fmc presentation

5/24/2018 FMC Presentation

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Havbunnsproduksjon

NTNU 26. mars 2012

Sverre Corneliussen

Senior System Enginer, FMC Studies & Tenders


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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


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Subsea Applications


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Topside ControlsTopside

Process

Umbilical/Flowline

Production Vessel

Floating production ship

Manifold

XT

Bijupira Saleema


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Snorre Tension Leg Platform (TLP)

SnorreUPA


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Terra Nova iceberg protection


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Owertrawl

protection


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Subsea to beach (Ormen Lange)


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8 Slot Template System. Ormen Lange1100 ton

Suctionanchor


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Basic reservoar and drilling


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Horisontal Wellcompletion


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Fishhook well


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Wellhead system

13 3/8

CasingHanger

18 3/4

Wellhead

Housing

13 3/8

Productiontubing

Hanger


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Smaller production bore (5 -7 )Production tubing installed brfore XT

XT can be removed wi thout removing

production tubing


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X-mas tree

Weight 40 ton

Subsea Control

Module


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X-mas tree


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Horizontal X-mas tree


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Subsea Production Control


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Functions Production Control System

19

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 systemintegrity


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Electro Hydraulic Control System

HydraulicActuators

InjectionChemicals

HydraulicPower unit

XmasTree

SubseaDistributionunit

UmbilicalCross Section

ElectricCables

Umbilical

MasterControlStation Electric

Power Unit

TopsideGateway

Hydraulic andChemical Lines

SCM

Up to 200 kmFluid linesElectrical lines

Fluid lines: Super duplex

Electrical lines: HDPE


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Subsea Control Umbilical - Typical

Topsides Termination Subsea Termination

Connects topsides control equipment to subsea field equipment

Routes hydraulic and electric power and chemicals to subsea field

Routes signals between topside and subsea equipment

Cross Section


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Subsea Control Module (SCM)

Lifting Adapter

Anti -Rotation Guide Pin

Locking Mechanism

Hyd. Couplers

Elec. Connectors

Elec. Connectors


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23

Subsea Electronic

Subsea Hydraulics &

Mechanics

Subsea Control Module: Components

SCM

without

outer canSCM


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Typical operator display picture


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DHSV

PMV PWV

Choke

Manifold HIPPSFlowline

Production Riser

Riser

EV

Utility Riser

CIV

EUC 1

EUC 2

Isolation of well from environment (OLF 070)


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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


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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


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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


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Conductor

interface

Hydrate formation in 1200 m water depth


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Subsea Instrumentation

Vega as example

Vega is a gas & codensate field in the North Sea

Sofisticated instrumentation due to high pressure and splitof production between different owners


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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


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Vega field


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Vega template & manifold


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High Integrity Pressure Protection System (S)HIPPS

PSD600

CU A

PSD A- B link

SV1

SV2

SV3

Flow

Line

BV1

BV2

BV3

MIV2

DCV

BV1

DCV

SV1

DCV

MIV2

DCV

SV2

DCV

BV2

DCV

SV3

DCV

BV3

PT6

A/B

PT7

A/B

PT4

A/B

PT5

A/B

PT10

A/B

PT8

A/B

PT9

A/B

PSD600

CU B

A B A B A B A BA B

A B

A B

A B

A B

Serv ice/

/

Line

IV2 IV1

A B A B A B

From

wells

MAIN HIPPS VALVESTEST VALVES


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SIL 3 controller hardware architecture

PSD SYSTEM SIDE A PSD SYSTEM SIDE B

PSD600 Control Unit

SensorsOutput to final

elements

Top Side

Sub Sea

SC1

SC2

ETH

PSD600 Control Unit

SensorsOutput to final

elements

SC1

SC2

ETH

Umbilical

PSD600 Control Unit

Switches Output

SC1

SC2

ETH

PSD600 Control Unit

SwitchesOutput

SC1

SC2

ETHCAN

From CAN

sensors

CAN CAN

From CAN

Sensors

CAN

From CAN

sensors

From CAN

SensorsComm.

Power

Comm.

Power

Direct

link

Direct

link

Direct

link

Direct

link

SCU

A

SCU

B


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SIL 3 controller software architecture

PSD Safety Core A2

ETH Subsystem

PSD Safety Core A1

CSC01 Execution control

PSD Safety Application

PSD Control Unit

Triton PXA255 (T-ETH-400/64S/32F/ETN/EXT) with RedBoot Firmware

Sensor Reading

Linux Operating System

Linux kernel 2.6.x

FMC 722

Handler

Serial

Handler

Net

Handler

Maintenance

and

Diagnostics

ETH Router

RS 422 x 1

UART TTL x 2Ethernet 100 Mbit PHY

SW

HW /

FW

RS 422 x 1

UART 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

Test

RAM,

CPU

SerialHandler

DO control,Monitoring and Test

Sensor

Reading and

Test

ADC

SPI

EEPROM

SPI

ConfigHandler

SW

HW /

FW

ADC

(SPI)

WD

SPIKernel

Mod

WDInt.

