SPE 199286 - Profiling the Production Performance of Five HPHT Gas Condensate Wells Drilled and Completed with High-Density Cesium Formate Fluids in the Brent Group Formations of the Kvitebjorn Field
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1. The document discusses production performance from five high-pressure, high-temperature gas condensate wells in the Kvitebjorn Field in the Norwegian North Sea that were drilled and completed using cesium formate drilling fluids. 2. Logging data obtained using cesium formate brine showed improved reservoir quality, leading to a 33% increase in estimated hydrocarbon reserves. Actual cumulative production from the field has matched or exceeded revised reserve estimates. 3. Cumulative production from the initial five wells after 14 years is now higher than the original reserves projection for the entire field, demonstrating the benefits of using cesium formate fluids for drilling and completion.
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SPE 199286 - Profiling the Production Performance of Five HPHT Gas Condensate Wells Drilled and Completed with High-Density Cesium Formate Fluids in the Brent Group Formations of the Kvitebjorn Field
- 1. 1 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control SPE -199286-MS Profiling the Production Performance of Five HPHT Gas Condensate Wells Drilled and Completed with High-Density Cesium Formate Fluids in the Brent Group Formations of the Kvitebjorn Field John Downs, Formate Brine Ltd, and Niall Fleming, Equinor ASA
- 2. 2 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control The Kvitebjorn Field • Kvitebjorn is a HPHT gas/condensate field in the Norwegian North Sea • Water depth: 190 metres • Reservoir: Brent Group – Middle Jurassic sandstones • Av. porosity 20%, permeability 50-90 mD, net/gross 0.63 • Reservoir thickness: 125-165 metres • Reservoir depth: 4,000 metres TVD • Reservoir temperature/pressure: 150oC/ 770 bar • Drainage strategy: Pressure depletion • No aquifer or mobile water in main reservoir • Production start-up date: 2004 -5 from initial 5 (of 14) wells • All development wells drilled and completed with cesium formate fluids* * see SPE 105733 SPE 199286 Presenter: Niall Fleming
- 3. 3 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control The Kvitebjorn Field – Hydrocarbon Resources and Reserves • Improved reservoir quality identified from logging operations in cesium formate brine - Higher net reservoir, increased porosity, reduced water saturation • Hydrocarbon Pore Factor (HPF) increased by 33% • Reserves increased by 50% in 2006, two years after the start of development well drilling SPE 199286 Presenter: Niall Fleming Time-lapse resistivity (left) and Pe readings (right) track cesium formate filtrate movement and provide accurate definition of net reservoir
- 4. 4 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Kvitebjorn Field – Actual versus predicted cumulative gas and condensate production, September 2004 – September 2019 Cumulative gas and condensate production now exceeds the original reserves estimates by 50% and is still rising following installation of a gas pre-compression unit in 2014 SPE 199286 Presenter: Niall Fleming 2006-2009 - Production deliberately restricted to maintain reservoir pressure. Production also shut down for periods while repairs carried out on pipeline damaged by ship's anchor
- 5. 5 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Kvitebjorn Field – Cumulative production from the first 5 production wells (2 cased and 3 screen completions) - all drilled and completed in same cesium formate fluid • Screen well A-5 (initial skin = 3) and cased well A-14 (initial skin = 15) have been the strongest producers • Two screen wells (A-5 and A-15) and one cased well (A-14) have produced without intervention for 13-14 years • Cumulative gas and condensate production to October 2018 exceeds by 24 % and 38% respectively the upgraded P50 recoverable reserves predicted for these five wells in 2006 SPE 199286 Presenter: Niall Fleming
- 6. 6 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Kvitebjorn field – Cumulative gas production over 14 years from well A-4 completed with 6 5/6” single-wrap sand screens The 1st well in the initial drilling campaign. It has produced 3x more gas than the original reserves figure estimated in 2004 prior to drill-in with Cs formate brine SPE 199286 Presenter: Niall Fleming • Initial skin = 3 and PI = 166,101 Sm3 gas /day/bar • PI reducing over time due to screen plugging with CaCO3 • Gas flow choked back from 3.8 MSm3/day in Feb 2012 following sand breakthrough • Perforating through screens in 2015 increased gas flow to 3 MSm3/day Revised gas reserves estimate in 2006 after drill-in with Cs formate brine Original gas reserves estimate in 2004
