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SPE 165151 Gunnar Olsvik and Siv Howard, Cabot Specialty Fluids John Downs, Formate Brine Ltd

The Long-Term Production Performance of Deep HPHT Gas Condensate Fields Developed Using Formate Brines. SPE 165151 Gunnar Olsvik and Siv Howard, Cabot Specialty Fluids John Downs, Formate Brine Ltd. SPE European Formation Damage conference , Noordwijk, The Netherlands, 5-7 June 2013.

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SPE 165151 Gunnar Olsvik and Siv Howard, Cabot Specialty Fluids John Downs, Formate Brine Ltd

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  1. The Long-Term Production Performance of Deep HPHT Gas Condensate Fields Developed Using Formate Brines SPE 165151 Gunnar Olsvik and Siv Howard, Cabot Specialty Fluids John Downs, Formate Brine Ltd SPE European Formation Damage conference , Noordwijk, The Netherlands, 5-7 June 2013

  2. Formate brines Formates are also soluble in some non-aqueous solvents SPE European Formation Damage conference, 5-7 June 2013

  3. Formate brines for HPHT gas wells Low-solids heavy fluids for deep HPHT gas well constructions • Reservoir drill-in • Completion • Workover • Packer fluids • Well suspension • Fracking (OHMS) Used in hundreds of HPHT wells since 1995, including some of Europe’s deepest, hottest and highly-pressured gas reservoirs SPE European Formation Damage conference, 5-7 June 2013

  4. 42deep HPHT gas fields developed using formate brines, 1995-2011* (published data) * Now more HPHT fields in Kuwait, India and Malaysia during 2012-2013 SPE European Formation Damage conference, 5-7 June 2013

  5. The economic benefits of using formate brines in HPHT gas field developments – Reference papers • SPE 130376 (2010): “A Review of the Impact of the Use of Formate Brines on the Economics of Deep Gas Field Development Projects” • SPE 145562 (2011): “Life Without Barite: Ten Years of Drilling Deep HPHT Gas Wells With Cesium Formate Brine” 5 SPE European Formation Damage conference, 5-7 June 2013

  6. Formate brines – The economic benefits provided in HPHT gas field developments Formate brines tend to improve oil and gas field development economics by : • Reducing well delivery time and costs - 12 years of use with screens - Very good with ESS • Improving well/operational safety and reducing risk • Delivering production rates that exceed expectations • Providing more precise reservoir definition SPE European Formation Damage conference, 5-7 June 2013

  7. Several highlights from some Kvitebjoern HPHT gas wells drilled and completed with formates Fast open hole screen completions and high well productivity Operator quote after well testing (Q3 2004 ) “The target well PI was 51,000 Sm3/day/bar This target would have had a skin of 7” “A skin of 0 would have given a PI of 100,000” “THE WELL A-04 GAVE A PI OF 90,000 Sm3/day/bar (ANOTHER FANTASTIC PI)” The Well PI was almost double the target * Fastest HPHT well completion in the North Sea SPE European Formation Damage Conference, 5-7 June 2013

  8. But productive for how long ? Objectives of the analysis presented in this paper : • Map the production profiles of North Sea HPHT fields where formate brines were the last fluids to contact the reservoirs in every well • Compare actual cumulative production over time against published estimates of recoverable reserves at start-up • See if the well construction design influences the production profile (e.g. Cased vs. Open hole completions) SPE European Formation Damage conference, 5-7 June 2013

  9. Reviewed long-term production from 8 North Sea HPHT gas condensate fields in 3 categories Production data obtained from UK DECC and Norwegian NPD websites SPE European Formation Damage conference, 5-7 June 2013

  10. Tune field – semi-HP/HT gas condensate reservoir drilled and completed with formate brines, 2002 4 wells : 350-900 m horizontal reservoir sections. Open hole screen completions. Suspended for 6-12 months in formate brine after completion SPE European Formation Damage conference, 5-7 June 2013

  11. Tune wells - Initial Clean-up – Operator’s view (direct copy of slide) June 2003 • Wells left for 6-12 months before clean-up • Clean-up : 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 11 SPE European Formation Damage conference, 5-7 June 2013

  12. Tune – Production of recoverable gas and condensate reserves since 2003 (NPD data) • Good early production from the 4 wells • - « No skin» • - 12.4 million m3 gas /day • - 23,000 bbl/day condensate • Good sustained production • - 90% of recoverable hydrocarbon • reserves produced by end of Year 7 • NPD current estimate of RR: • - 18.3 billion m3 gas • - 3.3 million bbl condensate • Open hole screen completions and single filtrate SPE European Formation Damage conference, 5-7 June 2013

