Halliburton Energy Services, Inc.

The University of Texas System

Ketan Chimanlal Bhaidasna

Bhargav Gajji

Robert Phillip Darbe

Vy Pho

Richard Gary Morgan

Andrew David Vos

Nazli Demirer

Subrahmanyam Surya Venkata Sista

Shahin Tasoujian

Yang Liu

Khunsa Hisham

Yuanyan Chen

Subrahmanyam Surya Sista

Julien Marck

Dongmei Chen

Kaixiao Tian

Dale E Jamison

Jeffrey James Miller

Abhimanyu Pramod Deshpande

Zhijie Sun

Siva Rama Krishna Jandhyala

Ganesh Shriniwas Pangu

Umut Zalluhoglu

Bipin Kumar Pillai

Jian Wu

Kenneth Heidt Matthews, Iii

Reena Agarwal Chanpura

Cili Sun

John R Hardin

Jeremy Alexander Greenwood

Christopher Ray Bell

Shawn Lynn Broussard

Alexander Mathew Keller

Ganesh Ramakrishnan

He Zhang

James Robert Jones

Min Wu

Sandeep Mavinkal Kizhakke Veedu

Harmeet Singh Jammu

Walmy Cuello Jiminez

Chatti Srinivasa Rao

Tianheng Feng

Robert Alan Friedrich

Kennedy J Kirkhope

Fernando Costa Oliveira Chagas

Shichao Xu

Jiamin Xu

Vyacheslav Chernin

Justin T Loop

Viatcheslav Tchernin

Kenneth Heidt Matthews

Abhhilash Mamilla

A method that may comprise disposing a bottom hole assembly into a formation, wherein the bottom hole assembly comprises a mud motor, identifying a first segmented data set for a slide mode of the mud motor, and identifying a second segmented data set for a rotate mode of the mud motor. The method may further comprise calibrating the mud motor at least in part using a Reversible Jump Markov Chain Monte Carlo (RJMCMC), wherein the RJMCMC uses at least in part the first segmented data set and the second segmented data set.

Real-time tool yield calibration of mud motor

In directional drilling, a nonlinear Delay Differential Equation (DDE) model may be used for its high precision in predicting how a borehole may be drilled according to a well plan. To address challenges associated with real-time control of a drill drilling wellbore, techniques of generalized feedback linearization, finite element concept, and zero-order hold discretization may be used to transform a nonlinear DDE model into discretized domain with a linear Ordinary Differential Equation (ODE) form. Following this transformation, a novel optimization framework may be used to concurrently determine optimal control inputs and solve a linear complementarity problem (LCP). The validity of both the discretized model and the optimization strategy may be verified by comparing modeled results with real-world results. Subsequent closed-loop simulations demonstrate the ability of the proposed model predictive control to maintain alignment of a drill string with a planned well trajectory, even in the presence of disturbances and noise.

Nonlinear model predictive control for directional drilling applications

The disclosed embodiments include systems and methods to determine the steering of a bit. The method includes receiving input parameters associated with a model of a bottomhole assembly having a housing and a shaft that runs through an interior of the housing. The method also includes analyzing the housing as a first beam, and analyzing the shaft as a second beam that is nested within the first beam. The method further includes estimating a force and moment at a contact point between the shaft and the housing, determining a housing deflection based on the force and the moment, determining a shaft deflection at the contact point, and determining whether the shaft deflection is within a threshold of the housing deflection. In response to a determination that the shaft deflection is within the threshold of the housing deflection, the method further includes providing an output indicative of steering of a bit.

Systems and methods to determine the steering of a bit

A computer-implemented method for drilling a curve section of a wellbore in a subsurface formation. The method comprises obtaining a curvature setpoint. The method comprises obtaining drilling process feedback from a drilling assembly drilling the curve section of the wellbore. The method comprises updating a scheduling parameter vector based on the drilling process feedback. The method comprises updating a controller, wherein the controller is configured with the scheduling parameter vector. The method comprises determining an error based on the curvature setpoint and the drilling process feedback. The method comprises inputting the error into the controller. The method comprises determining, via the controller, steering decisions based on the error and the scheduling parameter vector.

Robust linear parameter varying control design for automated curvature cruise

The disclosure provides a solution to problems associated with vibrations during drilling by applying metrics on post job data and providing inputs from past experiences to pre-job planning for drilling jobs. The vibration information and analysis can also be used during a current drilling operation wherein a vibration source can be automatically identified and operating parameters can be changed to mitigate the vibration. The disclosure provides a method of executing a drilling operation, a vibration analyzer, and a drilling system. In one example, the method includes: (1) collecting drilling job data from a completed drilling job, wherein the drilling job data includes sensor data collected from downhole sensors, (2) determining a vibration severity index from the sensor data, and (3) executing at least a portion of a drilling operation based on the vibration severity index.

Service improvements using adaptive models derived from classified vibration mechanisms

Systems and methods of the present disclosure are directed to systems and methods for controlling a wellbore drilling apparatus where the system may include a surface controller and a downhole controller. In certain instances, control of the drilling apparatus may be transferred from the surface controller to the downhole controller. The control of the drilling apparatus may be transferred to the downhole controller as the surface control monitors operation of the drilling operation. The surface controller may also send a command that transfers control of the drilling apparatus from the downhole controller to the surface controller.

