DUAL DEVICE APPARATUS AND METHODS USABLE IN WELL DRILLING AND OTHER OPERATIONS

• US 20170009538A1
• Filed: 09/21/2016
• Published: 01/12/2017
• Est. Priority Date: 08/26/2014
• Status: Active Grant

• Current Assignee: Nisku Supply Industrial Oilfield Services Limited
• Original Assignee: Raptor Rig, Inc.
• Inventors: Layden, Reginald Waye
• Granted Patent: US 10,920,505 B2
• Time in Patent Office: Days
• US Class Current: 1/1
• CPC Class Codes: E21B 15/003 adapted to be moved on their substructure, e.g. with skidding means; adapted to drill a plurality of wells
• CPC Class Codes: E21B 19/06 Elevators, i.e. rod- or tube-gripping devices
• CPC Class Codes: E21B 19/07 Slip-type elevators
• CPC Class Codes: E21B 19/155 Handling between horizontal and vertical position
• CPC Class Codes: E21B 19/16 Connecting or disconnecting pipe couplings or joints E21B19/20 takes precedence
• CPC Class Codes: E21B 21/01 Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes
• CPC Class Codes: E21B 21/106 Valve arrangements outside the borehole, e.g. kelly valves valves specifically for maintaining circulation of drilling fluid while connecting or disconnecting tubular joints E21B21/019
• CPC Class Codes: E21B 3/02 Surface drives for rotary drilling
• CPC Class Codes: E21B 3/022 Top drives

Abstract

The present disclosure relates generally to devices and methods useable during well drilling operation. More particularly, the present disclosure pertains to a drilling rig incorporating a dual top drive apparatus useable for decreasing connection time of pipe segments useable during well drilling or other well operations, and methods of connecting pipe segments useable during well drilling or other operations.

Claims

1. A rig comprising:

a. a plurality of tubular rotational devices;

b. a derrick assembly for supporting the plurality of tubular rotational devices, wherein each of the plurality of tubular rotational devices is slidably disposed to move the tubular rotational devices toward a single wellbore and away from the wellbore, the wellbore having a wellbore axis; and

c. a plurality of lifting assemblies, wherein the plurality of lifting assemblies are operatively connected to the plurality of tubular rotational devices and a first lifting assembly is capable of moving a first tubular rotational device vertically inline with the wellbore while a second lifting assembly is capable of independently moving a second tubular rotational device vertically out of alignment with the wellbore,

wherein the first tubular rotational device is capable of rotating and lifting a first tubular segment inline with the wellbore while the second tubular rotational device is lifting and rotating a second tubular segment out of alignment with the wellbore.

2. The rig of claim 1, wherein each of the plurality of tubular rotational devices move simultaneously in an axis perpendicular to the wellbore axis.

3. The rig of claim 1, wherein the derrick assembly is capable of transitioning to move a first tubular rotational device inline with the wellbore while simultaneously moving the second tubular rotational device out of alignment with the wellbore.

4. The rig of claim 1, further comprising a check valve operatively connected to a tubular segment.

5. A method of assembling a tubular segment string using the rig of claim 1, the method comprising the steps of:

a. coupling the first tubular segment having a top and a bottom end with the first tubular rotational device;

b. moving the first tubular segment in a horizontal direction relative to a wellbore axis;

c. engaging the first tubular segment with a tubular segment string in the wellbore;

d. lowering the first tubular segment into the wellbore;

e. coupling the second tubular segment having a top and a bottom end with the second tubular rotational device;

f. moving the second tubular segment in a horizontal direction relative to the wellbore axis;

g. engaging the bottom end of the second tubular segment with the top end of the first tubular segment and lowering the second tubular segment into the wellbore; and

h. repeating at least steps a.-d. for additional tubular segments.

6. The method of claim 5, wherein the tubular is a pipe.

7. The method of claim 5, wherein the tubular rotational device is a top drive.

8. A method of moving a tubular segment using the tubular rotational devices of claim 1, the method comprising moving the tubular segment from a first position over the wellbore to a second position wherein a top end of the tubular segment is in contact with the tubular rotational device and the tubular segment is not over the wellbore.

