Landmark Graphics Corporation

Halliburton Energy Services, Inc.

Other

University of Houston System

Halliburton

Landmark Graphics Corporalion

Robello Samuel

Zhengchun Liu

Adolfo Gonzales

Aniket

Yongfeng Kang

Yuan Zhang

Manish Kumar Mittal

Olivier Germain

Xiaoqian Huang

Umesh N Reddy

Richard Thomas Hay

Srinath Madasu

Keshava Prasad Rangarajan

Gustavo Adolfo Urdaneta

Serkan Dursun

Jun Jiang

Rishi Adari

Jeffrey Marc Yarus

James Randolph Lovorn

Mark Evans Williams

Christopher Neil Marland

Nishant Raizada

Aravind Prabhakar

Aniket Aniket

Gangbing Song

James H Dudley

Amit Kumar Singh

Shang Zhang

Nitish Chaudhari

R Daniel Colvin

Wenjun Huang

Vikrant Lakhanpal

Ramakrishna R Chada

Douglas Caraway

Shashi Dande

Cili Sun

Richard Daniel Colvin

Devendra Patil

DeWayne Edward Pratt

Avinash Wesley

William Wade Samec

Jin Fei

Raja Vikram R Pandya

Dong Li

Nagaraj Srinivasan

Yashas Malur Saidutta

Alp Kozak

Gabriela M Morales-Ocando

Vanessa Ndonhong Kemajou

Qingzhao Kong

Abhishek Agrawal

Robert H Gales

Jenny Xie

Roddy Hebert

Swaminathan Kiran Kumar

Ying Zhao

Jeremy Codling

Vakkeyil Naveen Nair

Nadeem A Haq

Abbas Sami Eyuboglu

Alfred Fung

Paola Alejandra Perez Pena

Krishna Chaitanya Nunna

Gareth M Braund

Oluwafemi I Oyedokun

Robert D Gilcrist

Zhenying Wang

Chris Neil Marland

Emad Bakri Yassin Ibrahim

Olivier R Germain

Nfn Aniket

Manish K Mittal

Aniket,

(none) Aniket

Zhengchun M Liu

Ram Naresh Adari

Zhenchun Liu

Olivier Roger Germain

Adolfo C Gonzales

Dewayne Pratt

A method comprises determining a value of at least one oppositional force for a drillstring at multiple depths in the wellbore, determining a value of hook load for the drillstring at the multiple depths based on the value of the at least one opposition force at the multiple depths, and determining a calibrated drillstring weight based on a change in the value of the hook load over the multiple depths of the wellbore. The change in the value of the hook load can be determined based on a change in a measured hook load and/or a change in an estimated hook load. From the calibrated drillstring weight, an adjusted estimated hook load can be determined.

Calibration of drillstring weight for friction factor estimation

A system for designing a casing string for a well. The system comprises a processor, a non-transitory memory, a thermodynamic modeling application stored in the non-transitory memory that, when executed by the processor, models carbon dioxide (CO) material in the well using a carbon dioxide equation of state (EoS) to determine thermodynamic properties of the COmaterial, and a downhole environment modeling application stored in the non-transitory memory that, when executed by the processor determines temperatures of and pressures at well components at each of a plurality of points of a casing string design based in part on the thermodynamic properties of the COmaterial determined by the thermodynamic modeling application, and provides the temperatures of well components and pressures in the casing string at each of the plurality of points of the casing string to a casing string strength analysis application executing on the computer system.

COoperation temperature and pressure analysis and well design with COmodeling with equation of state method

A system can generate, via a software model, downhole pressure estimations and downhole debris estimations using caving parameters. Additionally, the system can generate, via the software model, settled caving volume percent estimations using the caving parameters. The system can determine a pack off volume percent using the downhole pressure estimations, the downhole debris estimations, and the settled caving volume percent estimations. The system can output, via a user interface, the pack off indicator and a subset of the caving parameters for use in adjusting a wellbore operation. The user interface can provide a plot of the pack off volume percent horizontally offset with respect to a plot of the subset of the caving parameters and a depth of the wellbore.

Pack off indicator for a wellbore operation

A method comprises drilling a borehole and capturing data during drilling of the borehole, wherein the data comprises at least one value of at least one operational parameter of the drilling. A specific energy formula is modified and used to determine at least one of an efficiency and a quality of drilling of a borehole. Modifying the specific energy formula is based on data captured during drilling of the borehole. The specific energy formula comprises at least one of a mechanical specific energy formula and a hydromechanical specific energy formula. An adjusted specific energy value for the drilling is calculated based on the modified specific energy formula. At least one of the efficiency and the quality of the drilling of the borehole is determined based on the adjusted specific energy value. Also disclosed is a system comprising a machine-readable medium having program code executing the method.

Mechanical and hydromechanical specific energy-based drilling

A system can receive input data indicating a current state of a wellbore drilling operation. The system can determine, by a set of software applications, constraints associated with the wellbore drilling operation. The system can optimize, by an optimization model and using the input data, a drilling parameter subject to the constraints associated with the wellbore drilling operation. The system can output the optimized drilling parameter for controlling the wellbore drilling operation.

Optimizing drilling parameters for controlling a wellbore drilling operation

The embodiments include systems and methods to determine torque and drag of a string. A method includes analyzing a plurality of continuous segments of a string deployed in a wellbore, and determining a deflection of the plurality of continuous segments from a node of the string and a tortuosity deflection of the wellbore. In response to a determination that deflection of the plurality of continuous segments from the node of the string is greater than the tortuosity deflection of the wellbore, the method includes applying a soft string model to determine a torque and a drag of the string. In response to a determination that deflection of the plurality of continuous segments from the node of the string is not greater than the tortuosity deflection of the wellbore, the method includes applying a stiff string model to determine a torque and a drag of the string.

