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.
