Baker Hughes Corporation

Other

Nabors Drilling Technologies Usa, Inc.

Shell Oil Comapny

Canrig Drilling Technology Ltd.

Weatherford Canada Partnership

Navigate Energy Services, LLC

Rotary Drilling Technology, LLC

Harvey, Peter R.

Peter R Harvey

Michael H Johnson

Yang Xu

Tyler Clark

Mark Ellsworth Wassell

Matthew A White

Daniel E Burgess

James Minto

Pradeep Annaiyappa

Vadim Minosyan

Andrew R Harvey

Kirk Towns

Martin Sorrells

Harmeet Kaur

Stephen Krase

Michael J Woods

Stanley Lane Walker

Alexander Baues

George S Findlay

Denis P Biglin

James Babek

Grace Harvey

Steve J Krase

A method is described for determining a measure of geo-mechanical strength of subterranean rock at the cutting surface of a drill bit during drilling using a single measurement related to mechanical power at the drill bit. This measurement in combination with a measure of volumetric rate of rock failure defines an expression for mechanical specific energy (SMSE). SMSE is the mechanical power at the drill bit divided by volumetric rate of rock failure over any time interval. A method is described for predicting geo-mechanical and physical properties (lithology) of subterranean rock at the cutting surface of a drill bit during drilling operations using machine learning (data analytical) model(s). Said models are driven by a set of subterranean measurements related to the structural, physical response of subterranean rock mechanical failure in combination with the measure of SMSE. The geo-mechanical and physical properties of subterranean rock may include measures of rock geo-mechanical strength, unconfined compressive strength (UCS), porosity, density, natural gamma ray, and/or borehole natural fracture network. Said machine learning models are developed (or trained) using historical drilling data sets of subterranean sensors through correlation to an accepted or accurate measure of subterranean rock properties. Said predicted measures may be further processed along with other data from oilfield development operations to provide vital information for drilling performance, well bore placement and engineered completion design.

At-bit sensing of rock lithology

A method of subterranean drilling comprising monitoring at least one drilling criteria at the surface; communicating a marker signal to a bottom hole assembly of a drill string upon meeting a condition of the at least one drilling criteria; and repeating the marker signal at least two consecutive times the condition is met. In an embodiment, the marker signal can be repeated every time the condition is met. A system for subterranean drilling comprising a drill rig adapted to monitor at least one drilling criteria at the surface; a communication element adapted to communicate a marker signal to a bottom hole assembly of a drill string upon meeting a condition of the at least one drilling criteria, wherein the communication element is adapted to communicate the marker signal to the bottom hole assembly at least two consecutive times the condition is met.

Marker signal for subterranean drilling

An apparatus includes a sensor assembly disposable in a drill string proximate a drilling motor. The sensor assembly has a first pressure sensor in fluid communication with an upstream side of a rotor in the drilling motor, a second pressure transducer in fluid communication with a downstream side of the rotor and a rotational speed sensor coupled to the rotor. A processor is in signal communication with the first pressure transducer, the second pressure transducer and the rotational speed sensor.

Drilling motor having sensors for performance monitoring

A method includes coupling a strain gauge to a tubular member, and positioning the tubular member in the wellbore such that the tubular member is placed under bending stress by a curvature or deviation in the wellbore. The method also includes measuring bend on the tubular member with the strain gauge in at least one plane and determining one or more of the magnitude or orientation of the curvature of the wellbore based on an output of the strain gauge.

Method and apparatus for continuous wellbore curvature orientation and amplitude measurement using drill string bending

An improved gap sub assembly that can withstand the rigors of directional drilling, while still being cost effective and easy to deploy at the drill site. Embodiments can be assembled by sliding a mandrel into a housing without any threading or clocking, filling the gap between the housing and mandrel with an electrically isolating material, and curing the electrically isolating material to mechanically couple the housing and mandrel. In some embodiments, the interior surface of the housing and the outer surface of the mandrel comprise a plurality of complimentary axial sections having staggered diameters so that a constant dielectric gap is maintained. In some embodiments, the interior surface of the housing and the outer surface of the mandrel comprise non-overlapping right- and/or left-handed helical grooves that, when filled with a cured electrically insulating material, forms a complex 3D shear resistance mechanism optimized to resist torsion or twisting.

EM gap sub assembly

The invention comprises systems and devices for calculating and displaying real-time race information to a racer during a race. A portable race device may be worn by a racer. During the race, while within range of a race gate transmission, the race device receives gate crossing times for other race participants, and may calculate and display the current positions and times for a selected race group, and the pace needed for the racer to win, and also may display the projected finish positions and times for a selected race group, and the pace needed for the racer to win.

Portable race device for displaying real-time race information

An improved MWD system for drilling unconventional wells. Embodiments provide a particular combination of sensors in a specific arrangement in order to provide a system expressly designed for drilling unconventional wells. By minimizing modularity to reduce the need for redundant/duplicated components, including only sensors specifically needed for unconventional wells, and by separating long-life components such as sensors from components requiring more frequent maintenance or service such as batteries, the components can be more efficiently combined into a BHA sensor assembly having the shortest possible length.

