Drilling Optimization Reduced Nonproductive Time in Canadian ...
Case History
Drilling Optimization Reduced Nonproductive Time in Canadian Offshore Field Baker Hughes saved approximately USD 10.4 million on four-well project
Benefits Saved
an average of 10 days per well
Reduced
costs per well by USD 2.58 million
Background and challenges Terra
Nova field, offshore Newfoundland, Canada
Four-well
project
stuck pipe and bottomhole assembly incidents due to wellbore instability
An operator wanted to reduce nonproductive time (NPT) caused by wellbore instability on four wells being drilled in the Terra Nova field in offshore Newfoundland, Canada. NPT on previous wells in the field had ranged from 2 to 860 hours per well due to wellbore instability. On eight of those wells, NPT had totaled 1,922 hr with an associated cost of almost USD 22 million.
Eliminate
Run
logs and casing without problems
Improve
borehole quality
Optimize
rate of penetration, wellpath design, and trajectories
Reduce
trip hours, reaming, washing, and hole conditioning, leading to fewer drilling days
Baker Hughes solution and results Used
logging-while-drilling pressure services to monitor equivalent circulating density (ECD) and vibration
Evaluated
overall wellbore stability and hole cleaning by reviewing hookloads and torque and drag
Working closely with the operator, the Baker Hughes Drilling Optimization Solutions team developed a drilling optimization plan that incorporated geomechanical modeling for two development areas in the field. This plan was based on the post-well review of data and operations from previous offset wells. It included a comprehensive evaluation of depth-based drilling data, daily drilling reports, mud reports, caliper and image logging data, and petrophysical log data. The Drilling Optimization Solutions team refined and closely monitored drilling parameters and constraints as required
for critical sections based upon trend analysis of recorded-whiledrilling data, and cuttings/cavings analysis. Operating improvements on the first four wells drilled as part of the new plan have resulted in total NPT of just 2.5 hr. The operator’s savings was approximately USD 10.4 million, achieved through the more efficient use of drilling, casing, coring, and logging time. The average cost savings per well was USD $2.58 million.
Optimized
mud weight and properties, hydraulics, and surge and swab operating regimes
Provided
real-time analysis of ECD, cuttings, and friction factor analysis while drilling
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.
© 2013 Baker Hughes Incorporated. All rights reserved. 37400 07/2013
Drilling Optimization Reduced Nonproductive Time in Canadian Offshore Field Baker Hughes saved approximately USD 10.4 million on four-well project
Benefits Saved
an average of 10 days per well
Reduced
costs per well by USD 2.58 million
Background and challenges Terra
Nova field, offshore Newfoundland, Canada
Four-well
project
stuck pipe and bottomhole assembly incidents due to wellbore instability
An operator wanted to reduce nonproductive time (NPT) caused by wellbore instability on four wells being drilled in the Terra Nova field in offshore Newfoundland, Canada. NPT on previous wells in the field had ranged from 2 to 860 hours per well due to wellbore instability. On eight of those wells, NPT had totaled 1,922 hr with an associated cost of almost USD 22 million.
Eliminate
Run
logs and casing without problems
Improve
borehole quality
Optimize
rate of penetration, wellpath design, and trajectories
Reduce
trip hours, reaming, washing, and hole conditioning, leading to fewer drilling days
Baker Hughes solution and results Used
logging-while-drilling pressure services to monitor equivalent circulating density (ECD) and vibration
Evaluated
overall wellbore stability and hole cleaning by reviewing hookloads and torque and drag
Working closely with the operator, the Baker Hughes Drilling Optimization Solutions team developed a drilling optimization plan that incorporated geomechanical modeling for two development areas in the field. This plan was based on the post-well review of data and operations from previous offset wells. It included a comprehensive evaluation of depth-based drilling data, daily drilling reports, mud reports, caliper and image logging data, and petrophysical log data. The Drilling Optimization Solutions team refined and closely monitored drilling parameters and constraints as required
for critical sections based upon trend analysis of recorded-whiledrilling data, and cuttings/cavings analysis. Operating improvements on the first four wells drilled as part of the new plan have resulted in total NPT of just 2.5 hr. The operator’s savings was approximately USD 10.4 million, achieved through the more efficient use of drilling, casing, coring, and logging time. The average cost savings per well was USD $2.58 million.
Optimized
mud weight and properties, hydraulics, and surge and swab operating regimes
Provided
real-time analysis of ECD, cuttings, and friction factor analysis while drilling
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.
© 2013 Baker Hughes Incorporated. All rights reserved. 37400 07/2013
