L10 - NEW TECHNOLOGIES

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L10 - NEW TECHNOLOGY : SUBSEA PROCESSING & BOOSTING

• SUBSEA MULTIPHASE PUMPING

• PARTIAL SUBSEA SEPARATION / PRESSURE BOOSTING SYSTEMS

• FULL SUBSEA SEPARATION

• SUBSEA GAS BOOSTING

• TEST AND OPERATIONAL RESULTS

• OTHER SEABED PROCESSES

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Subsea Boosting, Why?

• Enhanced and faster production

-Wellhead pressure draw-down

-Compressor discharge pressure overcomes back-pressure and frictional losses

• Reduced OPEX

• Reduced CAPEX

• De-bottle-necking oil production

• Development and production of low pressure reservoirs

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WHERE TO CARRY OUT SUBSEA BOOSTING OR PROCESSING?

1 2 3 1 2 4 MULTIPHASE PUMP

RISER BASE SYSTEM PUMP OR GAS LIFT SUBSEA

SEPARATOR

EXISTING EXPORT PIPELINE GAS LIFT IN WELLS

DOWNHOLE PUMP

FPSO

PLATFORM HOST PLATFORM HOST

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y

In dummy well

y

At mud line

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Well fluid

SMUBS

- Subsea Multiphase Booster Station for Draugen field,

AS Norske Shell

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Multi-Booster;

A twin-screw Pumping Principle

Positive displacement by use of twin-screw or moyno pumps

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Subsea MultiBooster

-Data below: for the as built Demo 2000

Possible duties:

• Multiphase boosting

• Wet gas compressor

Design Data DEMO 2000:

• Flow:

940 m

3

_/h

• Diff. press: 40 bar

• Duty:

Wet gas compression

Main Technical Features:

• Design press.: 250 barg

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Subsea Booster Projects

• Shell, Draugen

(1 × 750 kW Water Turbine)

• Shell / Statoil, ELSMUBS

(1

×

Electric Motor 1 MW)

• Statoil, Lufeng

(5

×

Electric Motor 400kW)

• BP, ETAP

(2

×

900 kW Water Turbine)

• Mobil, Topacio

(2

×

860 kW Electric Motor)

• Norsk Hydro, Troll C Pilot

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History of Subsea Processing

Category Projects Operators Year Technology Tie-back

Water depth Zakum ADMA (Total

Partner)

1970 Subsea separation w diver assist. 4 km 22 m Highlander Texaco 1985 Subsea separation & pumping 0 km 128 m Argyll Hamilton Brothers 1988 Subsea separation BOET 0 km 120 m Gas / Liquid

separation

VASPS (Marimba)

Petrobras 2001 Separator & pumping in dummy well

1 km 395 m HC / Water

separation

Troll C Norsk Hydro (w Total)

2000 Gravity separator & WI pump 3 km 340 m Draugen Shell 1994 1 MPP (turbine) Framo 6 km 270 m Lufeng Statoil 1997 5 booster pumps Framo 0 km 330 m

Machar BP 1999 2 MPP (turbine) Framo Never installed on site Topaccio Exxon Mobil 1999 2 MPP Framo 8 km 500 m

Mudline pumps

Ceiba Hamerada Hess 2002 2 MPP Framo 7 km 750 m

Lihua Amoco 1996 25 pumps 0 km 300 m

Otter Total 2002 5 pumps 21 km 184 m

Downhole pumps

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BOET SUBSEA SEPARATOR

-INSTALLED ON ARGYLL FIELD

AT ITS END OF LIFE

KBS - Kvaerner Booster Station

Centrifugal Compressor Prototype

Technical:

1200 hrs tests (submerged)

• Nuovo Pignone centrifugal

compressor

• 8 stage

• 850 kW

• 16 000 rpm

• Maag epicyclic gear

• Loher motor of

• 6.6 kV

• 1800 rpm

Testing included operation

as wet gas compressor

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Sump

Sand

Cyclone

Liquid

Sump

Pump

Motor

Separator

Joints

Inlet

Hdyrocyclone

Wellhead

Fluids In

Gas Scrubber

Electric Power Supply

Gas Out

Oil Out

LIQUIDS OUT

GAS OUT

TANGENTIAL

INLET

UPPER SECTION OF UNIT

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Vertical Annular Subsea Separation

( VASPS )

• THE FLUID FROM THE WELLS IS SEPARATED INTO A GAS AND LIQUID PHASES

• THE SEPARATED GAS NATURALLY FLOWS IN A DEDICATED LINE TO THE SURFACE FACILITIES UNDER ITS OWN PRESSURE

• THE LIQUID IS PUMPED OUT OF THE VASPS INTO A DEDICATED LINE BY AN ESP

TEST RESULTS FROM MARIMBA FIELD, BRAZIL

5 10 0 15 20 25 30 35 40 45 50 8 million 7 million 6 million 9 million 10 million 4 million 3 million 2 million 1 million 5 million Produced Gas Bbl/day 1000’s Oil Scf/ day

