Halliburton Energy Services, Inc.

Halliburton Company

Other

Stanley Vernon Stephenson

Jim Basuki Surjaatmadja

Timothy Holiman Hunter

Ronald Glen Dusterhoft

Philip D Nguyen

Tim H Hunter

Billy Don Coskrey

Bryan John Lewis

Joseph A Beisel

Max Lynn Phillippi

Ronald E Dant

Leslie N Berryman

David Mark Stribling

Herbert John Horinek

Mark Allen Adams

Mikko K Jaaskelainen

Harold Grayson Walters

Alexander Simon Chretien

Robert L Toellner

Vincent G Reidenbach

Joe A Beisel

David A Prucha

Edward P Arnold

Shahab Jamali Ghare Tape

Thuong Van Le

Chad A Heitman

Calvin Lynn Stegemoeller

Aaron Michael Beuterbaugh

Wesley John Warren

Ubong Akpan Inyang

Tirumani N Swaminathan

Glenn Howard Weightman

Joshua Lane Camp

Mehdi Sebdani Mazrooee

Andrew Silas Clyburn

Shameem Siddiqui

Thomas M Logan

David Rand Hill

Herb Horinek

Andrew James Summers

Sumit Bhat

Dingding Chen

Daniel Joshua Stark

Liang Xin Xu

Syed Hamid

James Marshall Barker

Mohamed Yousef Soliman

Michael Wayne Sanders

John Lodewyk Loth

Karl W Blanchard

Bruce Carl Lucas

Stephen F Crain

Keith A Frost

Baidurja Ray

Norman Raymond Warpinski

Neil Alan Stegent

Kenneth Gregory Neal

John Dexter Brunet

Jonathan Smith

Mark Farabee

Brian Alan Evans

Paul O Padgett

Bruce M Cox

John Hanton

Adam Lynn Marks

Larry Edwin Guffee

Oscar Andres Cabada Kriebel

Sergei Parsegov

Ivan L Blanco

Charles D Donaghe

Kenneth Ray Coffman

Terry H McCoy

David W Looper

Russell D Taylor

Phillip N Naegele

John Carl Reid

Corey Gene Ralls

Allan Zhong

Alan Coats

Ron Dusterhoft

Erik Lee

Timothy A Freeney

Kent J Dieball

Jerry N Browning

Neil A Pritchard

Herbert Hornick

Greg MaCauely

Phillip A Rogers

Philip A Rogers

Matthew R Margis

Herbert Horinek

Tim Holiman Hunter

Wesley J Warren

Tirumani Swaminathan

In accordance with presently disclosed embodiments, a hybrid drive system that uses multiple sources of mechanical energy to drive a pump is provided. The hybrid drive system may include a first mover for generating first mechanical energy, a pump, a drivetrain for providing first mechanical energy from the first mover to the pump, and a second mover within the drivetrain to generate and provide second mechanical energy to the pump. The multiple sources of mechanical energy may provide flexibility with respect to system design and allow for alternative sources of fuel and energy to be used to drive pumping systems. This may reduce the total diesel fuel consumption necessary to perform a well stimulation operation as well as provide for configurations in which diesel engines may be excluded from the pumping process in favor of alternative energy sources that typically do not have sufficient torque capacity to power a pump.

Hybrid drive systems for well stimulation operations

The life of internal components of a frack pump is affected by the frack fluid being pumped. The disclosure evaluates pump components and identifies parameters of frack pumps that may affect the remaining life of pump components based on pump models generated using flow type histories of the frack pumps. Pump related factors can also be used to identify the pump parameters. In one example, a method of evaluating pump components of a frack pump includes: (1) comparing a flow type history of the frack pump to at least one pump model, wherein the flow type history is automatically determined and is based on a proppant concentration of frack fluid pumped by the frack pump, (2) evaluating a condition of at least one component of the pump based on the comparing, and (3) changing a parameter of the pump based on the evaluating.

Automatically detecting a key parameter affecting pump components

A pumping system, comprising: a pump fluid end comprising a plurality of pump chambers, each pump chamber comprising a bore having a reciprocatable plunger disposed therein, a suction valve, and a discharge valve; a prime mover mechanically coupled to the fluid end [by a drivetrain] and configured to reciprocate the plungers; and a controller communicatively coupled to the prime mover, the fluid end, or both and configured to alert a user re a pump malfunction, initiate corrective action of the pump malfunction, or both in response to: (a) an indication of torque reversal during operation of the pumping system, (b) an indication of negative flow rate from the pump during operation of the pumping system, (c) an indication of leakage of (i) a single discharge valve in a 3-plunger pump or (ii) discharge valves associated with two plungers in adjacent firing order, or (d) any combination of (a)-(c).

Minimizing drivetrain damage from bad discharge valves on positive displacement pumps

The disclosure provides for a wellbore servicing system that comprises an engine operable to provide power to one or more pumps. The one or more pumps are operable to direct a fluid into a wellbore, wherein the engine is coupled to the one or more pumps via a transmission. The system further comprises an engine control module (ECM) coupled to the engine. The system further comprises a controller coupled to the one or more pumps and operable to determine the volumetric efficiency of each of the one or more pumps. The system further comprises an information handling system, wherein the ECM and the controller are communicatively coupled to the information handling system, wherein the information handling system is operable to determine a divergence when a load is placed on the engine and a pumping plan for the system.

Engine condition and control through the use of a pump as a dynamometer

The well system includes a first piece of wellsite equipment and a monitoring and control unit. The first piece of wellsite equipment includes an electronic storage device storing information related to the first piece of wellsite equipment. The monitoring and control unit is in electronic communication with the storage device of the first piece of wellsite equipment and configured to receive the stored information from the first piece of wellsite equipment, identify the first piece of wellsite equipment, and configure operational settings of the first piece of wellsite equipment.

