L10 - NEW TECHNOLOGIES

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

•

RECENT HEADLINE FIELD UTILISING NEW TECHNOLOGIES

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

WHERE TO CARRY OUT SUBSEA BOOSTING OR PROCESSING? PLATFORM HOST

PLATFORM HOST FPSO

MULTIPHASE PUMP

RISER BASE SYSTEM SUBSEA SEPARATOR

PUMP OR GAS LIFT

4

3

GAS LIFT IN WELLS

2

2

1

1 EXISTING EXPORT PIPELINE DOWNHOLE PUMP

y

In dummy well

y

At mud line

Well fluid

SMUBS - Subsea Multiphase Booster Station for Draugen field, AS Norske Shell

Drive fluid

Multi-Booster; A twin-screw Pumping Principle Positive displacement by use of twin-screw or moyno pumps ∆p = f(1/∆V)

Subsea MultiBooster Data below: for the as built Demo 2000 Possible duties: •

Multiphase boosting

•

Wet gas compressor

Design Data DEMO 2000: •

Flow:

•

Diff. press: 40 bar

•

Duty:

940 m3/h

Wet gas compression

Main Technical Features: •

Design press.: 250 barg

•

Water depth:

up to 1500m

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 (1+1 × 1.600 kW Electric Motor)

BP ETAPS FIELD

History of Subsea Processing Category

Projects

Gas / Liquid Zakum separation Highlander Argyll VASPS (Marimba) HC / Water Troll C separation Mudline Draugen pumps Lufeng Machar Topaccio Ceiba Downhole Lihua pumps Otter

Operators

Year Technology

ADMA (Total Partner) Texaco Hamilton Brothers Petrobras

1970 Subsea separation w diver assist.

Norsk Hydro (w Total) Shell Statoil BP Exxon Mobil Hamerada Hess Amoco Total

Tieback 4 km

Water depth 22 m

1985 Subsea separation & pumping 1988 Subsea separation BOET 2001 Separator & pumping in dummy well 2000 Gravity separator & WI pump

0 km 0 km 1 km

128 m 120 m 395 m

3 km

340 m

1994 1997 1999 1999 2002 1996 2002

6 km 270 m 0 km 330 m Never installed on site 8 km 500 m 7 km 750 m 0 km 300 m 21 km 184 m

1 MPP (turbine) Framo 5 booster pumps Framo 2 MPP (turbine) Framo 2 MPP Framo 2 MPP Framo 25 pumps 5 pumps

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

BOET SUBSEA SEPARATOR INSTALLED ON ARGYLL FIELD AT ITS END OF LIFE

Electric Power Supply Oil Out

VASP UNIT (Vertical Annular Subsea Separation)

Gas Scrubber Gas Out

LIQUIDS OUT Wellhead Fluids In

Inlet Hdyrocyclone Separator Joints

GAS OUT

Pump Motor

Liquid Sump

TANGENTIAL INLET

Sand Cyclone UPPER SECTION OF UNIT Sump

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

Bbl/day 1000’s Oil

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

Produced Gas

Gas Lift Gas

Scf/ day

50

10 million

45

9 million

40

8 million

35

7 million

30

6 million

25

5 million

20

4 million

15

3 million

10

2 million

5

1 million

0

0

Pre VASPS

With VASPS

TROLL PILOT - UPDATE •

Operational 17 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.

-

th

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 80%) has an oil level of some 100 ppm.

Typical concept : Gravity Separation 12” header

Well fluid

To pipeline TT

PT

LT PT

PT

Multiphase booster pump

3-phase separator

PT FT

PT

Produced water injection pumps

Reference : Troll pilot outlet water cut less than 10% oil in water less than 700 ppm

To water injection wells

SUBSEA POWER DISTRIBUTION SYSTEMS

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.

TORDIS FIELD SUBSEA SEPARATION BOOSTING & INJECTION

Layout of the Tordis improved oil recovery project

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.

PAZFLOR DEVELOPMENT - Block 17, Angola FIELDS - HORTENSIA, PERPETUA, ZINIA & ACACIA WATER DEPTH - 650 – 1300m 9 200 000

BLOCK 16 0 40

0 60

0 80

00 10

00 12

140

BLOCK 3 BLOCK 4

PERPETUA

KIAME

0

VIOLETA

9 180 000

0 160

BLOCK 32

LIRIO VLT1

LIR1 CRA1

ANT1

CRA VO ROSA2

HORTENSIA

TULIPA ANTURIO

ORQ1

ORQUIDEA

HOR1

PERPETUA

ZINIA

TUL1 HOR1

ROS2

PRP1

ROS3 ROS1

00 18

UP-MIOC

JAS1

DAL2

DAL1 DAL5

DAL4

CML1

DALIA CAMELIA UPPER

BLOCK 33

UP-MIOC

ACA1

GIR1

120 000

ZNA1 9 160 000

JASMIMGIRB DALIA JAS2 LOWER GIR2 ROSA1 DAL3

JCT1

ACA1

GAL1

BLOCK 18 PLT1 140 000

BLOCK 17

CRM1

ACACIA

PLD1 160 000

9 140 000

180 000 200 000

20 km

ZNA1 PRP1

MAG1

220 000

Reservoir data Upper Miocene (UM1,UM2,UM3) O9 & O9w (Acacia)

Burial (m)

Thickness (m)

Temp. ( )

Pressure (bara)

1100

10 ? 30

64

200

2000

40 ? 60

110

350

Upper Miocene (Perpetua-1 : UM2) 20°API, d=0,93,TAN=1.96 mg KOH/g GOR # 50 Sm3/Sm3 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

NOTE – TWO TYPES OF OIL

Oligocene (Acacia-1 : O9) 37°API, d=0,84, TAN=0.2 mg KOH/g. GOR # 250 Sm3/Sm3 Viscosity µ=20 cp Risk of sulphate of barium ==> desulphatation if Water Injection Risk of hydrate and paraffin Water & Gas injection

UM Area - Overall field development – Production Network MIOCENE Î

Í OLIGOCENE

Subsea Gas/Liquid Separation Single production line XT

XT

XT

XT

XT

XT

« Conventional » Development Dual line production loop

P 10 XT

XT XT

XT

XT

XT

XT

P 20

P 40 XT

XT XT

XT

XT

XT

XT

P 30

XT

XT

XT

XT

XT

PAZFLOR DEVELOPMENT

There will be three subsea separation systems provided by FMC following the company's success on Tordis.