ntnu 28. mars 2011 sverre corneliussen senior … corneliussen. senior system enginer, fmc studies...
TRANSCRIPT
Havbunnsproduksjon
NTNU 28. mars 2011
Sverre Corneliussen
Senior System Enginer, FMC Studies & Tenders
Contents• Subsea field layout & equipment
– Subsea structures & X-mas trees
– Subsea Wells
– Subsea Control Systems
– Safety systems
– Well flow
• Subsea Instrumentation, Vega example– Pressure protection
– Pressure & temperature sensors
– Sand sensors
– Multiphase meters
• Subsea separation
Topside ControlsTopsideProcess
Umbilical/Flowline
Production Vessel
Floating production ship
ManifoldXT
Bijupira Saleema
Functions – Production Control System
21
1. Safety - Shuts in the subsea system in critical situations
2. Operator Interface during Daily Operation- Operation of subsea valves and chokes
- Monitoring of production parameters and system integrity
22
Electro Hydraulic Control System
HydraulicActuators
InjectionChemicals
HydraulicPower unit
XmasTree
SubseaDistributionunit
Umbilical Cross Section
ElectricCables
Umbilical
MasterControlStation Electric
Power Unit
TopsideGateway
Hydraulic and Chemical Lines
SCM
Up to 200 kmFluid linesElectrical lines
Fluid lines: Super duplexElectrical lines: HDPE
23
Subsea Control Module (SCM)
Lifting Adapter
Anti-Rotation Guide Pin
Locking Mechanism
Hyd. Couplers
Elec. Connectors
Elec. Connectors
24
Subsea Electronic
Subsea Hydraulics &Mechanics
Subsea Control Module: Components
SCM withoutouter can
SCM
DHSV
PMV PWV
Choke
Manifold HIPPSFlowline
Production Riser
Riser EV
Utility Riser
CIV
EUC 1
EUC 2
Isolation of well from environment (OLF 070)
Subsea Control Safety Functions
ESD Node(redundant)
HPUHydraulicSupply
SolenoidValves
(redundant)
To riser EV
UPS
Relay
XT
PMV PWV
DHSV
DumpDCV
PWVDCV
PMVDCV
DHSVDCV
SCM
Production Flow
ESD Signals
Electrical Power
Hydraulic Fluid
Pilot Supply
CIV
CIVDCV
Injection Line
CIV = Chemical Injection ValveDCV = Directional Control ValveDHSV = Down Hole Safety ValveEPU = Electrical Power UnitESD = Emergency Shut DownHPU = Hydraulic Power UnitPMV = Production Master ValvePWV = Production Wing ValveSCM = Subsea Control ModuleUPS = Uninterruptible Power SupplyXT = X-mas Tree
EPU
Subsea Control Safety Requirement
• ESD of single well to SIL 3
• PSD of single well to SIL 1
• HIPPS to SIL 3
• Workover to SIL 2
Flow assurance
• Natural flow
– Pressure balancing using chokes
– Flow optimization in flow lines
– Well testing
• Flow boost
– Gas lift, in riser, in well
– Booster pumps
Flow assurance
• Hydrates
– “ice” created of gas, water and oil
– Stable in cold, deep water
– Methanol or MEG anti frost
• Wax, asphalt, corrosion
– Injection of wax, asphalt and corrosion inhibitor
• Pigging
– Scraping plug pumped through flowline
Subsea Instrumentation
Vega as example
Vega is a gas & codensate field in the North Sea
Sofisticated instrumentation due to high pressure and split of production between different owners
Vega subsea instrumentation
• High Integrity Pressure Protection System (HIPPS)– 2 + 1 HIPPS valves on manifold
– 6 voted pressure sensors
• High accuracy pressure and temperature sensors– Quartz crystal sensor
• Acoustic sand detector – Listen for sand “pings”
• Multi phase meter for flow measurement of wet gas– Microwave sensors for 3 D model of flow
– Nuclear density meter
– P & T sensors for PVT calculation over Venturi
• 9” Nuclear density meter
High Integrity Pressure Protection System (S)HIPPS
SIPPS SENSORSIPPS VALVE SIPPS logic system
PSD logic system
SIPPS
Base case: Vega SIPPS, including MEG
9'’ Production
TEST SENSOR
production
PT9
Main flow
line
PT8 PT7
From wells
Note:XOV is
normally forced closed
Normal LP function
from MCM
Safety critical LP function
from PSD 600 in MCM
Safety critical LP function
From PSD600 in
MCM
Normal LP function
from MCM
Normal LP function
from MCM
Safety critical LP function
From PSD 600 in MCM
TEST VALVE
Bypass VALVE
SV3 SV2 SV1
BV3 BV2 BV1
PT10
SIPPS functionality: SV 1, SV 2, BV 1, BV 2 and MEG valve are triggered by PT 4-7
BV 3 and SV 3 are test valves.
