Smith International, Inc.

Schlumberger Technology Corporation

Yuelin Shen

Youhe Zhang

Madapusi K Keshavan

Yuri Y Burhan

Wei Chen

Sujian Huang

Zhou Yong

Jiaqing Yu

Guodong Zhan

Peter Thomas Cariveau

Anthony Griffo

Zhengxin Zhang

Michael Janssen

Gregory Thomas Lockwood

Michael George Azar

J Daniel Belnap

Feng Yu

Yingwei Yu

Jibin Shi

Velizar Vesselinov

Richard John Meehan

Georgiy Voronin

Minh Trang Chau

Yani Dong

Scott D McDonough

Bala Durairajan

Zhenyu Chen

Riadh Boualleg

Gang Xu

Richard John Harmer

Qiuhua Liu

Steffen S Kristiansen

Rongbing Chen

Zan Svendsen

Geng Yun

David R Hall

Scott Steven Dahlgren

Jonathan D Marshall

Ronald K Eyre

Geoffrey Charles Downton

Michael Allen Siracki

Scott Richard Woolston

Xiaoge Gan

Lucian K Johnston

Huimin Song

Kjell Haugvaldstad

John Daniel Belnap

Xian Yao

Sylvain Chambon

Oney Erge

Sudarsanam Chellappa

Cheolkyun Jeong

Christopher Bogath

Mauro Caresta

Balasubramanian Durairajan

Cesar Pena

Jonan Fulenchek

Huseyin Murat Panayirci

Paul T Higgins

Yaou Wang

Fei Li

Clint William Philbrick

John J Pierce

John (Youhe) Zhang

Xiayang Sheng

John Youhe Zhang

Daniel J Belnap

Guishui Zheng

Mahavir Nagaraj

Charles H S Douglas, Iii

Harry Pratt

Mike Azar

Maria Neves Carrasquilla

Eric Wilshusen

Joshua J Hanson

Maria Lucia Cazares Gomez

Gregory Michael Skoff

My Lien Ta

Gregg Alexander

Ted Tessitore

Chanhui Bin

Youhe (John) Zhang

Hong Deng

A drill bit includes a bit insert. A bit body of the bit includes an insert cavity. The bit insert is inserted into the insert cavity. The bit insert is secured to the insert cavity, such as by braze or with a connection mechanism. The bit insert may be replaceable, thereby allowing a drilling operator to adjust the configuration of the bit based on which bit insert is used.

Bit insert for a drill bit

A torsional damping system includes a housing having an interior space. An inertia ring is located in the interior space, and a torsion fluid is located between the inertia ring and the housing. The inertia ring is rotatably installed relative to the housing. As the housing oscillates, the inertia ring damps at least a portion of the oscillation. The torsional damping system may be included in a downhole tool or bottomhole assembly, and used to damp oscillations along a drill string or along the bottomhole assembly, including between a downhole motor and a cutting tool.

Inertia damping systems and methods

A system and method that include receiving sensor data during drilling of a portion of a borehole in a geologic environment. The system and method also include selecting a drilling mode from a plurality of drilling modes based at least on a portion of the sensor data. The system and method additionally include simulating drilling of the borehole using the selected drilling mode and generating a state of the borehole in the geologic environment based on the simulated drilling of the borehole. The system and method further include generating a reward using the state of the borehole and a planned borehole trajectory and using the reward through deep reinforcement learning to maximize future rewards for drilling actions.

Drilling control

A method of detecting wear of a downhole tool implemented in a subject wellbore includes receiving offset wellbore data for one or more offset wellbores and, based on the offset wellbore data, determining an expected downhole tool index for the downhole tool at one or more measurement depths including an active measurement depth of the subject wellbore. The method further includes receiving subject wellbore data and, based on the subject wellbore data, determining a subject downhole tool index in real time for the downhole tool at the active measurement depth. The method further includes determining the wear of the downhole tool based on comparing the subject downhole tool index to the expected downhole tool index at the active measurement depth in real time.

Systems and methods for determining wear of downhole tools

A method for drilling a well includes generating a plurality of proposed drilling actions using a plurality of working agents based on a working environment, simulating drilling responses to the proposed drilling actions using a plurality of validation agents in a validation environment that initially represents the working environment, determining rewards for the proposed drilling actions based on the simulating, using the validation agents, selecting one of the proposed drilling actions, and causing a drilling rig to execute the selected one of the proposed actions.

