Office Action 1: Notice of Allowance (2024-10-23)

CLAIMS:
CLAIMS

What is claimed is:

1\. A device for performing a mechanical operation on a wireline, the device comprising:a motor;
a gear train coupled to the motor, the gear train including a first rotational output and a second rotational output, the first and second rotational outputs having different rotational speeds relative to each other;
a fluid pump coupled to both the first and second rotational outputs of the gear train, the fluid pump comprising:
a pump housing coupled to the first rotational output of the gear train, and a pump input coupled to the second rotational output of the gear train; and
a milling bailer coupled to the housing of the fluid pump and configured to rotate with the fluid pump housing, the milling bailer comprising:
a bailer portion shaped to intake fluid proximate a distal end of the bailer portion and allow the fluid to flow through a filter and through the fluid pump; and
a milling face proximate the distal end of the bailer portion, the milling face comprising at least one bit for milling and configured to perform a milling operation while fluid is flowing through the bailer portion.

2\. The device of claim 1, wherein the gear train comprises a three-stage planetary gear box comprising a sun gear, at least one planet gear coupled to the sun gear, and a planetary carrier gear coupled to the at least one planet gear.

3\. The device of claim 2, wherein the first rotational output of the gear train is coupled to the sun gear of the gear box and wherein the second rotational output of the gear train is coupled to the planetary carrier gear of the gear train.

4\. The device of claim 2, wherein the sun gear and planetary carrier gear rotate in a same direction.

5\. The device of claim 2, wherein the sun gear and the planetary carrier gear rotate in opposite directions.

6\. The device of claim 1, wherein the gear train is driven by a single input from the motor.

7\. The device of claim 1, wherein the fluid pump is driven based on the rotational difference between the first and second rotational outputs.

8\. The device of claim 1, wherein the distal end of the bailer portion comprises an aperture in the milling face that allows the fluid to enter an interior portion of the bailer portion.

9\. The device of claim 1, wherein the device further comprises a wireline cable head that receives the wireline and securely couples the device to the wireline.

10\. A method of simultaneous milling and debris collection, the method comprising:providing a tool, the tool comprising:
a motor;

a gear train coupled to the motor, the gear train including a first rotational output and a second rotational output, the first and second rotational outputs having different rotational speeds relative to each other;
a fluid pump coupled to both the first and second rotational outputs of the gear train, the fluid pump comprising:
a pump housing coupled to the first rotational output of the gear train, and a pump input coupled to the second rotational output of the gear train; and a milling bailer coupled to the housing of the fluid pump and configured to rotate with the fluid pump housing, the milling bailer comprising:
a bailer portion shaped to intake fluid proximate a distal end of the bailer portion and allow the fluid to flow through a filter and through the fluid pump; and a milling face proximate the distal end of the bailer portion, the milling face comprising at least one bit for milling and configured to perform a milling operation while fluid is flowing through the bailer portion;
lowering the tool down a well using the wireline,
positioning the tool such that the milling face is in contact with a surface to be milled; and operating the motor such that the milling bailer rotates, causing the milling face to mill the surface while fluid flows through the bailer portion to the fluid pump.

11\. The method of claim 10, wherein the gear train comprises a three-stage planetary gear box comprising a sun gear, at least one planet gear coupled to the sun gear, and a planetary carrier gear coupled to the at least one planet gear.

12\. The method of claim 11, wherein the first rotational output of the gear train is coupled to the sun gear of the gear box and wherein the second rotational output of the gear train is coupled to the planetary carrier gear of the gear train.

13\. The method of claim 11, wherein the sun gear and planetary carrier gear rotate in a same direction.

14\. The method of claim 11, wherein the sun gear and the planetary carrier gear rotate in opposite directions.

15\. The method of claim 10, wherein the gear train is driven by a single input from the motor.

16\. The method of claim 10, wherein the fluid pump is driven based on the rotational difference between the first and second rotational outputs.

17\. The method of claim 10, wherein the distal end of the bailer portion comprises an aperture in the milling face that allows the fluid to enter an interior portion of the bailer portion.

