interior surface and an end with an opening having an inner diameter sized to encircle the basepipe and connect to the first ring member such that the end tabs of the first ring member are locatable in the end opening of the second ring member and pressable against the tapered interior surface such that flexed portions of the end tabs engage with the basepipe.

Downhole packer ring apparatus and method of assembling thereof

A downhole tool having a mechanically adjustable bend angle from the surface and method for actuation of the tool. The tool includes a knuckled joint between upper and lower housing assemblies and tapered setting ring upon which the lower housing assembly bears. As the setting ring is rotated with respect to the upper housing assembly, the lower assembly is tilted. A spline sub for connection to a drill string is included, which, upon a certain weigh on bit, axially moves within the tool housing to engage the tapered setting ring and force shoes radially outward to engage the formation and hold the tool stationary. The drill string is then rotated to rotate the setting ring, and thereby alter the tool bend angle. Toggles hold the setting ring fixed to the upper housing to maintain a given bend angle during drilling operations.

Surface actuated downhole adjustable mud motor

The present disclosure describes a dynamic geo-stationary actuation technique that may be incorporated into a rotary steerable system. An example method described herein may include receiving a first angular orientation of a rotating housingdisposed in a borehole. The first angular orientation may be received from a sensor assemblycoupled to the housing, and the housingmay be coupled to a drill bit. A desired drilling direction for the drill bitmay also be received. A first trigger signal to a first actuatorcoupled to the rotating housingmay be generated based, at least in part, on the first angular orientation and the desired drilling direction.

Dynamic geo-stationary actuation for a fully-rotating rotary steerable system

A fiber optic sensor is disposed in the elastomer of the stator of the mud motor in order to sense elastomer strain while drilling. The frequencies of micro stalls and stick slips are measured from the fiber optic sensor data by classification using thresholds or by converting time-domain measurements from the fiber optic sensor data to frequencies. For example, the frequencies are produced by accumulating a histogram over an interval of time or by computing a Discrete Fourier Transform over an interval of time. A plurality of fiber optic sensors also can sense angular position of the rotor of the mud motor for correlation of the micro stalls and stick slips with the angular position. The measurements of the micro stalls and stick slips are used to select remedial action such as changes in drilling parameters.

Measuring micro stalls and stick slips in mud motors using fiber optic sensors

An assembly for inclusion between a drill bit and a drill string, the assembly having an overrunning clutch mechanism that disengages the drill bit from the drill string during the 'slip' portion of a stick-slip cycle to allow the drill bit to freely rotate faster than the drill string. The assembly further includes a rotational vibration dampener operatively connected between the overrunning clutch and the drill bit. The vibration dampener may include a fluid chamber with viscous fluid or restrictions to fluid flow to effect dampening. During normal operation, the one-way overrunning clutch remains engaged to transfer torque between the drill string and bit, while the torsional damper is in its maximum displaced position to transfer the load. During slip, the drill bit is disengaged until its speed is lower than the drill string speed. Torsional vibration dampener dampens sudden impulse force of the overrunning clutch re-engaging.

In-line tortional vibration mitigation mechanism for oil well drilling assembly

A bottom hole assembly for a casing-while-drilling operation utilizes a tethered float valve to retrieve the bottom hole assembly after the casing string has been positioned at a desired wellbore depth.

Bottom hole assembly retrieval for casing-while-drilling operations using a tethered float valve

An example downhole motor may include a first housing and a second housing coupled to the first housing at a movable joint. A turbine may be within the first housing in selective fluid communication with a bore of the first housing. A biasing mechanism may be coupled to the movable joint and the turbine. The biasing mechanism may alter an angle between a first longitudinal axis of the first housing and a second longitudinal axis of the second housing by altering an orientation of the movable joint.

Downhole mud motor with adjustable bend angle

A drilling optimization collar for use proximate a drilling tool within a wellbore includes a fiber optic sensor filament that is sized and configured to fit within a groove formed within the drilling optimization collar. The drilling optimization collar may be a pipe segment that is sized and configured to be installed in a drill string proximate the drilling tool, and may have a plurality of sensor elements. All or a portion of the sensor elements may be formed by discrete segments of the sensor filament, and as such, the sensor filament includes sensor elements that are configured to sense a condition of the wellbore and a load on the drilling optimization collar.

Downhole drilling optimization collar with fiber optics

Systems and methods are disclosed for obtaining distance related wellbore parameters using pulse-echo measurements. For example, the depth of a wellbore may be computed and/or the length of a tubular string positioned in a wellbore may be determined. In an embodiment, a pulsar is deployed into a wellbore along a length of tubular. Once deployed, a fluid pulse is sent form a surface pulse generator and the transmission time is recorded. The downhole pulsar receives the fluid pulse and, in response, returns a second fluid pulse back to the surface. Surface processing circuitry receives the second fluid pulse and records the reception time. The processing circuitry then process the data to determine the total time for travel, thereby determining the length of the downhole pipe or other tubing.

Wellbore tubular length determination using pulse-echo measurements

The subject matter of this specification can be embodied in, among other things, a locking clutch that includes a collection of movable locking blocks slidably coupled to the rotatable output shaft. The movable locking blocks slide radially inwardly and outwardly with respect to a central longitudinal axis of the rotatable output shaft, and are spaced apart circumferentially about the rotatable output shaft, with each movable locking block having a first contacting face and a second contacting face. A collection of fixed locking blocks are coupled to the rotatable housing, and are positioned radially around the output shaft and spaced apart circumferentially about the interior of the rotatable housing a distance sufficient to receive one of the movable locking blocks when it moves inwardly toward the central axis of the rotatable output shaft, each said fixed locking block having a first contacting face and a second contacting face.

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Barnagar, India

Ankit Purohit