- 7. 7 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Kvitebjorn field – Cumulative gas production over 14 years from well A-5 completed with 6 5/6” single-wrap sand screens The 2nd well in the initial drilling campaign. It has produced 2 x more gas than the original reserves figure estimated in 2004 prior to drill-in with Cs formate brine SPE 199286 Presenter: Niall Fleming • Initial skin = 3 and estimated initial PI = 140,000 Sm3 gas /day/bar • PI reducing over time due to screen plugging with CaCO3 • Initial gas flow of 4.4 MSm3/day had reduced to 1.8 MSm3/day by October 2018 • No interventions on this well 0 2 4 6 8 10 12 14 0 1000 2000 3000 4000 5000 CumulativeGasProduction[GSm3] Time since start-up (days) Well A-5 Well shut-in May 2007 to January 2009 (619 days) Revised gas reserves estimate in 2006 after drill-in with Cs formate brine Original gas reserves estimate in 2004
- 8. 8 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Kvitebjorn field – Cumulative gas production over 14 years from well A-15 completed with 6 5/6” single-wrap sand screens The 5th well in the initial drilling campaign. It has produced 50% more gas than the original reserves figure estimated in 2004 prior to drill-in with Cs formate brine SPE 199286 Presenter: Niall Fleming • Initial skin = 20 and estimated initial PI = 313,184 Sm3 gas /day/bar • PI reducing over time but no evidence of scaling • Gas flow rates of 4-4.5 M Sm3/d were sustained from 2008 to 2012, but had fallen to 1.8-1.9 MSm3/d by October 2018 • No sanding, no scaling and no interventions on this well Revised gas reserves estimate in 2006 after drill-in with Cs formate brine Original gas reserves estimate in 2004
- 9. 9 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Kvitebjorn field – Cumulative gas production over 14 years from well A-11 completed with a perforated 7" cemented liner The 3rd well in the initial drilling campaign. Cumulative gas production to date has exceeded the original reserves figure estimated in 2004 prior to drill-in with Cs formate brine SPE 199286 Presenter: Niall Fleming • Initial skin = 20 and initial PI = 45,516 Sm3 gas /day/bar • PI reduced by 50% over 6 years of production, 2005-2011 • Re-perforation of the Etive formation in July 2012 increased gas production from 2.6 M Sm3/d to 3.6 MSm3/d. Further re-perforations were conducted in the Ness, Tarbert and Etive formations in March 2015 • Sand breakthrough in January 2015 required production to be choked back to 3.0 M Sm3/d Revised gas reserves estimate in 2006 after drill-in with Cs formate brine Original gas reserves estimate in 2004
- 10. 10 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Kvitebjorn field – Cumulative gas production over 14 years from well A-14 completed with a perforated 7" cemented liner The 4th well in the initial drilling campaign. It has produced 2 x more gas than the original reserves figure estimated in 2004 prior to drill-in with Cs formate brine SPE 199286 Presenter: Niall Fleming • Initial skin = 15 and initial PI = 94,022 Sm3 gas /day/bar • Gas flow rates of 3-4 M Sm3/d during the first year (2005-6), but had fallen to 2.5 MSm3/d by October 2018 • Trouble-free well : no sanding and no interventions in 14 years of production Revised gas reserves estimate in 2006 after drill-in with Cs formate brine 0 2 4 6 8 10 12 14 0 1000 2000 3000 4000 5000 CumulativeGasProduction[GSm3] Time since start-up (days) Well A-14 Revised gas reserves estimate in 2006 after drill-in with Cs formate brine Four well shut-ins Dec 2006 to Aug 2011 (total 765 days)
- 11. 11 19–21 February 2020 Doubletree by Hilton Lafayette Lafayette, Louisiana, USA SPE International Conference and Exhibition on Formation Damage Control Conclusions SPE 199286 Presenter: Niall Fleming • Logging in cesium formate brine provided enhanced reservoir information - Logs showed improved reservoir quality, translating into a 33% increase in Hydrocarbon Pore Factor • Recoverable reserves were increased by 50% in 2006 after evaluating log data from first seven development wells - Recoverable reserves were increased to 79.97 GSm3 of gas and 30.13 million Sm3 of condensate • Cumulative production from Kvitebjorn field closely matches updated reserves recovery projection • Cumulative production from first 5 Kvitebjorn wells now exceeds original reserves projection for entire field - Cumulative production from the 5 wells stood at 60.1 GSm3 of gas and 20.4 million Sm3 of condensate (Oct 2018) - Production from these first 5 wells now exceeds the original recoverable reserves projection for the entire field