IADC DEC Technology Forum IOGP/IADC BOP Reliability Database Mark Siegmund Chairman: RAPID – S53 Oversight Committee
IADC DEC Technology Forum
IOGP/IADC BOP Reliability Database
Mark Siegmund
Chairman: RAPID – S53 Oversight Committee
IADC DEC Technology Forum
RAPID-S53 Overview
• Online subsea BOP performance reporting database developed by group
of seven offshore drilling contractors became operational in 2015.
• Database combined with IOGP/IADC efforts, now in third iteration of
Joint Industry Project with 14 contractors, 12 operators, and 3 OEMs.
• Latest phase branded as RAPID-S53 (Reliability & Performance
Information Database for Standard 53 well control equipment).
• Over 6000 event reports now in database.
• 700+ users from 29 participating companies accessing database
• Management & organizational support provided by IADC as Project
Coordinator.
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JIP Participating Companies
• Diamond Offshore
• Dolphin Drilling
• Ensco plc
• Maersk Drilling
• Noble Drilling
• Pacific Drilling
• Queiroz Galvão
• Ocean Rig
• Ocyan/Odebrecht
• Rowan Companies
• Seadrill
• Stena Drilling
• Transocean
• Vantage Drilling
• Anadarko
• BP
• Chevron
• CNOOC/Nexen
• Eni S.p.A
• Equinor
• ExxonMobil
• Hess
• Kosmos Energy
• Petrobras
• Shell
• Total SA
• Cameron
• Baker Hughes/GE
• NOV
Contractors OEMsOperators
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BOP Event Cause Designations
When Root Cause is known:• Design issue
• Documentation error
• Maintenance error
• Procedural error
• QA/QC manufacturing
• Wear and tear
When Root Cause is not known:• RCFA required (always used when there is a
loss of wellbore integrity)
• Assessment pending (e.g. used in the case
where stack is still subsea)
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A total of 2040 events were
reported by JIP members in
2017.
Of these, 1475 were
discovered with the BOP
Stack ‘Not In Operation’.
This reflects the very
positive fact that the bulk
of events occurred while
equipment was being
inspected, maintained and
tested prior to being put
into service.
1475 Not In Operation
Events
565 In Operation
Events
22 Stack Pull Events
2 Loss of Wellbore Integrity Events
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Drillship, 50
Semi-submersible,
25
Jack-up, 21
Platform, 6
102 total rig-years
Rig-Years of Operation by Rig Type - 2017
“Typical Rig”*
• 20 WCE events/year
• 14 Not in Operation
• 6 BOP in Operation
• 1 in 5 years – Stack pull
• 1 in 50 years – Loss of
Wellbore Integrity
*Composite example based on reports received in 2017.
BOP types and number of components vary significantly.
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Rig Type 2017 Number of rig-
years of operation
Number of reportable
components per rig
2017 Number of component-
years of operation
Dual-stack Drillship 26 4,200 109,200
Single-stack Drillship 24 2,900 69,600
Single-stack Semi-submersible 25 2,500 62,500
Jack-up Rigs 21 490 10,290
Platform Rigs 6 460 2,760
Totals 102 254,350
Distribution of 2017 BOP Stack & Control System Component-Years of Operation by Rig Type
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Sum of events associated with a component
Event Rate =
Sum of component-years for each component active during period
Event Rate as a Metric
0
10
20
30
40
50
60
70
80
0
0.02
0.04
0.06
0.08
0.1
0.12
0.14
Event
& S
tack-P
ull
Count
Event
Rate
Event Rate Event Count Stack-Pull Count
Highest Ranked BOP Stack Components by Event Rate
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Sum of events associated with a component
Event Rate =
Sum of component-years for each component active during period
Event Rate as a Metric
2 1 1 1 1 1 1 1 1 1
0
0.005
0.01
0.015
0.02
0.025
0.03
0.035
0.04
0.045
0
5
10
15
20
25
30
Event
Rate
Event
Count
& S
tack-P
ull
Count
Stack-Pull Event Count Event Count Event Rate
Controls System Related Components with 2017 Stack Pulls
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Initiatives in Development
• Applying cycle count data to aid in trend analysis and reliability
prediction.
• Currently collating field estimates of hours in service for
components where cycle count is more appropriate and cycle
counts are not available. This will be replaced by estimated cycle
counts for the applicable components.
• When actual cycle count is not known, an algorithm will be used to
estimate cycle count using date equipment was put in service and
the date of the event.
• The goal is to accumulate enough experience data to eventually
predict MTBF for certain components.
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Benefits realized by participants
• Monthly event review by Technical Reference Group provides
valuable opportunity to share information on events experienced.
• Common issues on similar equipment identified.
• Increased understanding by OEMs of problem areas needing
rectification.
• Improved procedures for hoses & fittings reduced leaks and
unplanned stack pulls.
• Refined RCFA process.
• Potential problems not previously seen can be anticipated.
• Increased efforts to improve product design for SPM valves, etc.
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Working with Regulators to Support Industry Compliance
• Modifications made to database facilitate
failure reporting by operators and contractors
to assist in compliance with the BSEE Well
Control Rule.
• Operators and OEMs both receive failure
reports.
• Agreement with BSEE that reports can be
forwarded directly to Bureau of Transportation
Statistics (BTS) - data repository for BSEE.
• Data reported directly to BTS protected by the
Confidential Information Protection and
Statistical Efficiency Act (CIPSEA).
Data collection and failure
analysis process
Failure data
reporting form
• Now working on data conduit to allow Operators to transmit reports directly to BTS.
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Continuous Improvement
As increased data continues to provide
new learnings, these are shared for the
benefit of all participants.
In addition, A number of specific topcs
have already been shared with the public:
• Regulator Valve Improvement Initiative
• Shuttle Valve Selection for ROV Circuits
• SPM Valve Spool Poppet Identification
• Deadman/Autoshear Timing Circuits
• Improper Subsea Control Valve Design Aspects
www.RAPID4S53.com
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Continuous Improvement
1.31
0.61 0.68
0.19 0.27 0.25
0.0
0.2
0.4
0.6
0.8
1.0
1.2
1.4
2013 2014 2015 2016 2017 2018ThroughSept 30
Unplanned BOP Pulls per Active Floater per 12M Equivalent
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Thank you!
▪ For further information on the JIP, contact:
▪ Steve Kropla, IADC
▪ JIP Project Coordinator
▪ E-mail: [email protected]
▪ Direct: +1 (713) 292-1959