Dual device apparatus and methods usable in well drilling and other operations

• US 10,920,505 B2
• Filed: 09/21/2016
• Issued: 02/16/2021
• Est. Priority Date: 08/26/2014
• Status: Active Grant

• Current Assignee: Nisku Supply Industrial Oilfield Services Limited
• Original Assignee: Raptor Rig Ltd.
• Inventors: Layden, Reginald Waye
• Primary Examiner(s): MacDonald, Steven A
• Application Number:
  US15/271,828
• Publication Number:
  US 20170009538A1
• Time in Patent Office: 1,609 Days
• 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

A trailer-mounted drilling rig incorporates a dual top drive apparatus and a plurality of lifting assemblies 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. The plurality of lifting assemblies operatively connected to the dual top drive apparatus and a first lifting assembly is capable of moving a first top drive vertically inline with a wellbore while a second lifting assembly is capable of independently moving a second top drive vertically out of alignment with the wellbore.

Claims

1. A rig comprising:

a. a plurality of tubular rotational devices, including at least a first tubular rotational device and at least a second tubular rotation device, wherein the first tubular rotation device and the second tubular rotation device each includes a drive shaft;

b. a derrick assembly for supporting the plurality of tubular rotational devices and a plurality of booms;

c. wherein the plurality of booms include at least a first boom and a second boom, wherein the first boom is operatively connected to at least the first tubular rotational device, wherein the second boom is operatively connected to at least the second tubular rotational device, wherein the first boom is capable of moving the first tubular rotational device vertically inline with a single wellbore while the second boom is capable of independently moving the second tubular rotational device vertically out of alignment with the wellbore,

wherein the plurality of booms are slidably disposed in a horizontal direction along a rail proximate an opening of the wellbore to move each of the plurality of tubular rotational devices and toward the wellbore and away from the wellbore, the wellbore having a wellbore axis;

d. an elevator assembly configured to engage a first tubular segment; and

,

e. a clamp assembly configured to move the first tubular segment toward the drive shaft of the first tubular rotational device;

wherein the first tubular rotational device is capable of rotating and lifting the 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 the plurality of booms are configured to move each of the plurality of tubular rotational devices simultaneously in an axis perpendicular to the wellbore axis.

3. The rig of claim 1, wherein the plurality of booms are capable of moving the 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 one of the first tubular segment and the second 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 first tubular segment is a pipe.

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

8. The rig of claim 1, wherein the first tubular segment is a pipe.

9. The rig of claim 1, wherein the first tubular rotational device is atop drive.

10. The rig of claim 1, wherein the plurality of booms are configured to move relative to the derrick assembly in the horizontal direction.

11. The rig of claim 1, further comprising a lifting assembly coupled to the rail and the plurality of booms.

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

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

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

a. a plurality of tubular rotational devices, including at least a first tubular rotational device and at least a second tubular rotation device, wherein the first tubular rotation device and the second tubular rotation device each includes a drive shaft;

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 booms, including at least a first boom and a second boom, wherein the first boom is operatively connected to at least the first tubular rotational device, wherein the second boom is operatively connected to at least the second tubular rotational device, wherein the first boom is capable of moving the first tubular rotational device vertically inline with the wellbore while the second boom is capable of independently moving the second tubular rotational device vertically out of alignment with the wellbore, wherein the first tubular rotational device is capable of rotating and lifting the 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;

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

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

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

iv. lowering the first tubular segment into the wellbore;

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

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

vii. 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

viii. repeating at least steps i-iv for additional tubular segments;

further comprising preventing a gas from the wellbore from venting into the atmosphere by employing a check valve operatively connected to one of the first tubular segment and the second tubular segment, wherein the check valve is opened by engaging one of the first tubular rotational device and the second tubular rotational device to whichever of the first tubular segment and the second tubular segment to which the check valve is connected.

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

a. a plurality of tubular rotational devices, including at least a first tubular rotational device and at least a second tubular rotation device, wherein the first tubular rotation device and the second tubular rotation device each includes a drive shaft;

b. a derrick assembly for supporting the plurality of tubular rotational devices and a plurality of booms; and

c. wherein the plurality of booms include at least a first boom and a second boom, wherein the first boom is operatively connected to at least the first tubular rotational device, wherein the second boom is operatively connected to at least the second tubular rotational device, wherein the first boom is capable of moving the first tubular rotational device vertically inline with a single wellbore while the second boom is capable of independently moving the second tubular rotational device vertically out of alignment with the wellbore, wherein the plurality of booms are slidably disposed in a horizontal direction along a rail proximate an opening of the wellbore to move each of the plurality of tubular rotational devices and toward the wellbore and away from the wellbore, the wellbore having a wellbore axis,

d. an elevator assembly configured to engage a first tubular segment; and

,

e. a clamp assembly configured to move the first tubular segment toward the drive shaft of the first tubular rotational device;

wherein the first tubular rotational device is capable of rotating and lifting the 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;

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

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

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

iv. lowering the first tubular segment into the wellbore;

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

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

vii. 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

viii. repeating at least steps i-iv for additional tubular segments;

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

16. The method of claim 15, wherein the drilling fluid is subsequently diverted from the fluid passageway during a connection operation wherein the first tubular segment is being connected to the second tubular segment.

17. The method of claim 16, wherein upon connecting the first tubular segment to the second tubular segment, the drilling fluid is diverted back to the fluid passageway.

18. The method of claim 16, wherein the step of diverting the drilling fluid comprises diverting the drilling fluid to a storage container.

19. The rig of claim 15, further comprising a lifting assembly coupled to the rail and the plurality of booms.