Production start-up in Tune gas condensate field, offshore Norway
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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.
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Production start-up in Tune gas condensate field, offshore Norway
- 1. Tune Case (NH) Experience from Clean-up and Production using formate based brines as drilling/completion fluids Drilling & Completion Fluid Seminar, Aberdeen 03.06.24 By Stine Bøhle Karlsen, Production Technology Tune
- 2. Agenda – 03.06.24 Tune Field Information Initial clean-up / Normal Production Tune
- 3. 3500 3500 3500 3500 3500 3500 35003500 3500 35003500 3500 3500 3500 3500 3500 3500 PPP 478000 479000 480000 481000 6701000 6702000 6703000 6704000 6705000 6706000 0 500 1000m 30/8-A-14H 30/8-A-12 H 30/8-A-13H/AH 30/8-3 30/8-1S 30/8-A-11 H 3750 3750 3750 3500 3500 3500 3500 35003500 3500 3500 3500 3500 3500 3500 PPP 475000 480000 485000 6695000 6700000 6705000 6710000 3850 - 3900 3800 - 3850 3750 - 3800 3700 - 3750 3650 - 3700 3600 - 3650 3550 - 3600 3500 - 3550 3450 - 3500 3400 - 3450 3350 - 3400 3300 - 3350 3250 - 3300 3200 - 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
- 4. Agenda – 03.06.24 Tune Key data Initial clean-up / Normal Production Tune
- 5. 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
- 6. 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
- 7. 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 T2B4 T2B2 T2B6 T2B5 T2B3 Well 30/8-A-14 H Horizontal section ~900 m Completed mid May 2002 K/Cs-formate in reservoir section
- 8. 30/8-A-12HT2 T2B5 T2B6 T2B4 T2B3 T2B2 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
- 9. A-11 AH – well trajectory BCU Top Res Heather/ Upper Tarbert “Lagoonal Event” GOC Lower Tarbert OWC Horizontal section ~350 m Completed mid April 2002 K/Cs-formate in reservoir section
- 10. 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 RKB Lagoonal 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
- 11. 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 SIDHP bara 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] Depth[mTVDMSL] A-11AH A-12HT2 A-13H A-14H A-11 AH plugged back
- 12. 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
- 13. 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