Pre VASPS With VASPS

0

Gas Lift Gas

Note pre VASPS oil production of 35,000 bbls / day with gas Lift. After VASPS 44,000 bbl / day with no need for gas lift

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TROLL PILOT - UPDATE

• Operational 17th

May 2000

• Typical Performance - 23,900 bopd Multiphase Flow Separated into :-- 16,350 bopd Oil

- 7,550 bopd Water

• After June Water Injected using Injection Pump • Quality of Separation Within Prescribed Limits - About 144 ppm Oil in Water (design Max 1000 ppm)

• During Operation some 80% of the Water in the Oil Stream is Removed

• Late in 2000 the Equipment experienced some Mechanical Problems, this was not

to do with the Fundamentals of the Process.

• Key Technology Areas

- Separator with Novel Inlet Device (semi-Cyclone) which reduces Momentum in the Wellstream gradually such that it Prevents the Formation of small Droplets which would Reduce the Efficiency of the Separation Process.

- Control of the Oil / Water Interface. Monitoring based on Nucleonics and Electric Sensors Control the Speed of the Injection Pump.

UPRDATE - PHASE 2

• The connector problem took 10 months to fix.

• In August 2001 the system was restarted and has works without problems since

then.

• It is typically operating at up to 70,000 bopd input fluids, the separated water (60 to

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Typical concept : Gravity Separation

To pipeline 12” header Well fluid PT LT To water injection wells Produced water injection pumps 3-phase separator TT Multiphase booster pump PT PT PT PT FT

Reference : Troll pilot

outlet water cut less than 10%

oil in water less than 700 ppm

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SUBSEA POWER

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KING FIELD – GoM

- DEEPWATER OIL BOOSTER PUMP

King is now one of three fields producing from the Marlin

TLP and represents more than half of Marlin TLP production.

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TORDIS FIELD SUBSEA

SEPARATION BOOSTING

& INJECTION

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The Tordis discoveries

have all been developed

with subsea installations

tied back to the Gullfaks C

platform.

The subsea separation station is

equipped with two multiphase flow

meters.

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LIR1 VLT1 CRA1 _ORQ1 ROS2 ROS3 ROS1 JCT1 JAS1 JAS2 GIR2 GIR1 DAL3 ANT1 TUL1 MAG1 CML1 ACA1 PLT1 GAL1 CRM1 ZNA1 PRP1 HOR1 VIOLETA TULIPA ANTURIO LIRIO CRA VO ROSA2 ROSA1 ORQUIDEA JASMIMGIRB DALIA LOWER DALIA UPPERCAMELIA PLD1 BLOCK 4 BLOCK 3 BLOCK 33 BLOCK 18 BLOCK 16 BLOCK 32 120 000 140 000 160 000 180 000 DAL5 DAL1 DAL4 DAL2 10 00 ₈₀ 0 60₀ 12 00 400 14 00 18₀₀ 16 00 PERPETUA UP-MIOC KIAME BLOCK 17 9 140 000 9 160 000 9 180 000 9 200 000 200 000 220 000 ACA1 ZNA1 PRP1 HOR1 UP-MIOC PERPETUA HORTENSIA ZINIA ACACIA

20 km

PAZFLOR DEVELOPMENT - Block 17, Angola

FIELDS - HORTENSIA, PERPETUA, ZINIA & ACACIA

WATER DEPTH - 650 – 1300m

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Upper Miocene (Perpetua-1 : UM2)

20°API, d=0,93,TAN=1.96 mg KOH/g

GOR # 50 Sm

3

/Sm

3

High viscosity (up to µ=500 cp at 20°C)

Risks of calcium naphtenate, emulsions, foaming

Risk of hydrate (no risk of paraffin)

Water injection

Oligocene (Acacia-1 : O9)

37°API, d=0,84, TAN=0.2 mg KOH/g.

GOR # 250 Sm

3

/Sm

3

Viscosity µ=20 cp

Risk of sulphate of barium ==> desulphatation if Water Injection

Risk of hydrate and paraffin

Water & Gas injection

Reservoir

Burial Thickness

Temp.

Pressure

data

(m)

(

)

(bara)

Upper M iocene

(UM1,UM2,UM3)

O9 & O9w

(Acacia)

1100

64

200 2000

110

350 10 ? 30

40 ? 60

NOTE – TWO

TYPES OF OIL

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UM Area - Overall field development – Production Network

MIOCENE

Î

Í

_OLIGOCENE

« Conventional » Development

Dual line production loop

XT XT XT XT P 10 XT XT XT XT P 20 P 30 XT XT XT XT XT XT P 40 XT XT XT XT XT XT XT XT XT XT XT