18\. The method of claim 10, wherein the device further comprises a wireline cable head that receives the wireline and securely couples the device to the wireline.

19\. The method of claim 10, further comprising retrieving the tool from the well by pulling the tool up by the wireline.

20\. The method of claim 19, further comprising cleaning the bailer portion to remove debris collected within the bailer portion.

OFFICE ACTION:
DETAILED ACTION
Notice of Pre-AIA  or AIA  Status
The present application, filed on or after March 16, 2013, is being examined under the first inventor to file provisions of the AIA .
Allowable Subject Matter
Claims 1-20 allowed.
The following is an examiner’s statement of reasons for allowance:
The Examiner agree with the conclusion of the Written Opinion of the International Searching Authority regarding PCT/US2023/016239 dated July 14, 2023 that the claims are allowable.
In addition to references cited by the PCT WO, the examiner found US 20200300049 A1 to Edvardsen, and US 20190257165 A1 to Toge, both are in the same field as the current application.
US 20200300049 A1 to Edvardsen discloses 1. A device 200/1 for performing a mechanical operation on a wireline 160, the device comprising:
a motor 6;
a gear train 41 coupled to the motor (Figure 1b), the gear train including a first rotational output;
a fluid pump 5 coupled to both the first rotational outputs of the gear train, the fluid pump comprising:
a pump input coupled to the second rotational output of the gear train; and
a milling bailer 71 coupled to the housing of the fluid pump, the milling bailer comprising:
a bailer portion shaped to intake fluid proximate a distal end of the bailer portion and allow the fluid to flow through a filter 73 and through the fluid pump; and
a milling face 2 proximate the distal end of the bailer portion, the milling face comprising at least one bit for milling and configured to perform a milling operation while fluid is flowing through the bailer portion.(Figure 1)
However Edvardsen fails to disclose the gear train including a  second rotational output, the first and second rotational outputs having different rotational speeds relative to each other; the fluid pump  coupled to both the first and second rotational outputs of the gear train, a pump housing coupled to the first rotational output of the gear train,
US 20190257165 A1 to Toge discloses 1. A device for performing a mechanical operation on a wireline 19, the device comprising:
a motor 31;
a gear train coupled to the motor [0079], the gear train including a first rotational output
a fluid pump 6 coupled to both the first outputs of the gear train, the fluid pump comprising:
a pump input coupled to the first rotational output of the gear train; and
a milling bailer 5 coupled to the housing of the fluid pump, the milling bailer comprising:
a bailer portion shaped to intake fluid proximate a distal end of the bailer portion and allow the fluid to flow through a filter 7 and through the fluid pump 3; and
a milling face  [0079] proximate the distal end of the bailer portion, the milling face comprising at least one bit  36 for milling and configured to perform a milling operation while fluid is flowing through the bailer portion.
However Toge fails to disclose the gear train including a second rotational output, the first and second rotational outputs having different rotational speeds relative to each other; the fluid pump  coupled to both the first and second rotational outputs of the gear train, a pump housing coupled to the first rotational output of the gear train
None of the prior art cited by the PCT, nor found the Examiner, disclose the limitations of “the gear train including a first rotational output and a second rotational output, the first and second rotational outputs having different rotational speeds relative to each other;
a fluid pump coupled to both the first and second rotational outputs of the gear train, the fluid pump comprising:
a pump housing coupled to the first rotational output of the gear train, and
a pump input coupled to the second rotational output of the gear train; and
a milling bailer coupled to the housing of the fluid pump and configured to rotate with the fluid pump housing”
It would not have been obvious to one of ordinary skill in the art to modify any of the cited prior art to add the missing limitations and arrive at the claimed invention.
Any comments considered necessary by applicant must be submitted no later than the payment of the issue fee and, to avoid processing delays, should preferably accompany the issue fee.  Such submissions should be clearly labeled “Comments on Statement of Reasons for Allowance.”
Conclusion



