Utilizing proNova’s Management Scoreboard to Monitor the
Performance of your Entire Rig Fleet
Table of Contents
proNova’s Complete Process Loop & Setup Requirements
Setting the Scene Typical Time Depth Chart of a Well
Common Definitions
Conventional IADC Reports vs. proNova’s Report
Drilling Performance Reporting
Real Case – Three Wells Critiqued
Company Performance & Potential Savings
Showcasing a 2nd Data Set
Conclusion
‘You cannot
improve what
you cannot
measure’
proNova’s Complete Process Loop
A Seam-less Setup & Installation
Flat Time Reduction (80%)
Data Gathering Optimization
Reducing Invisible Lost Time
Optimizing Connection time, Circulation
Time, Wipe log, Back-reaming,
Cementing, Running Casing/Tubing, WL
Logging etc.
Drilling Time Reduction (20%)
Drilling Technical Limit
Batch Drilling
Pilot Hole Vs. Mother Hole
New Technology
** Red Colour Denotes Cost Optimization ** Green Colour Denotes Drilling Performance Enhancement
Setting the Scene Typical Time Depth Chart for a Well
Setting the Scene Some Common Definitions
The following terms will be used throughout the slides:
Weight to Weight Time: starts when the DS is lifted off-bottom & lasts until the string is on-bottom again
Weight to Slips Time: starts when the DS is lifted off-bottom until string is set in slips again
Slips to Weight Time: represents the time when the slips are removed until the DS is on bottom again
Slip to Slip Connection Time: represents the time in slips, specifically during drilling connections
Total Non-Drilling Time Per Stand: represents any time spent while drilling a stand when the DS is lifted
off-bottom, which includes all wellbore conditioning time & the Weight to Weight time.
Reaming: when pumps are on, there is rotation & block is moving up & down
Washing: when pumps are on, there is no rotation & block is moving up & down
Circulating: when pumps are on, but there is no block movement
Setting the Scene Conventional IADC Report vs. ‘Automated’ Daily Report
Setting the Scene Drilling Performance Reporting
T
ime
[0
- 6
0 m
in]
M
ea
su
red
De
pth
[m]
Time [00:00 – 24:00]
Bit Depth
Hole Depth
Data from a Real Case (3 Different Offshore Rigs)
proNova asked by the Operator to review 2 historical wells & one live well
Objective: Cost Optimization Initiatives Across the Organization
Basis of Engagement: No Cure-No Pay
……Workshop conducted with the rig providers……
What Justifies those big potential saving values?
Invisible Lost Time
Target: 1.88 min
10% 90% Target: 1.88
Savings Potential Definition
Fre
qu
en
cy
Duration
Best Practice
Step 1: Define Current Rig Efficiency
Step 2: Identify Exceptions
– Exceptional Short – Maybe taking Shortcuts
– Exceptional Long – Operational Problems
Step 3: Define Best Practice as Target for Future Ops.
Data from a Real Case (3 Different Offshore Rigs)
Concept - Histograms
Drilling Key Performance Indicators KPIs….
Comparing Crews
Time [00:00 – 24:00]
Slip to Slip Connection Time
Slip to Slip Connection Time
Sequence
[min
] [m
in]
Tim
e A
vg (
min
)
Drilling – Weight to Slip Time, Avg (min)
Drilling – Slip to Slip Time, Avg (min)
Drilling – Slip to Weight Time, Avg (min)
Rig 1 Rig 2
Drilling Key Performance Indicators KPIs….
Comparing Rigs
Key Performance Indicators – 2nd Data Set
Weight-to-Weight Connections and Non-Drilling Time per Stand were identified
for their repetition and durations as major contributors to drilling efficiency
Weight-to-Slips
Slips-to-Slips
Slips-to-Weight
Non-Drilling Time Per Stand
Rig Performance Reporting Realizing Improvements & Optimizing Costs
Initial efficiency improvements were measured once the data was made available at the rig-site
and safe targets were established and communicated.
Rig Performance Reporting
Daily reporting allows rig-site personnel and management to analyze crew performance
and identify lessons learned and facilitate knowledge sharing between crews, rigs and business units.
Res. A
R
es. B
R
es. C
Identifying Best-Safe-Practices
Discovered discrepancies in operational performance
revealed the need for standardization of routine activities.
Identifying Best-Safe-Practices
Changes to the directional surveying methods were implemented
to streamline the process of making connections.
Identifying Best-Safe-Practices
Results showed a reduction in off-bottom time while drilling and therefore an increased realized ROP.
Pad 2: Total Non-drilling Time per Stand, Avg (min)
Pad 1: Total Non-drilling Time per Stand, Avg (min)
Company Performance and Savings
New processes led to a significant reduction in time spent making drilling connections,
resulting in 5.78 days in savings on a 9-well pad.
Company Performance and Savings
Benchmarking performance from a previously drilled pad showed a 45-percent reduction in time
lost to off-bottom activities per stand drilled – an actual savings or more than 11 days.
Conclusion
Through a knowledge-sharing and information-gathering culture,
new processes were implemented and standardized
with an end result of significant company savings.
By sharing accountability to
increase performance through
a safety-driven culture,
routine operations become
more consistent
and rig efficiencies climb.
Company Savings continues to grow
as lessons-learned are shared
between BUs, rigs and crews.
Utilizing proNova’s Management Scoreboard to Monitor the
Performance of your Entire Rig Fleet