Closed loop fully autonomous directional drilling

The disclosure provides a solution for monitoring stick-slip vibrations without using any surface torque measurements. Instead, the disclosure provides a method to monitor stick-slip vibrations based on rotational speed. A stick-slip monitor, a top drive controller and a method of operating a drill string are provided herein that use rotational speed for monitoring stick-slip vibrations. In one example, the method of operating a drill string includes: (1) performing a frequency domain analysis of an RPM signal associated with a top drive that is used to rotate a drill string, and (2) determining a presence of torsional oscillations of the drill string based on the frequency domain analysis of the RPM signal.

Monitoring drilling vibrations based on rotational speed

Methods and compositions for estimating one or more downhole qualities of a drilling apparatus by obtaining axial acceleration data. The axial acceleration data may be acquired by measuring an axial acceleration of a bottom hole assembly. The axial acceleration may then be used to estimate one or more of a downward weight on a drill bit of the drilling apparatus or a rate of penetration of the drill bit.

Methods for estimating downhole weight on bit and rate of penetration using acceleration measurements

A curvature cruise controller has been designed to maintain a desired curvature when drilling a curve section of a wellbore. The curvature cruise controller utilizes a model-based controller (such as an LQR controller) to generate steering inputs based on the desired curvature and attitude setpoints and real time measurements. The model-based controller is configured with a wellbore propagation model that characterizes the tool's response dynamics. The curvature cruise controller utilizes real time drilling operation parameters measurements to tune the model-based controller.

Model-based curvature cruise control design

A method and system for estimating a wellbore curvature. The method may include disposing a rotary steerable system (RSS) into a borehole, storing a real-time curvature estimation for the borehole in an information handling system, wherein the information handling system is disposed on the RSS, taking a first attitude measurement at a first sensor, and taking a second attitude measurement at a second sensor. The method may further include applying a filter to at least the first attitude measurement and the second attitude measurement to form a filtered measurement set, performing a curvature estimation with the filtered measurement set to form an estimated curvature signal, comparing the estimated curvature signal to a curvature set point to find a difference, and adjusting at least one operating parameter of the RSS based on the difference.

Real-time curvature estimation for autonomous directional drilling

Methods and systems for characterizing multiple properties of a cement composition for use at downhole conditions using ultrasonic analysis tools are provided. In some embodiments, the methods comprise: transmitting at least a first p-wave and a second p-wave having different frequencies through a cement composition; determining velocities of the first and second p-waves through the sample; transmitting at least a third p-wave having a third frequency through the cement composition while allowing the cement composition to at least partially hydrate, wherein the third frequency is higher than the second frequency; determining at least a velocity of the third p-wave through the cement composition; based at least in part on the velocities of the p-waves, determining at least the compressibility, Poisson's ratio, Young's modulus, and shear modulus of the cement composition.

Methods and systems for characterizing multiple properties of cement using p-waves of multiple frequencies

A lubricity tester unit may comprise a housing, a shaft, wherein a first end of the shaft is disposed at a first end of the housing, wherein the shaft extends through housing along a central axis of the housing, and an encoder, wherein the encoder is disposed on an internal wall of the housing, wherein the shaft is disposed through a hole in the encoder, wherein the encoder is an optical encoder configured to measure angular position of the shaft. The lubricity tester unit may further comprise rotating rings, wherein the rotating rings are coupled to a second end of the shaft, a friction inducing surface, wherein the friction inducing surface is disposed around the rotating rings, a first sensor, wherein the first sensor is disposed through the housing, and a second sensor, wherein the second sensor is disposed through the housing.

Non-contact torque sensing

Viscosity assemblies may be used to determine the viscosity of a sample fluid at a surface location under one or more downhole conditions prior to pumping or flowing of the sample fluid downhole. A viscosity assembly may include a bob assembly disposed in a container that includes a bob disposed about a magnet rotor that rotates when a shear force is applied by the flow of the sample fluid in the container. A stator coil may receive a control signal that induces a force or a voltage that causes the magnet rotor to rotate the bob by a predetermined distance to position the bob from the rotated position back to the initial position.

Active sensor for torque measurement in a viscometer

A mud retort assembly includes a retort that heats a fluid and thereby generates vapors, a condenser in fluid communication with the retort to at least partially condense the vapors and thereby generate a liquid, a condensate collector that receives the liquid and residual vapors via an outlet pipe of the condenser, and a collector plug having a frustoconical body that extends partially into the condensate collector at an opening to the condensate collector. The collector plug defines a central aperture that receives the outlet pipe and has an annular flange extending radially outward from the frustoconical body to rest on the condensate collector at the opening.

Increasing accuracy of measurements using mud retorts by maximizing recovery of vapors

The embodiments herein relate generally to subterranean formation operations and, more particularly, to enhancing aging testing to characterize settling of particulates in treatment fluids for use in subterranean formation operations. The embodiments use a test cell apparatus comprising a test cell body having an open end for receiving a treatment fluid into an interior of the test cell body, the interior having a floating piston for separating the treatment fluid from a pressurization fluid; a sampling port extending from the open end and having a sample valve for receiving samples of the treatment fluid from the sampling port; a pressure input for pressurizing the interior; and a sealing assembly adapted to be inserted into the test cell body in contact with the interior to fluidly seal the open end and through which the sampling port extends, the sealing assembly comprising a retainable test cell cap.

Aging testing apparatus and use thereof

Growing community of inventors

Houston, TX, United States of America

Ketan Chimanlal Bhaidasna