CITED REFERENCE SUMMARIES: Ref US20120211229A1: Claims:
A method of cleaning a tubular string disposed in a wellbore, comprising: connecting a cable to a BHA, the BHA comprising a motor and a cleaner; supplying a power signal to the BHA through the cable, thereby operating the motor to rotate the cleaner; deploying the BHA into the tubular string and the wellbore using the cable; and cleaning a deposit from an inner surface of the tubular string using the rotating cleaner.
connecting a cable to a BHA, the BHA comprising a motor and a cleaner;
supplying a power signal to the BHA through the cable, thereby operating the motor to rotate the cleaner;
deploying the BHA into the tubular string and the wellbore using the cable; and
cleaning a deposit from an inner surface of the tubular string using the rotating cleaner.
The method of claim 1 , wherein: the wellbore is live, tubular string is a production string, and the BHA is deployed also using a lubricator.
the wellbore is live,
tubular string is a production string, and
the BHA is deployed also using a lubricator.
The method of claim 1 , wherein: the BHA further comprises an anti-rotation guide and a tractor, and the motor also operates the tractor to propel the BHA along the tubular string.
the BHA further comprises an anti-rotation guide and a tractor, and
the motor also operates the tractor to propel the BHA along the tubular string.
The method of claim 1 , wherein the cleaner comprises a first set of brushes disposed therearound and a first set of scrapers disposed therearound.
The method of claim 4 , wherein: the cleaner further comprises a second set of brushes and a second set of scrapers, the BHA further comprises: a first speed reducer operable to rotate the first sets at a first speed substantially less than a rotational speed of the drive shaft; and a second speed reducer operable to counter-rotate the second sets relative to the drive shaft and the first sets at the first speed.
the cleaner further comprises a second set of brushes and a second set of scrapers,
the BHA further comprises: a first speed reducer operable to rotate the first sets at a first speed substantially less than a rotational speed of the drive shaft; and a second speed reducer operable to counter-rotate the second sets relative to the drive shaft and the first sets at the first speed.
a first speed reducer operable to rotate the first sets at a first speed substantially less than a rotational speed of the drive shaft; and
a second speed reducer operable to counter-rotate the second sets relative to the drive shaft and the first sets at the first speed.
The method of claim 1 , wherein: the power signal is DC, and the BHA further comprises a power conversion module operable to receive the power signal and supply a second power signal to the motor.
the power signal is DC, and
the BHA further comprises a power conversion module operable to receive the power signal and supply a second power signal to the motor.
The method of claim 1 , further comprising swabbing the tubular string using the BHA after cleaning.
The method of claim 7 , wherein: a first length of the tubular string is cleaned, and the method further comprises: swabbing the first length of the production tubing after cleaning the first length; and cleaning a second length of the production tubing after swabbing the first length.
a first length of the tubular string is cleaned, and
the method further comprises: swabbing the first length of the production tubing after cleaning the first length; and cleaning a second length of the production tubing after swabbing the first length.
swabbing the first length of the production tubing after cleaning the first length; and
cleaning a second length of the production tubing after swabbing the first length.
The method of claim 1 , further comprising spraying the cleaner with a fluid.
The method of claim 9 , wherein the fluid is injected through the cable to the BHA.
The method of claim 9 , wherein: the BHA is connected to a coiled tubing string, and the fluid is injected through an annulus formed between the cable and the coiled tubing to the BHA.
the BHA is connected to a coiled tubing string, and
the fluid is injected through an annulus formed between the cable and the coiled tubing to the BHA.
A bottom hole assembly (BHA) for cleaning a tubular string disposed in a wellbore, comprising: a cablehead; a drive shaft; a submersible electric motor operable to rotate the drive shaft; a cleaner rotationally connected to the drive shaft; an anti-rotation guide operable to engage the tubular string and connected to a housing of the motor; a tractor rotationally connected to the drive shaft and operable to propel the BHA along the tubular string; and a power conversion module operable to receive a DC power signal from the cablehead and supply a second power signal to the motor.
a submersible electric motor operable to rotate the drive shaft;
a cleaner rotationally connected to the drive shaft;