Test/Batch MEG
Flow module
PT 4
PT 3
PT
2P
T 1
Steady state MEG
V-cone Flowline
V-cone MEG
PT5 PT 6
PT 11
SIL 3 controller hardware architecture
Switch/Router
Switch/Router
Switch/Router
Switch/Router
PSD SYSTEM SIDE A PSD SYSTEM SIDE B
PSD600 Control Unit
Sensors Output to final elements
Top Side
Sub Sea
A1
A2
ETH
PSD600 Control Unit
SensorsOutput to final elements
A1
A2
ETHU
mbi
lical
PSD600 Control Unit
Switches Output
A1
A2
ETH
PSD600 Control Unit
SwitchesOutput
A1
A2
ETH
FSK modem
FSK modem
Power Power
Switch/Router
Switch/Router
FSK modem
FSK modem
Power Power
Switch/Router
Switch/Router
AC AC
SIL 3 controller software architecture
PSD Safety Core A2
ETH Subsystem
PSD Safety Core A1CSC01 Execution control
PSD Safety Application
PSD Control Unit
Triton PXA255 (T-ETH-400/64S/32F/ETN/EXT) with RedBoot Firmware
Sensor Reading
Linux Operating SystemLinux kernel 2.6.x
FMC 722 Handler
Serial Handler
Net Handler
Maintenance and
Diagnostics
ETH Router
RS 422 x 1UART TTL x 2 Ethernet 100 Mbit PHY
SW
HW /FW
RS 422 x 1UART TTL x 2
DO x 32
AI 4-20 mA x 16
CAN PHY
CSC01 CAN Safety Chip (M16C) 16 Bit Renesas Microcontroller
CAN Open Stack
TestRAM, CPU
Serial Handler
DO control, Monitoring and Test
Sensor Reading and
Test
ADCSPI
EEPROMSPI
Config Handler
SW
HW /FW
ADC(SPI)
WD
SPIKernel Mod
WD Int. LockFSPS
PWR MON &
CONTR.
PT/TT FUNCTIONAL COMPONENTS
FLOW LINE
HARNESSADAPTER
PENETRATOR
ADC BOARD
CONTROLBOARD
ELECTRONICS
PROBE
TRANSDUCER
PT/TT FUNCTIONAL COMPONENTS
HOUSING MODULE:
• The module is consisting of an flange with a probe for process interface and cylindrical housing for the containment of the electronic boards.
• The electronics is contained in atmospheric pressure sealed with glass-metal penetrator towards the ambient pressure.
• The jumper connection is done via an adapter module.
QUARTZ CRYSTAL TECHNOLOGY• Total Error Band: 0.02 % FS• Pressure ranges: 0- 345Bara, 0-690Bara, 0-1035Bara• Standard Temperature ranges : -30 to 150º C• Temperature accuracy: 0.3 % CR• Product family : PT/TT• Drift: 0,02 %FS/year @25C• Electrical interface: RS485, CANOPEN
Choke module -a challenge!
