production start-up in tune gas condensate field, offshore norway
DESCRIPTION
Presentation by Norsk Hydro describes the completion, suspension and production start-up of four wells in the Tune gas condensate field, offshore Norway. Wells suspended in open hole with formate brine for 6-9 months. Quick natural clean-up of potassium formate drilling fluid residues from the horizontal open holes during production start-up. No filter-cake clean-up required.TRANSCRIPT
Tune Case (NH)Experience from Clean-up and Production using formate based brines as drilling/completion fluids
Tune Case (NH)Experience from Clean-up and Production using formate based brines as drilling/completion fluids
Drilling & Completion Fluid Seminar, Aberdeen 03.06.24By Stine Bøhle Karlsen, Production Technology Tune
Drilling & Completion Fluid Seminar, Aberdeen 03.06.24By Stine Bøhle Karlsen, Production Technology Tune
Agenda – 03.06.24
Tune Field Information
Initial clean-up / Normal Production Tune
3500
PPP
478000 479000 480000 481000
6701000
6702000
6703000
6704000
6705000
6706000
0 500 1000m
30/8-A-14 H
30/8-A-12 H30/8-A
-13 H/A
H
30/8-3
30/8-1S
30/8-A-1
1 H
PPP
475000 480000 485000
6695000
6700000
6705000
6710000
3850- 39003800- 38503750- 38003700- 37503650- 37003600- 36503550- 36003500- 35503450- 35003400- 34503350- 34003300- 33503250- 33003200- 3250
0 2000 4000m
30/8-A-12 H
30/8-A-13 H/AH
30/8-1S
30/8-
A-11 H
30/8-A-14 H
Tune Field
Horizontal gas producers
Pure gas depletion
Sand screen completion
Tarbert Formation Gas/condensate
HP/HT – 525 bar / 131 degC
Reservoir thickness 100m - N/G 0.85
porosity ~16%, permeability 10-200 mD
12 m oil rim – non commercial
30/5-2
Agenda – 03.06.24
Tune Key data
Initial clean-up / Normal Production Tune
Initial clean-up Tune
PDO To drilling rig (Deep Sea Delta) 2-3 weeks after final completion
Actual To Oseberg Field Centre (through 11 km of pipeline)
– DSD not applicable
– outstanding verifications to perform clean-up
– Safety risks: flare + HT/HP 6-12 months after final completion
Initial clean-up Tune – continue
November /December 2002
Focus Initial clean-up Possible problems related to condensate blocking
Strategy Gradually opening of well Controlled by bottom hole pressure (Pdewpoint = 509 bar)
Measurements P/T sensors down hole and at wellhead Gas flow meter Online density meter on Tune separator
A-14 H – well trajectory
Geological cross-section along the drilled wellpath 31/8-A-14 H
BCU
Heather/Upper Tarbert
Lower Tarbert
TD
T2B1
T2B4T2B2
T2B6T2B5
T2B3
Well 30/8-A-14 H
Horizontal section ~900 m
Completed mid May 2002
K/Cs-formate in reservoir section
30/8-A-12HT2T2B5
T2B6
T2B4 T2B3T2B2
T2B1
Heather/Upper Tarbert
Lower Tarbert
A-12 T2H – well trajectory
Horizontal section ~650 m
Completed mid Nov 2001
Initially K-formeat in reservoir section
Displaced to K/Cs-formate mid June 2002, as upper completion was set
Tracers placed @
Antimonium - 4444 mMD RKB
Scandium - 4675 mMD RKB
Top reservoir @
4178 mMD RKB
TD @
4834 mMD RKB
A-11 AH – well trajectory
BCU
Top ResHeather/
Upper Tarbert
“Lagoonal Event”
GOC
Lower TarbertOWC
Horizontal section ~350 m
Completed mid April 2002
K/Cs-formate in reservoir section
30/8-A-13H
T2B5
T2B6
T2B4
T2B2
T2B1
Upper Tarbert
Lower Tarbert
T2B3
A-13 H – well trajectory
Tracers placed @
Silver - 4616 mMD RKB
Cobalt - 5031 mMD RKB
Top reservoir @ 4241 mMD RKB
4829 mMD RKBLagoonal event @ 5026 mMD
RKB
Reservoir section ~900 m
Completed mid Dec 2002
K-formate in reservoir section
Only well not displaced to K/Cs-formate
Overall performance Initial Clean-up Left for 6-12 months before clean-up
Planned for 2-3 weeks 10 - 24 hours per well Well performance
Qgas 1.2 – 3.6 MSm3/d PI 35 – 200 kSm3/d/bar Well length sensitive No indication of formation damage
– Match to ideal well flow simulations (Prosper) - no skin
Indications of successful clean-up Shut-in pressures Water samples during clean-up
– Formate and CaCO3 particles Registered high-density liquid in separator Tracer results
– A-12 T2H non detectable– A-13 H tracer indicating flow from lower reservoir first detected 5 sd after
initial clean-up <-> doubled well productivity compared to initial flow data No processing problems Oseberg Field Center
SIWHP SIDHP SIWHP SIDHPbara bara bara bara
A-11 AH 169 - 388 -
A-12 T2H 175 487 414 510
A-13 H 395 514 412 512
A-14 H 192 492 406 509
Before After
3350
3400
3450
3500
3550
3600
0 100 200 300 400 500 600 700 800 900 1000
Well length [m MD]
Dep
th [
m T
VD
MS
L]
A-11AH
A-12HT2
A-13H
A-14H
A-11 AH plugged back
Return of completion fluid
No quantitatively control of liquid flow during start-up and first weeks of production
Spot ”water” samples of clean-up flow from A-12 T2H and A-11 AH
s.g. 0.8 - 1.33 pH 7.8 – 8.7 CaCO3 particles Crushed Formation particles
Normal Production
Stepwise increase in production to monitor well behaviour (January 2003) Possible problems related to condensate blocking Production reached PDO defined plateau rate of 9 MSm3/d on
January 24th
No negative effect on well productivity has been registered Ion analysis of produced water (January) - high content of
Potassium
Pigging operation in March and June – minor/no formate
Status June 2003 All four wells producing Well productivity as expected Gas production 12.4 MSm3/d Condensate 23 000 bbls/d