Schlumberger Technology Corporation

Westerngeco L.l.p.

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Shunfeng Zheng

Hubertus V. Thomeer

Lawrence J. Leising

Benjamin P. Jeffryes

Benjamin Peter Jeffryes

Ashley Bernard Johnson

Walter David Aldred

Iain Michael Cooper

John Mervyn Cook

Michael Paul Barrett

Hubertus V Thomeer

Nathaniel Wicks

Geoffrey Charles Downton

Gokturk Tunc

Lawrence James Leising

Maurice Ringer

Michael Charles Sheppard

Claude J Vercaemer

Steven Antony Gahlings

William Lesso

Adam Ian Bowler

Jacques J Orban

Frank F Espinosa

Kjell Haugvaldstad

Riadh Boualleg

Andrew Hawthorn

Jian Wu

Goke Akinniranye

Brian Oliver Clark

Bikash Kumar Sinha

Arthur H Hartog

Martin E Poitzsch

J Ernest Brown

Richard Timothy Coates

Keith A Moriarty

Louise Bailey

Ginger Hildebrand

James Edward Martin

Paul Simon Hammond

Simon Hastings Bittleston

Dominique Guillot

Paul Bolchover

Arnaud Jarrot

Richard John Harmer

Tom R Bratton

Thomas J Plona

Sandra Denisse Reyes

Oney Erge

Geoffrey Colin Maitland

Samba Ba

Jonathan Dunlop

Rustam Isangulov

Christopher Bogath

Philip Christie

Mauro Caresta

Mochammad Faisal Wingky

Lee Dolman

Richard Dearden

David Edward Nichols

Timothy Tristam Jervis

Ines De Mata Cecilio

Lee F Dolman

Iead Rezek

John A McCullagh

William Li-Tien Wang

Yan Kuhn De Chizelle

Methods and apparatus pertaining to scaling of the proportional gain and the integral gain in PI controllers of an autodriller based on drilling context. For example, a proportional gain and an integral gain are each determined for utilization by a PI controller of an autodriller controlling operation of equipment to be utilized for a drilling operation to drill a borehole into a subterranean formation. During the drilling operation, the integral gain is updated in real-time utilizing current values of drilling parameters that change with respect to time.

Autodriller contextual scaling

An apparatus and method for controlling a drilling system in a manner that reduces stick-slip by receiving a desired rotation speed vof the drive system to rotate the drillstring, receiving property measurements of the drilling system, and deriving therefrom a rotation speed vof upgoing rotational waves of the drillstring associated with upgoing rotational energy in the drillstring. An actual rotation speed v of the drive system to rotate the drillstring is determined by representing energy in the drillstring as a mathematical expression containing a sum of rotational energy produced by the drive system and downgoing rotational energy caused by the upgoing rotational waves that are reflected downwardly at an upper end of the drillstring, and then optimizing the mathematical expression, which is then used for controlling the drive system to rotate the drillstring at v.

Drilling system control for reducing stick-slip by calculating and reducing energy of upgoing rotational waves in a drillstring

A method for changing a set point of a system where period of a dominant resonance of the system is determined, a change profile for the set point change is processed; a time period for the set point change based on the period of the dominant resonance in order to minimize excitation of the dominant resonance is also processed; and the set point change is actioned according to the processed change profile and the time period.

Changing set points in a resonant system

Apparatus and methods for optimizing a stick-slip algorithm for controlling a driver of a drill string. A method may include commencing operation of a control system for controlling the driver. The control system may have a processor and a memory storing a computer program code, which may include the stick-slip algorithm. The operating control system may receive a plurality of different numerical parameters, and for each of the different numerical parameters, incorporate the numerical parameter into the stick-slip algorithm and execute the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string.

Optimizing algorithm for controlling drill string driver

Embodiments of the present disclosure relate to a tangible, non-transitory, computer-readable medium that stores instructions executable by one or more processors, in which the instructions cause the one or more processors to determine a threshold value associated with an axial acceleration oscillation amplitude at a drill bit, in which the drill bit is a part of a drilling system. The instructions further cause the one or more processors to receive an operating parameter value of the drilling system, compare the operating parameter value with the threshold value, and adjust an operation of the drilling system in response to comparing the operating parameter value with the threshold value.

Systems and methods to determine rotational oscillation of a drill string

A proportional integral derivative (PID) controller implements control over a drilling system based on an integral term and a proportional term. The integral term is the integral of an operating drilling fluid pressure compared to a target drilling fluid pressure. The proportional term is the difference between an operating weight on bit and a target weight on bit. The sum of the proportional term and the integral term is multiplied by a controller parameter to determine a surface rate of penetration. A drill pipe lowering rate may be changed based on the determined surface rate of penetration, and the process may repeat in an iterative cycle until the integral term is reduced to an acceptable degree.