9. A method of lifting a tubular segment having a bottom end and a top end, using the tubular rotational device of claim 1, wherein the tubular rotational device lifts the tubular segment a pre-defined distance to provide a certain clearance between the bottom end of the tubular segment and the wellbore.

15. The rig of claim 1, wherein the tubular is a pipe.

16. The rig of claim 1, wherein the tubular rotational device is a top drive.

10. A method of assembling a tubular segment string using a rig comprising:

a. a plurality of tubular rotational devices;

b. a derrick assembly for supporting the plurality of tubular rotational devices, wherein each of the plurality of tubular rotational devices is slidably disposed to move the tubular rotational devices toward a single wellbore and away from the wellbore, the wellbore having a wellbore axis; and

c. a plurality of lifting assemblies, wherein the plurality of lifting assemblies are operatively connected to the plurality of tubular rotational devices and a first lifting assembly is capable of moving a first tubular rotational device vertically inline with the wellbore while a second lifting assembly is capable of independently moving a second tubular rotational device vertically out of alignment with the wellbore,

wherein the first tubular rotational devices is capable of rotating and lifting a first tubular segment inline with the wellbore while the second tubular rotational device is lifting and rotating a second tubular segment out of alignment with the wellbore;

the method comprising the steps of;

a. coupling the first tubular segment having a top and a bottom end with the first tubular rotational device;

b. moving the first tubular segment in a horizontal direction relative to a wellbore axis;

c. engaging the first tubular segment with a tubular segment string in the wellbore;

d. lowering the first tubular segment into the wellbore;

e. coupling the second tubular segment having a top and a bottom end with the second tubular rotational device;

f. moving the second tubular segment in a horizontal direction relative to the wellbore axis;

g. engaging the bottom end of the second tubular segment with the top end of the first tubular segment and lowering the second tubular segment into the wellbore; and

h. repeating at least steps a.-d. for additional tubular segments;

further comprising preventing gas from the wellbore from venting into the atmosphere by employing at least one tubular segment with a check valve operatively connected to the tubular segment.

11. The method assembling a tubular segment string using a rig comprising

a. a plurality of tubular rotational devices:

b. a derrick assembly for supporting the plurality of tubular rotational devices, wherein each of the plurality of tubular rotational devices is slidably disposed to move the tubular rotational devices toward a single wellbore and away from the wellbore, the wellbore having a wellbore axis; and

c. a plurality of lifting assemblies, wherein the plurality of lifting assemblies are operatively connected to the plurality of tubular rotational devices and a first lifting assembly is capable of moving a first tubular rotational device vertically inline with the wellbore while a second lifting assembly is capable of independently moving a second tubular rotational device vertically out of alignment with the wellbore,

wherein the first tubular rotational devices is capable of rotating and lifting a first tubular segment inline with the wellbore while the second tubular rotational device is lifting and rotating a second tubular segment out of alignment with the wellbore;

the method comprising the steps of;

a. coupling the first tubular segment having a top and a bottom end with the first tubular rotational device;

b. moving the first tubular segment in a horizontal direction relative to a wellbore axis;

c. engaging the first tubular segment with a tubular segment string in the wellbore;

d. lowering the first tubular segment into the wellbore;

e. coupling the second tubular segment having a top and a bottom end with the second tubular rotational device;

f. moving the second tubular segment in a horizontal direction relative to the wellbore axis;

g. engaging the bottom end of the second tubular segment with the top end of the first tubular segment and lowering the second tubular segment into the wellbore; and

h. repeating at least steps a.-d. for additional tubular segments;

further comprising communicating a drilling fluid into a fluid passageway of at least one tubular segment lowered into the wellbore.

12. The method of claim 11, wherein the drilling fluid is subsequently diverted from the fluid passageway during a connection operation wherein one tubular segment is being connected to another tubular segment.

13. The method of claim 12, wherein upon connecting one tubular segment to the other tubular segment, the drilling fluid is diverted back to the fluid passageway.

14. The method of claim 12, wherein the step of diverting the drilling fluid comprises diverting the drilling fluid to a storage container.