Erdos Miller, Inc.

Black Diamond Oilfield Rentals, LLC

Reme, L.l.c.

Reme Technologies, LLC

Micropulse, Inc.

Basin Drilling Tools LP

Leam Drilling Systems, LLC

Diamond Oilfield Rentals, LLC

David Erdos

Kenneth C Miller

Abraham Erdos

Joshua Carter

James Mathieson

Ken Miller

Nathan Szanto

Benjamin Jennings

Brad Munoz

Amador Baggerly

In one embodiment, a method is disclosed for using a trained machine learning model to classify mud pulse signals. The method may include receiving a mud pulse signal from a measurement while drilling (MVWD) tool, wherein the mud pulse signal includes data. The method may also include decoding, using the trained machine learning model, the data to determine a value of the data, and providing a user interface comprising the value of the data for presentation on a computing device of a user.

Enhanced measurement-while-drilling decoding using artificial intelligence

A method is disclosed for receiving, from a downhole system, data at a transmitter module of an intra-bottom hole assembly (BHA), wherein the transmitter module comprises a magnetic transmission antenna; transmitting, via a wireless short-range communication using the magnetic transmission antenna, the data to a receiver module of the intra-BHA, wherein the transmitter module and the receiver module form an intra-BHA network using the wireless short-range communication; receiving, via the wireless short-range communication, the data at the receiver module; transmitting the data to a measurement while drilling (MWD) tool; receiving, at the MWD tool, the data; and transmitting, via a type of telemetry, the data from the MWD tool to a surface processor.

Intra-bottom hole assembly (BHA) wireless communication system

In one embodiment, a computer-implemented method is disclosed. The method includes operating a downhole tool by transmitting first data to one or more surface processors in a telemetry sequence. The first data may include a flex word having a first identifier identifying a first payload, and the first data is transmitted using a synchronized time sequence. The method includes detecting, by the downhole tool, an operating condition that occurs while the downhole tool is downhole. Based on the operating condition, the method includes dynamically changing the flex word to comprise a second identifier identifying a second payload transmitted in second data in the telemetry sequence to the one or more surface processors, and the second data is transmitted in the telemetry sequence using the synchronized time sequence.

Flex word telemetry sequencing

In some embodiments, a system including a tool drill string having a downhole device is disclosed. The downhole device includes a memory storing instructions and a downhole processor configured to execute the instructions to operate in a first transmission mode by default. The downhole processor is communicatively coupled to an uphole processor via the first transmission mode. The downhole processor is further to transmit, via a second transmission mode, a message to the uphole processor, determine whether a response is received, via the second transmission mode, from the uphole processor, and responsive to determining the response is received from the uphole processor, switch from the first transmission mode to the second transmission mode.

Automated telemetry for switching transmission modes of a downhole device

In some embodiments, a system includes an uphole processor and a tool drill string having a downhole device including a downhole processor. The uphole processor may include a memory storing instructions, the uphole processor may be communicatively coupled to the downhole processor, and the uphole processor may be configured to execute the instructions to determine a configuration setting of the system, determine whether the configuration setting indicates a trigger event has occurred, and responsive to determining the trigger event has occurred, transmit a downlink message to the downhole processor to modify an aspect of the downhole device.

Optimization of automated telemetry for a downhole device

In some embodiments, a system includes a surface processor and a tool drill string having a downhole device including a downhole processor. The surface processor may include a memory storing instructions, and the surface processor may be communicatively coupled to the downhole processor. The surface processor may be configured to execute the instructions to receive one or more first measurements from the downhole device, and determine whether the one or more first measurements satisfy a threshold measurement. Responsive to determining the one or more first measurements satisfy the threshold measurement, the surface processor may electronically modify a weight on bit by a first amount and electronically modify a revolutions per minute of a motor by a second amount.

Method and apparatus for using a surface processor to electronically control components of a toll drill string based at least on measurements from a downhole device

In some embodiments, a system may include a tool drill string having a downhole device. The system may include a contact module including a first component. The first component may include a first data path capable of communicating data using a first communication protocol, a second data path capable of communicating the data using a second communication protocol, and a processor electrically connected to the first data path and the second data path. The processor may be capable of selectively routing the data between the first data path and the second data path.

Contact module for communicating with a downhole device

Systems and methods are presented for reducing electrical interference in measurement-while-drilling ('MWD') data. An example may include, among other features a MWD data acquisition system including an analog data reception for receiving analog MWD data, an analog-to-digital conversion circuit, at least one isolation circuit for electrically isolating the analog data reception circuit and the analog-to-digital conversion circuit from a digital data transmission circuit. In some embodiments, a power isolation circuit may electrically isolate an analog section power domain from a digital section power domain. The isolation techniques may improve the quality of the analog signal received.

Systems and methods for reducing electrical interference in measurement-while-drilling data

A measurement while drilling system for a drill string having a fluidic medium in the drill string. The measurement while drilling system includes a first module situated at a distal end of the drill string and including a downhole processor and a pulser communicatively coupled to the downhole processor and configured to provide a pressure pulse in the fluidic medium, and a second module situated at a proximal end of the drill string and including an uphole processor and a pressure sensor communicatively coupled to the uphole processor. The downhole processor is configured to direct the pulser to provide the pressure pulse and the pressure sensor is configured to sense the pressure pulse. The uphole processor is configured to receive signals from the pressure sensor to determine a distance from the first module to the second module.

Drill string length measurement in measurement while drilling system

Systems and methods are presented for reducing electrical interference in measurement-while-drilling ('MWD') data. An example may include, among other features a MWD data acquisition system including an analog data reception for receiving analog MWD data, an analog-to-digital conversion circuit, at least one isolation circuit for electrically isolating the analog data reception circuit and the analog-to-digital conversion circuit from a digital data transmission circuit. In some implementations, the data reception device may be at least partially powered by the battery.

A measurement while drilling system including a first module and a second module. The first module situated at a distal end of a drill string and including a downhole processor configured to determine that the drill string is one of on a drill plan and off the drill plan, and a downhole communication module communicatively coupled to the downhole processor to transmit signals. The second module situated at a proximal end of the drill string and including an uphole communication module configured to receive the signals. Where the downhole processor is configured to transmit non-compressed data if the drill string is off the drill plan and compressed data if the drill string is on the drill plan.

Measurement while drilling communication scheme

A programmable integrated measurement while drilling (MWD) system is an integrated, ruggedized, and condensed MWD system configured to enable end-user customizable applications for downhole exploration and drilling. The integrated MWD system integrates a co-processor with a directional controller enabling execution of the end-user customizable applications without interrupting the real-time operations of the directional controller.

Programmable integrated measurement while drilling directional controller

A smart lower end system that can detect multiple events and failures during the generation of pressure pulses by a pulser is disclosed. Pulser failures may occur if the pilot valve fails to fully close or open, if the signal shaft fails to move and close pilot valve orifice, or if movement of the pilot valve or signal shaft is restricted. The components of the smart lower end system may cycle between sleep and wake states to allow for low power operation.

Growing community of inventors

Houston, TX, United States of America

David Erdos