an anti-rotation guide operable to engage the tubular string and connected to a housing of the motor;
a tractor rotationally connected to the drive shaft and operable to propel the BHA along the tubular string; and
a power conversion module operable to receive a DC power signal from the cablehead and supply a second power signal to the motor.
The BHA of claim 12 , wherein the tractor comprises a polymer screw operable to engage an inner surface of the tubular string.
The BHA of claim 12 , wherein the cleaner comprises a first set of brushes disposed therearound and a first set of scrapers disposed therearound
The BHA of claim 14 , wherein: the cleaner further comprises a second set of brushes and a second set of scrapers, the BHA further comprises: a first speed reducer operable to rotate the first sets at a first speed substantially less than a rotational speed of the drive shaft; and a second speed reducer operable to counter-rotate the second sets relative to the drive shaft and the first sets at the first speed.
The BHA of claim 15 , further comprising a third speed reducer operable to rotate the tractor at a second speed substantially less than the first speed.
The BHA of claim 12 , wherein: the drive shaft has a bore, and the BHA further comprises: a hydraulic swivel in fluid communication with the bore, and an injector in fluid communication with the bore and operable to spray the cleaner with a fluid.
the drive shaft has a bore, and
the BHA further comprises: a hydraulic swivel in fluid communication with the bore, and an injector in fluid communication with the bore and operable to spray the cleaner with a fluid.
a hydraulic swivel in fluid communication with the bore, and
an injector in fluid communication with the bore and operable to spray the cleaner with a fluid.
The BHA of claim 17 , further comprising: a coiled tubing head; and a fluid conduit in communication with the coiled tubing head and the hydraulic swivel.
a coiled tubing head; and
a fluid conduit in communication with the coiled tubing head and the hydraulic swivel.
A downhole assembly, comprising: the BHA of 12 ; and a cable having two or less conductors and a strength sufficient to support the BHA.
the BHA of 12 ; and
a cable having two or less conductors and a strength sufficient to support the BHA.
The downhole assembly of claim 19 , wherein the cable has a fluid conduit.
Ref US20140326510A1: Claims:
A wireline drilling system comprising a drilling assembly configured to drill a wellbore, and an integral cuttings removal system arranged to collect and store cuttings displaced by the drilling assembly for transport to the surface, the integral cuttings removal system comprising a cuttings basket to store the drilling cuttings and a rotatable screw member operable to carry drilling cuttings along at least a portion of the integral cuttings removal system, and a pump configured to circulate fluid between the drilling assembly and the rotatable screw member via one or more inlets.
A wireline drilling system according to claim 1 , wherein the rotatable screw member is operable to transport cuttings to the cuttings basket.
A wireline drilling system according to claim 1 , wherein the rotatable screw member is operable to distribute cuttings within the cuttings basket.
A wireline drilling system according to claim 1 , wherein the rotatable screw member comprises a first portion and a second portion, the first portion arranged to distribute cuttings within the cuttings basket, and the second portion arranged to transport cuttings to the cuttings basket.
- 8 . (canceled)
A wireline drilling system according to claim 4 , wherein the cuttings removal system comprises one or more inlets positioned at or near the second portion of the screw member.
A wireline drilling system according to claim 9 , wherein the pump is configured for forward circulation.
A wireline drilling system according to claim 1 , wherein the wireline drilling system further comprises a tractor configured to selectively engage the wellbore and produce an axial displacement of the wireline drilling system within the wellbore.
A wireline drilling system according to claim 13 , wherein the tractor is configured to displace the wireline drilling system at two or more different speeds.
A wireline drilling system according to claim 13 , wherein the tractor is configured to provide weight on bit to urge the drilling assembly against a formation being drilled.
- 19 . (canceled)
A wireline drilling system according to claim 13 , wherein the wireline drilling system comprises one or more articulated portions to permit longitudinal deflection of the wireline drilling system.
A wireline drilling system according to claim 13 , wherein the tractor is coupled to the cuttings removal system by a flexible elongate member which provides an axial separation therebetween.
A wireline drilling system according to claim 1 , wherein the cuttings basket comprises at least one sensor responsive to a quantity of cuttings contained therein.
