High Integrity Pressure Protection System
(HIPPS) in Subsea Applications
Marcel Castro Ph.D.– TS&R Engineer
Agenda
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•
•
•
•
Definition/Motivation of subsea HIPPS
Subsea HIPPS architecture
Design drivers
Safety life-cycle
Subsea HIPPS challenges:
– Components arrangement
– Location
– Response time
11/14/2014
Subsea HIPPS
1
Typical Subsea HIPPS
Riser “Fortified”
zone
An autonomous Safety Instrumented System
(SIS) used to protect production assets from
high-pressure upsets [ API 17O]
“Fortified” zone
XT
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Subsea HIPPS
Brownfield developments
Lower rated downstream equipment
Thinner wall / lighter pipeline
Lower material cost
Reduce pipe welding and fabrication
costs
• Easier handling/transportation
• Flexibility in choice of installation vessel
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•
•
•
•
HIPPS
2
Platform
Typical HIPPS Architecture
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Subsea HIPPS
3
Design Drivers for Subsea HIPPS
Industry Standards & Guidelines
Governmental Regulations
PTIL
IEC 61511
IEC 61508
API 17O
Client requirements
OLF 070
API RP 14C
API RP 521
NORSOK P001
Best practises
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Subsea HIPPS
4
Risk Reduction
Actual
Remaining
Risk
Process
Risk
Tolerable
Risk
Necessary risk reduction
Actual risk reduction
Partial risk covered by non-SIS
/ protection layers
Partial risk covered by SIS
Risk reduction achieved by all protection layers
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Subsea HIPPS
5
Increasing
risk
Subsea HIPPS
2
Allocation of safety functions
to protection layers
Safety requirements
specification
Design and engineering
Design and development
of other means of risk
reduction
4
5Installation,
FMCTI responsibility
11
Hazard and risk assessment
commissioning and validation
6
Operation and maintenance
7
Modification
8
Decommissioning
6
9
Source: IEC 61511
10
3
1
Verification
Safety life-cycle structure and planning
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Management of functional safety and
functional safety assessment and auditing
FMCTI responsibility
SIS Life-cycle
Agenda
•
•
•
•
•
Definition/Motivation of subsea HIPPS
Subsea HIPPS architecture
Design drivers
Safety life-cycle
Subsea HIPPS challenges:
– Components arrangement
– Location
– Response time
11/14/2014
Subsea HIPPS
7
Challenge 1: Architectural Constraint and Sensor
Arrangement
1oo2
PT
PT
IEC 61511: Sensors, final elements, and non-PE
SIL
Hardware Fault Tolerant
1
0
2
1
3
2
4
Special requirements apply (IEC 61508)
2oo3
PT
PT
PT
2oo3
PT
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Subsea HIPPS
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PT
PT
PT
Challenge 2: HIPPS Location
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•
•
•
•
•
•
Field lay outs
#HP Wells
Flow line size
Weight/Space
Installation
Retrieval
Testing
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Subsea HIPPS
9
Challenge 2: HIPPS Location
•
•
•
•
•
•
•
Field lay outs
#HP Wells
Flow line size
Weight/Space
Installation
Retrieval
Testing
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Subsea HIPPS
10
Challenge 3: HIPPS Response Time
• Combination of sensor, logic solver
and final elements response time.
Components
response
Clogging
Response
time
Field
layout
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Water
Depth
Hydraulic volume/
pressure/type
Subsea HIPPS
11
𝐻𝐻𝐻𝐻𝐻𝐻𝐻𝐻𝐻𝐻 𝑇𝑇𝑇𝑇𝑇𝑇𝑇𝑇 ∶ 𝐹𝐹𝐹𝐹𝐹𝐹𝐹𝐹.
𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃𝑃,
𝑇𝑇𝑖𝑖𝑖𝑖𝑖𝑖
Response Time Reduction
• Improve through design
–
–
Instrumentation
Valve and hydraulic system
Subsea HIPPS
20%
4% Logic
solver
76%
• Hydraulic return system example:
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Final Elements
Sensor
12
Subsea HIPPS within FMC Technologies
20K/350F JDA
• 20Kpsi
• 10 sec
Gullfaks II
• 10Kpsi
• 1 sec
• 7-1/16“ valve
Vega
• 10Kpsi
• 8 sec
• 9“ valve
Julia
• 15Kpsi
• 8 sec
Mexilhão
• 10Kpsi
• 30 sec
• 5-1/8" valve
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Subsea HIPPS
GERM
• 6,6Kpsi
• 5 min
• 5-1/8“ valve
13
Shah Deniz II
• 13Kpsi
• 15 sec
• 10“ valve
Summary
• Subsea HIPPS is a key enabler to develop high-pressure
high-temperature subsea fields
• SIS lifecycle applies to the subsea HIPPS development
• Main design drivers
• Subsea HIPPS challenges
– Sensor arrangement
– HIPPS location
– Response time
• FMC technology has extensive subsea HIPPS experience
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Subsea HIPPS
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Questions ?
Marcel Castro Ph.D.
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Subsea HIPPS
15