Multi-agent drilling decision system and method

A method can include receiving sensor data during drilling of a portion of a borehole in a geologic environment; determining a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issuing a control instruction for drilling an additional portion of the borehole using the determined drilling mode.

Methods, computing systems, and computer-readable media for interpreting drilling dynamics data are described herein. The method can include receiving drilling dynamics data simulated by a processor or collected by a sensor positioned in a drilling tool. The method can further include extracting a feature map from the drilling dynamics data, and determining that a feature zone from the feature map corresponds to a predetermined dynamic state. The feature zone can be determined using a neural network trained to associate feature zones with dynamic states. Additionally, the method can include selecting a drilling parameter for a drill string based on the feature zone.

Automatic interpretation of drilling dynamics data

A method for determining tortuosity, e.g., in an oilfield well includes obtaining a planned trajectory for a hole, and obtaining a first survey of the hole using a sensor deployed into the hole. The first survey includes a first surveyed position at a first depth of the hole and a second surveyed position at a second depth of the hole, and no surveyed positions between the first and second depths. The method further includes simulating a second survey of the hole between the first and second depths using a model. The second survey includes a plurality of simulated positions of the hole between the first and second depths. The method includes determining that the simulated position at the second depth is proximal to the second surveyed position, and visualizing a trajectory of the hole based on the first and second surveys.

Virtual high-density well survey

A motor bypass valve diverts drilling fluid away from a downhole motor when the motor is off bit. Bypassing the downhole motor reduces the shock and vibration on the BHA caused by the downhole motor, thereby reducing the damage to the BHA. The motor bypass valve may divert fluid out of a housing or into a bore through the rotor of the downhole motor.

Motor bypass valve

A method can include receiving data for a borehole trajectory in a formation, a length of pipe, and a bottom hole assembly that includes a mud motor and a bit; generating a sequence for operation of the mud motor using a model of at least the bit, where the sequence includes a sliding mode and a rotary mode for drilling the borehole in the formation a distance less than or equal to the length of pipe; and drilling the borehole according to the sequence.

Drilling mode sequence control

Management of fatigue life includes partitioning a drilling interval into sections, and calculating a stress value for each section. From the stress value, an equivalent alternative stress amplitude is calculated for each location, and a fatigue life consumption value in each section is computed. The fatigue life consumption value across the sections is aggregated to obtain an aggregated fatigue life consumption value, which is presented.

Fatigue analysis procedure for drill string

A method, system, and computer readable medium for managing drilling operations include calibrating a drilling model using collected drilling data, and executing, during a drilling operation, a simulation on the drilling model to generate a predicted measurement value for a drilling property. During the drilling operation and from a drillstring, an actual measurement value for the drilling property is obtained. Based on the actual measurement value matching the predicted measurement value, the simulation is extended to generate a simulated state of the drilling operation during the drilling operation, and a condition of the drilling operation is detected. A notification may be presented based on the condition during the drilling operation.

Real time drilling monitoring

A method for drilling a well includes applying energy input to a drill string () by at least one of rotating the drill string () from surface and operating a drilling motor () disposed in the drill string () to operate a drill bit () at a bottom of the drill string (); an amount of the applied energy not consumed in drilling formations caused by at least one of motion, deformation, and interaction of the drill string () is calculated; an amount of the applied energy used to drill formations below the drill bit () is calculated; and at least one drilling operating parameter is adjusted based on energy calculation before or during drilling operation.

Drilling energy calculation based on transient dynamics simulation and its application to drilling optimization

A method can include receiving a maximum depth of cut value of a bit that accounts for bit body formation engagement; receiving a total revolution rate value for the bit that is based at least in part on a differential pressure value of a mud motor; generating a rate of penetration value for the bit as operatively coupled to the mud motor by multiplying the maximum depth of cut value and the total revolution rate value; and operating a rigsite system according to the rate of penetration value for drilling a portion of a borehole using the bit as operatively coupled to the mud motor.

Rate of penetration drilling operation controller

A cutting element is provided having a substrate and an ultra hard material cutting layer over the substrate. The cutting layer includes a surface portion for making contact with a material to be cut by the cutting element. The surface portion in cross-section has a curvature that has a varying radius of curvature. A bit incorporating such a cutting element is also provided.

Cutting elements having cutting edges with continuous varying radii and bits incorporating the same

Growing community of inventors

Houston, TX, United States of America

Yuelin Shen