Method of incorporating remote communication with oilfield tubular handling apparatus

Patent metadata

Field	Value
Publication number	US-2016369573-A1
Application number	US-201615257384-A
Country	US
Kind code	A1
Filing date	Sep 6, 2016
Priority date	May 31, 2011
Publication date	Dec 22, 2016
Grant date	—

Abstract

Signal communications at a drilling system generally includes communicating upwards or downwards from the rig floor. For example, signal communications upwards may comprise the control of a cementing head operation (e.g., actuating cementing head). Signal communications downwards may comprise the activation of tools and their confirmation (e.g., hole opening tools, liner hangers, and packers). Actuation may be performed via umbilicals, for example, via pressure spikes or the dropping of balls, darts, or radio-frequency identification (RFID) tags. However, issues may arise wherein, for example, a ball may not properly land to close a circulation valve. As another example, a cementing head could be over 100 feet above the rig floor, which may make it difficult for signal communications via an umbilical. Accordingly, what is needed are techniques and apparatus for activation of tools and their confirmation by a remote communication system.

First claim

1 . An oilfield tubular handling apparatus configured to handle a tubular member and capable of remotely communicating with a device associated with a wellbore, the apparatus comprising at least one of:
an acoustic transmitter integrated with the oilfield tubular handling apparatus and configured to transmit acoustic signals to the device via the tubular member; or an acoustic receiver integrated with the oilfield tubular handling apparatus and configured to receive other acoustic signals from the device via the tubular member.

2 . The apparatus of claim 1 , wherein the acoustic receiver comprises a piezoelectric sensor.

3 . The apparatus of claim 1 , wherein the acoustic transmitter comprises a solenoid.

4 . The apparatus of claim 1 , wherein the acoustic transmitter comprises a piezoelectric stack.

5 . The apparatus of claim 1 , wherein the at least one of the acoustic transmitter or the acoustic receiver is in physical contact with the tubular member.

6 . The apparatus of claim 1 , wherein the apparatus comprises tongs for making up or breaking out the tubular member.

7 . The apparatus of claim 1 , wherein the apparatus comprises an elevator, slips, a spider, a top drive, or gripping tools attached to the top drive.

8 . A system comprising:
a tubular member; a device associated with a wellbore; an oilfield tubular handling apparatus configured to handle the tubular member and capable of remotely communicating with the device associated with the wellbore, the apparatus comprising at least one of:
an acoustic transmitter integrated with the oilfield tubular handling apparatus and configured to transmit acoustic signals to the device via the tubular member; or
an acoustic receiver integrated with the oilfield tubular handling apparatus and configured to receive other acoustic signals from the device via the tubular member.

9 . The system of claim 8 , wherein the device is disposed in the wellbore.

10 . The system of claim 9 , wherein the device comprises a liner hanger.

11 . The system of claim 8 , wherein the device comprises a cementing head.

12 . The system of claim 8 , further comprising a handheld device configured to control the device associated with the wellbore via the acoustic signals.

13 . The system of claim 8 , wherein the tubular member comprises drill pipe, coiled tubing, or casing.

14 . An oilfield tubular handling apparatus capable of remotely communicating with a device associated with a wellbore, comprising:
partial toroidal coil sections integrated with the oilfield tubular handling apparatus, wherein the partial toroidal coil sections are configured to:
form a toroidal coil upon handling a tubular member with the handling apparatus; and
at least one of transmit signals to or receive other signals from the device, via the tubular member.

15 . The handling apparatus of claim 14 , wherein the toroidal coil comprises first and second windings, wherein the first winding is configured to transmit the signals, and wherein the second winding is configured to receive the other signals.

16 . The handling apparatus of claim 15 , wherein the first winding has a different number of windings from the second winding.

17 . The handling apparatus of claim 15 , wherein the first winding has a different wire diameter from the second winding.

18 . The handling apparatus of claim 14 , wherein the toroidal coil is not in physical contact with the tubular member.

19 . The handling apparatus of claim 14 , wherein a number of the partial toroidal coil sections that form the toroidal coil is dependent upon a diameter of the tubular member.

20 . The handling apparatus of claim 14 , wherein:
each of the partial toroidal coil sections is integrated with a respective clamp of the oilfield tubular handling apparatus; and the partial toroidal coil sections are configured to form the toroidal coil as clamps of the oilfield tubular handling apparatus move closer to the tubular member.

Assignees

• Weatherford Tech Holdings Llc

Inventors

• Teodorescu Sorin Gabriel
• Hatloy Hallvard Svadberg
• Gudmestad Tarald
• Ring Lev

Classifications

• E21B47/14

  using acoustic waves · CPC title

• E21B19/16

  Connecting or disconnecting pipe couplings or joints (E21B19/20 takes precedence) · CPC title

• E21B17/00

  Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; {Cables;} Casings; Tubings · CPC title

• E21B19/07

  Slip-type elevators · CPC title

• E21B31/20 Primary

  gripping internally, e.g. fishing spears · CPC title