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Drilling Safely &
Reducing Downtime in
GOM Loop Currents
May 2015
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Gulf of Mexico Loop CurrentsAn Explanation
Loop Current
• A warm ocean current that flows northward between Cuba and the Yucatan Peninsula, moves northward in the GOM, loops east and south before exiting to the east through the Florida Straits
• Reaches maximum flows of 5 knots
Eddy Current
• A “loop current ring” that separates from the loop current somewhat randomly
• Swirling at up to 3.9 knots, they drift west at speeds of 2 to 5 kilometers per day until they bump into the Texas / Mexico coast
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Implications
Gulf of Mexico Loop Currents
“The Loop Current caused 13 deepwater rigs to be sidelined at one point or another during the quarter”
– Barron’s 2014
“The strong current has completely shut down operations as the drilling risers, pushed hard by the currents, have exceeded their environmental limits and in at least one case, required a rig to unlatch from the BOP on the sea floor.”
– gCaptain 2014
“Chevron's Big Foot TLP platform, whose sailouthad been delayed for months by the GOM loop current, is waiting offshore to head to its final destination due to further effects from same the ocean pattern.”
– Upstream 2015
Wellhead & Conductor Integrity
•Wellhead and conductor system subjected to cyclic lateral loads from drilling riser, BOP and vessel motions driven by environmental conditions
Implications
•Loop Current events can accelerate the fatigue damage of the wellhead, conductor, and riser system.
•High levels of fatigue accumulation can make workoveroperations unsafe and reduce asset and production life
Operating Windows
•Drilling operations confined by critical parameters such as flex joint angles, telescopic joint stroke, tension, & BOP motion
Implications
•When operating windows are exceeded this causes uncertainties regarding asset integrity bringing a greater likelihood of operational HSE issues and Non-Profitable Time
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The Solution
A Pulse real-time Drilling Riser Monitoring
System (DRMS) that assist with
operational decision making to make
smarter decisions and reduce non-
productive time
• Supports drill / no drill decisions in harsh
environmental conditions
• Tracks fatigue accumulation of critical
components essential for asset life
extension
• Real-time KPI’s (Key Performance
Indicators)
DRMS - Safer Operations & Reduce Overall Drilling Costs
Drilling Riser vs. Diverter Housing
(2 knot current)
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System Schematic
Real-Time DRMS
Wireless or
Hardwired
communicationReal-time KPI’s ensure safe
and efficient drilling ops.
*Optional
*Optional
*Optional
*Optional
*Optional
*Required
(min. 3)
*Required
Wellhead and Conductor
fatigue life accumulation is
tracked for the life of field.
Track Riser,
LMRP, & BOP
Fatigue
Accumulation
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Situation Awareness through Real-Time Data and KPI’s
Real-Time Drilling Optimization
Real-Time Instrumentation Data Feed
• Allows an overall view of the system structural response
• Allows trends and anomalies to be visualized
• Data is stored and can be transmitted to base
Real-Time KPI’s
• Pre-analysis of well, vessel, and equipment performance specifications are fed into software to enable customized traffic light KPI indicators
• Rig crew can easily know when something is wrong and proper risk mitigation measures can be taken
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Increasing ROI by Reducing Non-Profitable Time (NPT)
Real-Time DRMS
Deepwater Well Costs vs. Real-Time DRMS
•Average deepwater rig costs are $500k/day*
•Real-Time DRMS have a per rig annualized cost of $400k – $1 million per year to operate depending on complexity.
•Typical payback for the DRMS is achieved by saving as few as 1 day of rig time.
Case Study
•Client without a real-time DRMS came to us in the midst of high loop current events in which they shut down rig ops and needed measured wellhead fatigue data to resume operations or disconnect.
•We were only able to instrument the Telescopic Joint (TJ) and could not deploy sensors subsea to gather measured BOP motion data due to the high currents.
•The rig had 10+ days of NPT due to relying on overly conservative analysis prior to our arrival. Actual time saved was 4 days after analysis of our measured TJ data.
•If the Client had a real-time DRMS they could have known the actual fatigue within minutes and resumed operations based on further analysis.
-150%
-100%
-50%
0%
50%
100%
150%
200%
250%
300%
350%
1 24 47 70 93
Rig Time Saved (Hours)
REAL TIME DRMS - RETURN ON INVESTMENT
Payback achieved
with <1 day of rig
time saved.
* RigLogix April 2015
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Summary of Business Case for Real-Time DRMS
Real-Time DRMS
Business Objectives No Real-Time MonitoringWith DrillASSURE™ Real-Time
DRMS
Reduce Cost Per Well Drilled /
Decrease Number Of Days To Drill A
Well
Mitigation measures are REACTIVE
and often leads to NPT when
operation stops to assess situation
and perform analysis. Ex. “Loop
Currents”
Allows a PROACTIVE response to
integrity issues. KPI indicators give
quick visual “Go-No Go” to Rig Ops
Team.
No Harm To Environment, Personnel,
Or Company Reputation
No real time feedback to proactively
prevent an undesirable event such as
wellhead, riser, or conductor failure.
Real-Time feedback can be used to
proactively detect and mitigate
undesirable events. Helps to address
any regulatory scrutiny by showing
due diligence.
Asset Life ExtensionNo insight into wellhead fatigue life
utilization and risk/uncertainty
increases as asset ages.
Historical record of wellhead integrity
can be captured over its life cycle.
This can result in asset life
optimization and maximum return on
investment.
Every hour saved on an offshore operation is a savings of $20,000 to $50,000 per hour.
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Real-Time DRMS
Contact Us
Pulse Structural MonitoringPhone: +1 [email protected]://www.pulse-monitoring.com
Questions?