LockFSPS

PWR

MON &

CONTR.


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PT/TT FUNCTIONAL COMPONENTS

FLOW LINE

HARNESS

ADAPTER

PENETRATOR

ADC BOARD

CONTROL

BOARD

ELECTRONICS

PROBE

TRANSDUCER


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PT/TT FUNCTIONAL COMPONENTS

HOUSING MODULE:

The module is consisting of an flangewith a probe for process interface andcylindrical housing for the containmentof the electronic boards.

The electronics is contained inatmospheric pressure sealed withglass-metal penetrator towards theambient pressure.

The jumper connection is done via anadapter module.

QUARTZ CRYSTAL TECHNOLOGY


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QUARTZ CRYSTAL TECHNOLOGY

Total Error Band: 0.02 % FS

Pressure ranges: 0- 345Bara, 0-690Bara, 0-1035Bara

Standard Temperature ranges : -30 to 150 C Temperature accuracy: 0.3 % CR

Product family : PT/TT

Drift : 0,02 %FS/year @25C

Electrical interface:

RS485, CANOPEN

S d d t t W ki i i l


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Sand detector Working principle


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The results of sand

Cl O DSP P ti l M it S b


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ClampOn DSP Particle Monitor Subsea

DEEPWATER Weight 18 kg

4500 Meter Water Depth Intelligent DSP Processing = improved S/N ratio ROV installable sensor

COMPACT SUBSEA Weight 8 kg

3000 Meter Water Depth Intelligent processing = improved S/N ratio ROV installable sensor & clamp

ALL SYSTEMS

Fast economical installation

No drilling, welding or pressure dropDigital communication between field and computer


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ClampOns 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!


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Subsea multiphase meters on each well

Allows for accurate and continuous online wellallocation

Multi-rate testing to be performed wheneverdesired

Reduced need for well testing by using topside testseparator; only needed for verification:

Represents redundant solution

Yearly or when indication of anomalies

Reduces host platform deferred production

Results in substantial well regularity improvement


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Micro

wave

Gamma

ray

Venturi


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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


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Subsea Separation


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Separator Module

Miocene: 65% of overall reserves


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Pazflor reservoir Heavy oil: 1722 API

High viscosity: 40 cP at 55C

Reservoir Pressure: 200 bar

Reservoir Temperature: 65C

Oligocene: 35% of overall reserves

Light oil: 35-38 API

Reservoir Pressure: 350 bar

Reservoir Temperature: 115C

Free flow is not possible


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Solution - Subsea Processing

Gas / Liquid Separation andLiquid Boosting:

Gas flows freely to the FPSO

Hydrate preventions of flow lines bymeans of depressurization is possible

Reduced cost due to elimination ofcircular flow line

Liquid out of separator with relative lowgas fracttion

Efficient pumps with high P can be used Increased recovery & less power

consumption Boosting of liquid

Stabilized flow regime in risers reducesslugging


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LC

Pumps

Sep gas

XV

Sep

inlet

XV

Separatorliquid XV

Sep

inlet

bypass

XV

Riser

top XV

Pump

outlet XV

Choke

valve

PMV

PWV

Riser

top XV

ROV

LAH

RO

PC

23bar

60C

LAL

SSU Process Principle


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Separator Internals

Internals: Gas outlet pipe

EvenFlow

Liquid distributor plates

Singel helix

Sand cone

Swirl breaker

Liquid flushing arrangement


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Level Measurement

Subsea Nucleonic Density Profiler: Nucleonic source array (Cesium 137-50mCi)

Two detector arrays with Geiger Mllertubes

Topside PLC

Source and detectors installed in dip pipes

Detectors are retrievable, whereas nucleonicsource is permanently installed

Primary function is to measure liquid level, butprovides also information about densitydistribution between HH and LL

i


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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


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Snhvit

Ormen

Lange

Longest & deepest fields

Tormore-

Laggan

Shell

Perdido

b l b l


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FMC Kongsbergs Global Presence

Houston

Kongsberg

Singapore

Dunfermline

Rio De Janeiro

St. Johns

Macae

Lagos

Eq. Guinea

Luanda

AberdeenBergen

Stavanger

PerthMossel Bay


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Blow OutPreventer(BOP)

58

BP Macondo Shear ram failure


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BP Macondo Shear ram failure

59


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BOPshearRAM

60


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Thank You for Your Attention!

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