Wellsite automatic configuration systems and methods of operation

The life of internal components of a frack pump is affected by the frack fluid being pumped. Manually trying to keep track of the frack fluid type being pumped is a tedious task that is susceptible to incorrect data or missing data. As such, the disclosure provides automated tracking of the amount of time or fluid volume that frack pumps pump the different fluid types and managing usage of the frack pumps using a history of the pumping. An example method of managing usage of a frack pump includes: (1) obtaining, for a time period or fluid volume, a proppant presence for a frack fluid being pumped by a frack pump, (2) automatically determining a flow type history for the frack pump over the time period or fluid volume based at least on the proppant presence, and (3) controlling a usage of the frack pump using the flow type history.

Automatically determining flow type histories for frack pumps and managing usage thereof using the flow type histories

Disclosed is generating an acquisition request of a component, using a probabilistic model based on current and planned life consumption, to maintain a usable component inventory, by: determining planned consumption of the component; retrieving historical lifetime data associated with the component; determining the associated normalized current life consumed for historical specimens at failure based on a power law equivalency model; determining a probability of survival distribution associated with the component; determine a probability of future failure of each component in inventory given planned consumption of the component; determine a projected number of component failures prior to completion of the job associated with the component; generate the at least one acquisition request to acquire a quantity of new components at least equal to the projected number of specific component failures prior to completion of the job; wherein the usable inventory of the component includes at least the quantity of new components.

Systems and methods for automated probabilistic based forecasts of component demand and cost incorporating data up-sampling

Provided are methods and systems for combining hydrogen supply and fuel cell processes for increased efficiency of electricity generation. The method may include decomposing methane to produce at least hydrogen, introducing at least a portion of the hydrogen to a fuel cell to generate at least electricity and heat, and capturing at least a portion of the heat from the fuel cell to reduce an electricity requirement for the methane decomposition. The system may include a methane preheater, a reaction system, a hydrogen storage system, a hydrogen fuel cell, and a heat recovery unit. The reaction system may comprise one or more reaction chambers containing a liquid base fluid, carrier droplets and a catalyst, wherein the reaction system is configured to decompose methane. The heat recovery unit may be configured to supply waste heat from the hydrogen fuel cell to the methane preheater.

Combined hydrogen supply and fuel cell processes for increased efficiency of electricity generation

Introduced herein are system and method for precisely determining the actual location of a standing wave created within a wellbore as well as other key properties about the created wave. The introduced system and method utilize a fiber optic sensing system, such as fiber optic Distributed Acoustic Sensing (DAS) system, that actively interrogates and monitors fiber optic sensors along the length of a wellbore. The introduced system and method generate one or more pressure pulses that combine with one another to create a standing wave within a wellbore and process the acoustic response of the standing wave using the fiber optic DAS system over a wide range of frequencies. Based on the measurements, the introduced system and method determine the actual location of the created standing wave and move it to a desired location within the wellbore by adjusting one or more properties of the pressure pulses.

Using fiber optic sensing to establish location, amplitude and shape of a standing wave created within a wellbore

A method of performing a wellbore operation may include providing a real-time treatment decision engine, equipment centric decision engine, and equipment controls. The equipment centric decision engine may be configured to interface with the real-time treatment decision engine and the equipment controls. The equipment centric decision may include an operational database comprising wellbore servicing equipment models. The method may further include providing wellbore servicing equipment. The wellbore servicing equipment may be operable to be controlled by the equipment controls. The method may further include sending a command from the real-time treatment decision engine to the equipment centric decision engine. The method may further include evaluating the command using the wellbore servicing equipment models. The method may further include selecting equipment to carry out the command based at least in part on the wellbore servicing equipment models. The method may further include sending a control signal to the equipment controls.

Real-time decision engine

Provided are methods and systems for delivering a treatment fluid to a wellsite. An example method includes receiving a container containing a treatment fluid component from a treatment fluid component supplier. The method further includes introducing the treatment fluid component into a wellbore from the container by pumping the treatment fluid component out of the container and into the wellbore. The treatment fluid component is not transferred to another container during the receiving or the introducing.

Storage, transport, and delivery of well treatments

A pumping system for performing a borehole operation including pumping a fluid into a borehole. The system may include a motor, a transmission, a pump, and a control system. The motor, transmission, and pump may each include sensors. The transmission may be operatively coupled to the motor. The pump may be operatively coupled to the transmission and configured to pump fluid into the borehole. The control system may be in communication with the motor sensors, the transmission sensors, and the pump sensors. The control system may be configured to monitor the operation of the motor, the transmission, and the pump, determine if at least one of the motor, the transmission, or the pump is operating outside of predetermined parameters, and determine at least one component of the motor, the transmission, or the pump that is most likely to cause the operation to be outside of the predetermined parameters.

Wellsite pumping systems and methods of operation

To detect the occurrence of slippage, a transmission health monitor integrates speed measurements for an engine shaft and a transmission shaft to determine a number of revolutions for each shaft. The monitor then uses a ratio of the revolutions adjusted for a transmission gear ratio to determine whether slippage has occurred. Based on the slippage, the monitor can determine a cumulative amount of wear on a clutch for each gear and track the rate of change of slippage over time to determine a rate at which wear is occurring. The monitor can also correlate slippage calculations with torque measurements to identify operating conditions at which slippage is occurring. The monitor uses the cumulative amount of slippage, the rate of change of slippage, and the operating conditions at which slippage is occurring to estimate a remaining lifespan for a clutch or indicate that a clutch should be repaired or replaced.

Transmission health indication and life prediction

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Duncan, OK, United States of America

Stanley Vernon Stephenson