A wireline drilling system according to claim 24 , wherein the at least one sensor is configured to determine a formation composition based on the resistivity of cuttings in the cuttings basket.
- 30 . (canceled)
A wireline drilling system according to claim 1 , wherein the wireline drilling system further comprises an adjustable bend arranged to effect an off-axis deviation of the drilling assembly.
A wireline drilling system according to claim 31 , wherein the adjustable bend is controllable to control a drilling direction.
A wireline drilling system according to claim 1 , wherein the wireline drilling system further comprises one or more sensors selected from the group comprising; a calliper sensor to determine the diameter of the wellbore; an orientation sensor to determine the orientation of the drilling assembly; a pressure sensor to determine the annular pressure in the wellbore; an RPM sensor to determine the speed of rotation of the drill bit; a torque sensor to determine the torque applied to the drill bit; and a weight-on-bit sensor to determine the weight-on-bit.
A wireline drilling system according to claim 34 , wherein the wireline drilling system further comprises a control module configured to control drilling operations responsive to information received from the one or more said sensors.
A method of drilling a wellbore, the method comprising: providing a wireline drilling system comprising a drilling assembly and an integral cuttings removal system, the integral cuttings removal system comprising a cuttings basket and a rotatable screw member; running the wireline drilling system into the wellbore; drilling a formation; operating a pump of the wireline drilling system to circulate fluid between the drilling assembly and the rotatable screw member; operating the rotatable screw member to carry drilling cuttings along at least a portion of the integral cuttings removal system; and collecting cuttings displaced by the drilling assembly.
providing a wireline drilling system comprising a drilling assembly and an integral cuttings removal system, the integral cuttings removal system comprising a cuttings basket and a rotatable screw member;
running the wireline drilling system into the wellbore;
drilling a formation;
operating a pump of the wireline drilling system to circulate fluid between the drilling assembly and the rotatable screw member;
operating the rotatable screw member to carry drilling cuttings along at least a portion of the integral cuttings removal system; and
collecting cuttings displaced by the drilling assembly.
A method of drilling according to claim 36 , further comprising retrieving the wireline drilling system, at least once, to dispose of the collected cuttings.
- 40 . (canceled)
A method of drilling according to claim 36 , further comprising determining a formation composition based on the resistivity of the contents of the cuttings basket.
A method of drilling according to claim 36 , further comprising rotating the screw member to transport drilling cuttings to the cuttings basket.
A method of drilling according to claim 36 , further comprising rotating the screw member within the cuttings basket to distribute cuttings within the cuttings basket.
A method of drilling according to claim 36 , further comprising circulating fluid between the drilling assembly and the cuttings removal system via one or more inlets.
- 48 . (canceled)
A method of drilling according to claim 36 , further comprising producing an axial displacement using a tractor of the wireline drilling system to provide weight on bit to urge the drilling assembly against a formation being drilled.
A method of drilling according to claim 36 , further comprising powering up a tractor of the wireline drilling system at an intermediate position in the wellbore to determine a maximum push force.
A method of drilling according to claim 36 , further comprising fracturing a formation being drilled by resonating or oscillating the drill bit during drilling.
- 57 . (canceled)
A method of drilling according to claim 36 , further comprising controlling the drilling direction to drill open hole laterals from the wellbore.
A method of drilling according to claim 36 , further comprising ceasing drilling operations or reciprocating the wireline drilling system off bottom responsive to information received from one or more sensors.
A method of drilling according to claim 60 , further comprising resuming operations and/or bottomhole placement or maintaining cessation and/or withdrawal responsive to changes or lack of changes in the information received from the one or more sensors.
Ref US20180058146A1: Claims:
- 15 . (canceled)
A downhole tool string for performing an operation downhole in a well having a well fluid, the downhole tool string having an outer diameter and comprising: a motor unit having a rotational shaft rotating with a rotational motor speed, a gear section, an operational tool having a tool shaft rotated by the gear section at a lower rotational speed than that of the rotational shaft, and a pump unit having a rotor shaft rotated by the motor unit for providing fluid around or past the operational tool,