Methods of drilling using mixed proportional integral derivative control

A method includes creating a digital description of the well construction system, wherein the digital description of the well construction system describes the locational relationship of components in the well construction system, collecting multiple types of data from a well construction system, and tagging the collected data with an identification indicating at least one of a location of a source of collected data and a component in the well construction system from which the data is collected. The multiple types of data include sensor data collected from one or more sensors disposed along the well construction system and operational state data indicating an on/off status of one or more components in the well construction system.

System and method for using data with operation context

Changes to the vibrational frequencies of a drill string or BHA are monitored for prognostic health monitoring purposes. When one or more orders of resonance frequencies deviate from a baseline frequency, the magnitude of the deviation, and possibly the rate of deviation, is evaluated. When the deviation exceeds a threshold value, an alert is triggered. The alert may be triggered by downhole processing of the vibration data and conveyed to an operator to allow changes in operational parameters or removal of the component from the wellbore. The alert may instead be triggered by post-run processing of stored and dumped data, that can be used to evaluate whether the tool can be re-run, or whether it should be inspected, repaired, or scrapped.

Prognostic health monitoring of downhole tools

Systems and methods for drilling a wellbore. The method includes measuring a first distance that a drilling device is raised while connected to a drill string, determining a weight-on-bit in the drill string, determining a second distance to lower the drilling device such that a drill bit at a lower extremity of the drill string approaches toward a bottom of the wellbore, based on the first distance and the weight-on-bit, and lowering the drilling device by the second distance.

Drill bit distance to hole bottom measurement

Apparatus and methods pertaining to a processing system operable to determine a change to an operation of a well construction system based on an indication of a quality of transmitted communication between downhole equipment of the well construction system in a wellbore and surface communication equipment of the well construction system transmitted during the operation, a projected effect of the operation on future communication between the downhole equipment and the surface communication equipment, downhole data related to one or more conditions in the wellbore, or a combination thereof. The processing system is operable to cause the change to the operation of the well construction system to be implemented.

Well construction using downhole communication and/or data

A method for determining a rotational frequency of a positive displacement motor positioned in a downhole portion of a drill string, the method including: providing at least one measurement device for measuring a property of a part of the drill string; providing a processor for processing a signal output by the at least one measurement device; operating the positive displacement motor whilst the part of the drill string is in a non-driven state; receiving the signal at the processor; determining, using the processor, a frequency spectrum of the signal; and determining the rotational frequency of the positive displacement motor by: identifying a peak in the frequency spectrum in a pre-determined frequency range associated with an expected rotational frequency of the positive displacement motor; and/or identifying a peak in the frequency spectrum having a pre-determined peak width associated with an expected rotational frequency of the positive displacement motor.

Methods and systems for use with a positive displacement motor

A system and method for operating a mud motor in a wellbore. The method includes running the mud motor into the wellbore. A threshold rate of a pressure increase over time is selected. A rate of a pressure increase over time is measured across the mud motor in the wellbore. A flow rate of a fluid being pumped into the wellbore is varied when the measured rate is greater than or equal to the threshold rate.

System and method for mitigating a mud motor stall

An apparatus and method for controlling a drilling system in a manner that reduces stick-slip by receiving a desired rotation speed vof the drive system to rotate the drillstring, receiving property measurements of the drilling system, and deriving therefrom a rotation speed vof upgoing rotational waves of the drillstring associated with upgoing rotational energy in the drillstring. An actual rotation speed v of the drive system to rotate the drillstring is determined by representing downgoing energy in the drillstring as a mathematical expression containing a sum of downgoing rotational energy produced by the drive system and downgoing rotational energy caused by the upgoing rotational waves that are reflected downwardly at an upper end of the drillstring, and then optimizing the mathematical expression, which is then used for controlling the drive system to rotate the drillstring at v.

A method for detecting an influx and/or loss of circulation in a wellbore, comprising measuring a condition in the wellbore using a downhole sensor; determining that a positive displacement pump is shut off or turned on; predicting pit volume and/or gas concentration at a plurality of time points after the positive displacement pump is shut off or turned on using the measured condition in the wellbore prior to the positive displacement pump is shut off or turned on, wherein the measured condition correlates with the pit volume and/or gas concentration; measuring pit volume and/or gas concentration at the plurality of time points; comparing the predicted and the measured pit volumes and/or gas concentrations at the plurality of time points; and producing a warning signal if the difference between the predicted and the measured pit volumes and/or gas concentrations is greater than a pre determined value.

Detection of influx and loss of circulation

Methods and apparatus for controlling drill string rotation. The apparatus may be a control system for controlling a driver operable to rotate a drill string to form a wellbore extending into a subterranean formation. The control system may include a first controller operable to control rotation of the driver and a second controller communicatively connected with the first controller. During the drilling operations the first and/or second controller may be operable to generate a rotational speed command based on status information indicative of operational status of the drill string, and thereby cause the driver to rotate the drill string based on the rotational speed command.

Controlling drill string rotation

Growing community of inventors

Histon, United Kingdom

Benjamin Peter Jeffryes