ClampOn Ultrasonic Intelligent Sensors
Choke
The subsea modules are more an more compact - more instrumentation and less space for “optimum” conditions.
Distance from choke to detector is less then 2 meters
Chokes generates high unwanted ultrasonic noise due to extreme velocities!
How to overcome this? – lets look at a real case!
ClampOn DSP Particle Monitor Subsea
DEEPWATERØ Weight 18 kgØ 4500 Meter Water DepthØ Intelligent DSP Processing = improved S/N ratioØ ROV installable sensor
COMPACT SUBSEAØ Weight 8 kgØ 3000 Meter Water DepthØ Intelligent processing = improved S/N ratioØ ROV installable sensor & clamp
ALL SYSTEMS•Fast economical installation•No drilling, welding or pressure drop•Digital communication between field and computer
ClampOn’s Subsea Philosophy!
Titanium body
Jumper interface
High pressure chamber with silicon oil
Glass-metal penetrator
Atmospheric chamber
Electronic beam weldings
No o-rings, gaskets or mechanical seals!
Subsea multiphase meters on each well
Allows for accurate and continuous online well allocation
– Multi-rate testing to be performed whenever desired
Reduced need for well testing by using topside test separator; only needed for verification:
– Represents redundant solution
– Yearly or when indication of anomalies
– Reduces host platform ”deferred production”
Results in substantial well regularity improvement
Subsea seabed separation
• Separate water and sand from oil – Produced fluid may contain 90 % water from old wells
– Remove and re-inject water and sand close to well
– Avoid transport of water long distance for separation on surface
• Separate heavy oil from gas on deep fields– Pump heavy oil to surface, natural well pressure will not lift oil
– Gas to surface by natural flow
Challenges with the Pazflor in West Africa
• Low energy reservoir
• Deep water ~ 800 – 1000m
• High viscosity and stable emulsion– Large pressure drop in flowlines and risers
• High water production from year 4– Large amounts of methanol needed for hydrate prevention
è Free flow is not possible
Solution - Subsea Processing
• Gas / Liquid Separation and Liquid Boosting:– Gas flows freely to the FPSO
• Hydrate preventions of flow lines by means of depressurization is possible
• Reduced cost due to elimination of circular flow line
– Liquid out of separator with relative low gas fracttion
• Efficient pumps with high ∆P can be used → Increased recovery & less power
consumption
– Boosting of liquid• Stabilized flow regime in risers reduces
slugging
LC
Pumps
Sep gasXV
SepinletXV
Separatorliquid XV
Sepinlet
bypassXV
Risertop XV
Pumpoutlet XV
Chokevalve
PMV
PWV
Risertop XV
ROV
LAH
RO
PC
23bar 60°C
LAL
SSU Process Principle
Separator Internals
• Internals:
– Gas outlet pipe
– EvenFlow
– Liquid distributor plates
– Singel helix
– Sand cone
– Swirl breaker
– Liquid flushing arrangement
Level Measurement
• Subsea Nucleonic Density Profiler:
– Nucleonic source array (Cesium 137-50mCi)
– Two detector arrays with Geiger Müller tubes
– Topside PLC
• Source and detectors installed in dip pipes
• Detectors are retrievable, whereas nucleonic source is permanently installed
• Primary function is to measure liquid level, but provides also information about density distribution between HH and LL
Test Overview
• EFAT of:– Control System
– Pump Systems
• Interchangeability of modules
• System Integration Test of all SSU
• Shallow Water Test of SSU#2
• Function Test of SSU#1
FMC Kongsberg’s Global Presence
Houston
Kongsberg
Singapore
Dunfermline
Rio De Janeiro
St. John’s
Macae
LagosEq. Guinea
Luanda
AberdeenBergen
Stavanger
PerthMossel Bay