Talon 3D 6¾-in. PDC Drill Bit Drilled Lateral Section in ... AWS
Case History
Talon 3D 6¾-in. PDC Drill Bit Drilled Lateral Section in One Run in Haynesville Shale Play Baker Hughes decreased drilling time by 36 hours to deliver savings of more than $80,000
Benefits Reduced
drilling costs by minimizing slide time
Improved
penetration rates in horizontal lateral hole section
Increased
junk slot area to improve cleaning and reduce balling
Optimized
gauge to reduce bit walk
Well background and challenges Haynesville
Shale, Bossier Parish, Louisiana
Operators were actively drilling horizontal wells in the Haynesville shale play. The horizontal lateral hole section of these wells were typically between 4,000 ft and 5,000 ft and presented several drilling challenges such as bit, bottom hole assembly and hole cleaning in highly weighted mud at a shale under high pressure. Performance was also affected by the limited hydraulic and mechanical horsepower at the bit.
Baker Hughes to save time and money in a lateral section. This one-piece steel PDC bit offered superior directional control as well as increased junk slot area for enhanced hydraulic efficiency. Reduced slide time and improved penetration rates enabled the Talon 3D PDC bit to successfully drill an entire lateral section in one run, which increased the single-run footage by 53% and decreased drilling time by 36 hours. The Talon 3D PDC bit reduced drilling costs and saved the client more than $80,000 for the lateral section.
An operator chose the 6¾-in. Hughes Christensen Talon™ 3D Q405S highefficiency vector-accurate PDC bit from
Wells
with 4,000-ft to 5,000-ft lateral hole sections
Baker Hughes solution and results
11,000
6¾-in.
12,000
Hughes
Christensen patented polished cutters provided superior cutting efficiency and minimized cutter and bit balling
Drilled
entire lateral section in one run and decreased section drilling time by 36 hours
Increased
Lateral Section Cost / Foot Q405S
$26
Well1 13,000
Footage
Hughes Christensen Talon 3D Q405S High-Efficiency Vector-Accurate PDC bit
Lateral Section Performance Comparison
$30
Well 2
14,000
Well 3
15,000
Well 4
16,000
Well 5
$38 $54 $82 $100
Well 6
17,000 0
20
40
60
80
$31 $-
$20
$40
$60
$80
$100
ROP (ft/hr)
single-run footage by 53%
Saved
client more than $80,000 for the section
www.bakerhughes.com Disclaimer of Liability: This information is provided for general information purposes only and is believed to be accurate as of the date hereof; however, Baker Hughes Incorporated and its affiliates do not make any warranties or representations of any kind regarding the information and disclaim all express and implied warranties or representations to the fullest extent permissible by law, including those of merchantability, fitness for a particular purpose or use, title, non-infringement, accuracy, correctness or completeness of the information provided herein. All information is furnished “as is” and without any license to distribute. The user agrees to assume all liabilities related to the use of or reliance on such information. BAKER HUGHES INCORPORATED AND ITS AFFILIATES SHALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE.
© 2012 Baker Hughes Incorporated. All rights reserved. 34832
Talon 3D 6¾-in. PDC Drill Bit Drilled Lateral Section in One Run in Haynesville Shale Play Baker Hughes decreased drilling time by 36 hours to deliver savings of more than $80,000
Benefits Reduced
drilling costs by minimizing slide time
Improved
penetration rates in horizontal lateral hole section
Increased
junk slot area to improve cleaning and reduce balling
Optimized
gauge to reduce bit walk
Well background and challenges Haynesville
Shale, Bossier Parish, Louisiana
Operators were actively drilling horizontal wells in the Haynesville shale play. The horizontal lateral hole section of these wells were typically between 4,000 ft and 5,000 ft and presented several drilling challenges such as bit, bottom hole assembly and hole cleaning in highly weighted mud at a shale under high pressure. Performance was also affected by the limited hydraulic and mechanical horsepower at the bit.
Baker Hughes to save time and money in a lateral section. This one-piece steel PDC bit offered superior directional control as well as increased junk slot area for enhanced hydraulic efficiency. Reduced slide time and improved penetration rates enabled the Talon 3D PDC bit to successfully drill an entire lateral section in one run, which increased the single-run footage by 53% and decreased drilling time by 36 hours. The Talon 3D PDC bit reduced drilling costs and saved the client more than $80,000 for the lateral section.
An operator chose the 6¾-in. Hughes Christensen Talon™ 3D Q405S highefficiency vector-accurate PDC bit from
Wells
with 4,000-ft to 5,000-ft lateral hole sections
Baker Hughes solution and results
11,000
6¾-in.
12,000
Hughes
Christensen patented polished cutters provided superior cutting efficiency and minimized cutter and bit balling
Drilled
entire lateral section in one run and decreased section drilling time by 36 hours
Increased
Lateral Section Cost / Foot Q405S
$26
Well1 13,000
Footage
Hughes Christensen Talon 3D Q405S High-Efficiency Vector-Accurate PDC bit
Lateral Section Performance Comparison
$30
Well 2
14,000
Well 3
15,000
Well 4
16,000
Well 5
$38 $54 $82 $100
Well 6
17,000 0
20
40
60
80
$31 $-
$20
$40
$60
$80
$100
ROP (ft/hr)
single-run footage by 53%
Saved
client more than $80,000 for the section
www.bakerhughes.com Disclaimer of Liability: This information is provided for general information purposes only and is believed to be accurate as of the date hereof; however, Baker Hughes Incorporated and its affiliates do not make any warranties or representations of any kind regarding the information and disclaim all express and implied warranties or representations to the fullest extent permissible by law, including those of merchantability, fitness for a particular purpose or use, title, non-infringement, accuracy, correctness or completeness of the information provided herein. All information is furnished “as is” and without any license to distribute. The user agrees to assume all liabilities related to the use of or reliance on such information. BAKER HUGHES INCORPORATED AND ITS AFFILIATES SHALL NOT BE LIABLE FOR ANY DIRECT, INDIRECT, SPECIAL, PUNITIVE, EXEMPLARY OR CONSEQUENTIAL DAMAGES FROM ANY CAUSE WHATSOEVER INCLUDING BUT NOT LIMITED TO ITS NEGLIGENCE.
© 2012 Baker Hughes Incorporated. All rights reserved. 34832