a motor unit having a rotational shaft rotating with a rotational motor speed,
an operational tool having a tool shaft rotated by the gear section at a lower rotational speed than that of the rotational shaft, and
a pump unit having a rotor shaft rotated by the motor unit for providing fluid around or past the operational tool,
wherein the pump unit is arranged between the gear section and the operational tool.
A downhole tool string according to claim 16 , wherein the outer diameter of the downhole tool string is less than 54 mm.
A downhole tool string according to claim 16 , wherein the pump unit comprises a pump inlet in fluid communication with the well fluid.
A downhole tool string according to claim 16 , wherein the gear section comprises a reduction gear assembly having a first end part closest to the motor unit, the first end part engaging the rotational shaft, and the reduction gear assembly further having a second end part rotating at a lower speed than the rotational shaft.
A downhole tool string according to claim 19 , wherein the reduction gear assembly has a through-bore through which the rotational shaft extends.
A downhole tool string according to claim 19 , wherein the second end part of the reduction gear assembly is connected to the tool shaft in a connection area.
A downhole tool string according to claim 19 , wherein the reduction gear assembly is a planetary gearing assembly.
A downhole tool string according to claim 16 , wherein the rotor shaft of the pump unit has a pump through-bore through which the tool shaft extends.
A downhole tool string according to claim 19 , wherein the gear section comprises a transition gear assembly arranged at the second end part of the reduction gear assembly, the transition gear assembly comprising a transition shaft having a first shaft end having a first toothed part, and a second shaft end having a second toothed part, the first toothed part engaging the rotational shaft and the second toothed part engaging the rotor shaft, so that the rotation of the rotational shaft is transferred to the rotor shaft.
A downhole tool string according to claim 24 , wherein the transition shaft has an un-toothed part between the first and second toothed parts, the un-toothed part bridging over the connection area.
A downhole tool string according to claim 24 , wherein the second end part of the reduction gear assembly comprises one or more cavity/ies in which the transition shaft(s) is/are arranged.
A downhole tool string according to claim 24 , wherein the transition shaft is arranged in the second end part of the reduction gear assembly.
A downhole tool string according to claim 24 , wherein the transition shaft rotates at a rotational speed being greater than that of the second end part of the reduction gear assembly.
A downhole tool string according to claim 28 , wherein the rotational shaft rotates at 5,000-10,000 rpm and the second end part of the reduction gear assembly rotates at 50-500 rpm, so that the operational tool is rotated at 50-500 rpm while the rotor shaft of the pump unit is rotated at 5,000-10,000 rpm.
A method for operating an operational tool and pump unit of a downhole tool string according to claim 16 by means of the rotational shaft of the motor unit, comprising: activating the motor unit to rotate the rotational shaft at a first rotation speed, rotating the first end part of the reduction gear assembly by means of the rotational shaft, reducing the rotations of the second end part to a second rotation speed, rotating the tool shaft by means of the second end part of the reduction gear assembly, rotating the transition shaft by means of the rotational shaft, rotating the rotor shaft of the pump unit by means of the transition shaft, and pumping fluid around or past the operational tool while the operational tool rotates.
activating the motor unit to rotate the rotational shaft at a first rotation speed,
rotating the first end part of the reduction gear assembly by means of the rotational shaft,
reducing the rotations of the second end part to a second rotation speed,
rotating the tool shaft by means of the second end part of the reduction gear assembly,
rotating the transition shaft by means of the rotational shaft,
rotating the rotor shaft of the pump unit by means of the transition shaft, and
pumping fluid around or past the operational tool while the operational tool rotates.
Ref US20190257165A1: Claims:
Collecting device for displacement in a tubing, the collecting device is extended in shape with a longitudinal axis, the collecting device forms a leading portion with an entrance and an end portion; the collecting device comprises: a wall extending from the leading portion to the end portion; a collecting chamber formed 
[Truncated to input limit]