MWD system for unconventional wells

New locking connector assemblies and telescoping extension/retraction assemblies are disclosed that operate on the natural spring rate constraints of radial protrusions or radially constrained rings as they interact with engaging members to provide the locking force and permit the connector and extension retraction assemblies to be engage and disengaged or extended and retracted.

Radial spring latch apparatus and methods for making and using same

An apparatus for telemetering a downhole parameter from a well. The apparatus comprises a housing having a bore. The apparatus further comprises an annular main valve with an enlarged end positioned within the bore, with the main valve having a center of axis. A restrictor is concentrically disposed within the bore, the restrictor configured to define an annular passage with the main valve. The apparatus also includes: a pressure device for supplying hydraulic pressure to the main valve; a control valve, operatively associated with the restrictor member, for controlling pressure to the main valve; and a solenoid control valve assembly for activating the control valve. In one preferred embodiment, the solenoid control valve assembly comprises a controller for emitting an electrical signal, a coil that receives the electrical signal and generates a magnetic field, a solenoid static pole receptive to the generated magnetic field, and a solenoid moving pole responsive to the magnetic field so that the solenoid moving pole moves in a direction towards the solenoid static pole. A method for communicating a downhole parameter is also disclosed.

Measurement while drilling tool and method

Geophysical measurement system employed during the drilling of a well borehole. The system employs a reference clock disposed within equipment at the surface of the earth and a borehole assembly which houses a downhole clock and at least one sensor. The borehole assembly is operationally connected to a drill string, which advances the borehole. At least one synchronization shuttle apparatus containing a shuttle clock is conveyed downhole to the borehole assembly to synchronize the borehole clock with the reference clock. Reference and borehole clock synchronization is maintained at one millisecond or less over a period of days. Outputs from the reference clock and borehole clock and sensor are combined to obtain a measure of a geophysical parameter of interest. Although the measurement system is particularly applicable to seismic-while-drilling measurements, it can be used in a wide variety of clock driven geophysical measurements.

Downhole clock synchronization apparatus and methods for use in a borehole drilling environment

A stabilizer especially adapted for use with an drill string having an eccentric drilling element, such as a bi-center bit. The stabilizer has a pair of circumferentially displaced blades that lie in a common circumferential plane and extend from a rotatable sleeve supported on the stabilizer body, as well as a stationary blade. The rotating blades are aligned with the stationary blade when in a first circumferential orientation and are disposed so that the mid-point between the rotating blades is located opposite the stationary blade, thereby providing full-gauge stabilization, when the rotating blades are in a second circumferential orientation. A magnetic systems senses the circumferential orientation of the rotating blades and transmits the information to the surface via mud pulse telemetry. A piston actuated by the drilling mud locks the rotating blades into the active and inactive positions. A brake shoe located on the distal end of each rotating blade provides contact with the walls of the bore hole and serves as a support pad for a formation sensor.

Stabilizer for use in a drill string

An apparatus is disclosed for thermal desorption of contaminants from contaminated material, the apparatus including: a plurality of first insulated boxes, each insulated box, defining a volume effective for holding contaminated material, and each insulated box defining an opening at the top of the insulated box; at least one top effective to fit on the opening at the top of the insulated box and each top defining a pattern of heater orifices; a plurality of heaters, the heaters being insertable into the volume for holding contaminated material, through the heater orifices defined by the top; and a vapor extraction system effective to-remove vapors from within the volume for holding contaminated material.

Apparatus for exsitu thermal remediation

A modular measurement while drilling sensor assembly is presented. A typical cross-over assembly for mating with a measurement while drilling (MWD) tool is connected to a typical positive displacement mud motor (e.g., a Moineau motor). A modular sensor assembly comprises two portions, an upper drive shaft portion which includes a flexible shaft connected to the motor and a lower sensor portion and supported by a radial bearing. The lower end of the flexible shaft is connected to a hollowed shaft which extends beyond the lower end of the upper drive shaft portion and which is supported by a radial bearing. The lower sensor portion has a central channel extending longitudinally therethrough, with the lower portion of the hollowed shaft extending through this channel. The sensor portion may comprise any type of MWD sensor, however the present invention is preferably used with sensors (e.g., formation evaluation sensors) that benefit from obtaining measurements close to the bit. The lower end of the hollowed shaft is supported with a radial bearing and connected to a flexible shaft of an adjustable kick off assembly connected to the sensor portion. The adjustable kick off assembly allows the introduction of a kick off angle, generally between 0.degree. and 3.degree., in the assembly. The adjustable kick off assembly is connected to a typical bearing pack assembly. The lower end of the bearing pack assembly is typically connected to a drive shaft, a bit box and then the bit.

Modular measurement while drilling sensor assembly

An eccentric fluid displacement sleeve is disclosed for use with a measurement-while-drilling instrument, to convert the instrument for use in different size boreholes. The sleeve is made eccentric by either increasing or decreasing the thicknesses of positioning blades on the periphery of the sleeve, while maintaining the thickness of the fluid displacement blade aligned with the detectors.

Growing community of inventors

Houston, TX, United States of America

Peter R Harvey