Systems and methods to determine torque and drag of a downhole string

The disclosed embodiments include well operation evaluation systems and methods to analyze a broomstick chart of a well operation. The method includes receiving data indicative of a well operation involving deploying a conveyance to a predetermined location. The method also includes determining one or more conditions that impact deployment of the conveyance to the predetermined location. The method further includes determining a likelihood of occurrence of the one or more conditions. The method further includes determining one or more operations which, when performed by one or more tools used during the well operation, overcome the one or more conditions.

Conveyance deployment systems and methods to deploy conveyances

Drilling parameters for a wellbore operation can be determined based on resonance speeds. For example, a system can receive real-time data for a drilling operation that is concurrently occurring with receiving the real-time data. The system can determine, for a drilling depth, a rotations-per-minute (RPM) value corresponding to a resonance speed based on a weight-on-bit (WOB) value and the real-time data. The system can generate a plot of the WOB value and the RPM value corresponding to the resonance speed. The system can determine drilling parameters for the drilling operation based on the plot. The drilling parameters can exclude, for the WOB value, the RPM value corresponding to the resonance speed.

Determining parameters for a wellbore operation based on resonance speeds of drilling equipment

The disclosed embodiments include well operation evaluation systems and methods to analyze a broomstick chart of a well operation. The method includes receiving data indicative of a broomstick chart of a well operation. The method also includes diagnosing an issue during the well operation based on the broomstick chart. The method further includes predicting an impact on the well operation as a result of the issue. The method further includes determining a likelihood of occurrence of the impact. The method further includes determining a solution to overcome the issue.

Well operation evaluation systems and methods to analyze a broomstick chart of a well operation

Processes to receive user input parameters and system input parameters associated with a borehole undergoing active drilling operations to continually update drilling directions with wholistically applied optimizations to bring the actual borehole trajectory closer to the planned borehole trajectory. The processes can project ahead of the drilling assembly to determine the actual trajectory of the borehole and generate corrections to reduce the gap between the actual and planned trajectory paths. Various optimizations can be applied to the corrections to avoid overstressing systems or reducing the borehole productivity. Conflicts between optimizations can be resolved using a weighting or ranking system. More than one set of corrections can be determined and a user or a machine learning system can be used to select the one set of corrections to use as the results to be communicated and applied to the drilling operation plan or a borehole system, such as a geo-steering system.

Trajectory tracking and optimization for drilling automation

Systems, methods, and computer-readable media for an integrated and comprehensive hydraulic, environmental, and mechanical tubular design analysis workflow and simulator for complex well trajectories. An example method can include obtaining data defining a configuration of a wellbore having a complex well trajectory, one or more operations to be performed at the wellbore, and one or more loads associated with the wellbore; calculating environmental conditions associated with a set of wellbore components along the complex well trajectory based on the data defining the configuration of the wellbore, the one or more operations, and the one or more loads; calculating stress conditions associated with the set of wellbore components based on the environmental conditions and the data defining the configuration of the wellbore, the one or more operations, and the one or more loads; and presenting the environmental conditions and the stress conditions via a graphical user interface.

Systems and methods for integrated and comprehensive hydraulic, thermal and mechanical tubular design analysis for complex well trajectories

Systems, methods, and computer-readable media are provided for rig monitoring and in particular, to receiving data from a plurality of sensors in real-time, mapping the data from the plurality of sensors with a micro-activity and a macro-activity, generating a message based on the mapping of the data from the plurality of sensors with the micro-activity and the macro-activity, selecting a parameter to be compared with a bit depth, tuning the parameter and the bit depth with a corresponding model based on the message, generating a parameter uncertainty array and a bit depth uncertainty array based on the tuning of the parameter and the bit depth, and generating dynamic uncertainty ellipses based on the parameter uncertainty array and the bit depth uncertainty array.

Intelligent rig state detection and uncertainty analysis on real-time drilling parameters

Aspects and features of this disclosure relate to projecting physical drilling parameters to control a drilling operation. A computing system applies Bayesian optimization to a model incorporating the input data using varying values for an adverse drilling factor to produce a target function. The computing system determines a minimum value for the target function. The computing system provides a projected value for the physical drilling parameters based on the minimum value. The computing system generates an alert responsive to determining that the projected value for the physical drilling parameters exceeds a prescribed limit.

Physical parameter projection for wellbore drilling

The disclosure presents apparatuses and systems to reduce drag and friction forces on a drill string located downhole a borehole. The drill string can have two or more movement isolators to allow a movement sensitive tool to be movement isolated from other portions of the drill string that have powered movement. The other drill string portions can be powered by a surface equipment or by a downhole movement motor attached to the drill string, such as a rotational mud motor, an agitator, a jar motor, or a rotary steerable. Portions of the drill string located further downhole than the movement sensitive tool can utilize a movement motor attached to the drill string to provide movement to reduce drag and friction force where the movement isolators can reduce the movement force experienced by the movement sensitive tool.

Multiple swivels and rotation motor system

A method for designing a borehole tubular for use in a borehole. The method may include defining tubular sections that make up the borehole tubular, defining a downhole operation that will be conducted using the borehole tubular at a first timestamp, determining loads that will be applied to each of the tubular sections at respective specific depths along the borehole during the downhole operation at the first timestamp, determining a design limit envelope for each of the tubular sections at the first timestamp based on design parameters of the tubular section and the specific depth of the tubular section at the first timestamp, and displaying a three-dimensional (3D) plot of the design limit envelopes of the tubular sections and the loads applied to the tubular sections as a function of depth within the borehole on a display.

Systems and methods for borehole tubular design

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Cypress, TX, United States of America

Robello Samuel