  13. Huldra field – HPHT gas condensate reservoir drilled and completed with formate brines, 2001 • 6 production wells • 1-2 Darcy sandstone • BHST: 147oC • TVD : 3,900 m • Hole angle : 45-55o • Fluid density: SG1.89-1.96 • 230-343 m x 81/2” reservoir sections • Open hole completions, 65/8” wire wrapped • screens • Lower completion in formate drilling fluid and • upper completions in clear brine SPE European Formation Damage conference, 5-7 June 2013

  14. Huldra – Production of recoverable gas and condensate reserves since Nov 2001 (NPD data) • Plateau production from first 3 wells • - 10 million m3 gas /day • - 30,000 bbl/day condensate • Good sustained production • - 78% of recoverable gas and 89% of • condensate produced by end of Year 7 • - Despite rapid pressure decline..... • NPD current estimate of RR: • - 17.5 billion m3 gas • - 5.1 million bbl condensate • Open hole screen completions and single filtrate SPE European Formation Damage conference, 5-7 June 2013

  15. Kvitebjørnfield – HPHT gas condensate reservoir drilled and completed with formatebrines, 2004-2013 • 13 wells to date – 8 O/B, 5 in MPD mode • 100 mD sandstone • BHST: 155oC • TVD : 4,000 m • Hole angle : 20-40o • Fluid density: SG 2.02 for O/B • 279-583 m x 81/2” reservoir sections • 6 wells completed in open hole : 300-micron single wire-wrapped • screens. • Remainder of wells cased and perforated SPE European Formation Damage conference, 5-7 June 2013

  16. Kvitebjørn– Production of recoverable gas and condensate reserves since Oct 2004 (NPD data) • Good production reported from first 7 wells in 2006 - 20million m3 gas /day • - 48,000 bbl/day condensate • Good sustained production (end Y8) • - 37 billion m3 gas • - 17 million m3 of condensate • - Produced 70% of original est. RR by • end of 8th year • NPD : Est. RR have been upgraded • - 89 billion m3 gas (from 55) • - 27 million m3 condensate (from 22) • Note : Shut down 15 months, Y3-5 • - To slow reservoir pressure depletion • - Repairs to export pipeline SPE European Formation Damage conference, 5-7 June 2013

  17. Formate brines have been used to complete all of the cased wells in 5 HPHT fields in UK North Sea All wells drilled with OBM * The deepest, hottest and highest-pressured fields in UK North Sea SPE European Formation Damage conference, 5-7 June 2013

  18. Fluid losses from HPHT wells in UK North Sea perforated in formate brines SPE European Formation Damage conference, 5-7 June 2013

  19. Braemar field – Production of recoverable gas and condensate reserves since September 2003 (DECC data) • Estimated (2003) recoverable reserves produced in full from this single well development by Year 9 • Estimated recoverable reserves • - 3.28 billion m3 gas • - 1.59 million m3 condensate • Cumulative production @Sep 2012 • - 3.4 billion m3 gas • - 1.9 million m3 condensate SPE European Formation Damage conference, 5-7 June 2013

  20. Glenelg – Production of gas and condensate since March 2006 (DECC data) • No published reserves information ? Similar to Braemar ? • Highest temperature and pressure reservoir developed in UK North Sea (2006), accessed by single extended reach well • Good initial production • Operator statements : • - «30,000 boe/day capability» • - «500,000 m3/year condensate» • Cumulative production @ Feb 2011 • - 2.2 billion m3 gas • - 2.13 million m3 condensate SPE European Formation Damage conference, 5-7 June 2013

  21. West Franklin – Production of gas and condensate from West Franklin/Franklin 2001-11 (DECC data) • No published reserves information. Hottest, highest pressure commercial development in world (2007), accessed by two extended reach wells, F7z and F9y • Excellent initial production • Operator statements : • - « F9y has 40,000 boe/day capability» • - «one of most productive wells in • N. Sea» • - «2.6 million m3/day of gas from F9y» • West Franklin has sustained • the Franklin field output • - > 2.5 billion m3 gas per year from Y6 • onwards • Note : 566 m3 of cesium formate brine was pumped into formation around F9Y SPE European Formation Damage conference, 5-7 June 2013

  22. BP Rhum field – largest undeveloped gas field in UK in 2005 45 mD sandstone reservoir SPE European Formation Damage conference, 5-7 June 2013

  23. Rhum field – Production of recoverable gas reserves: December 2005- October 2010 (DECC data) • After nearly 5 years the 3 Rhum production wells had produced 35% of the estimated recoverable gas reserves • Estimated recoverable reserves • - 23 billion m3 gas • Cumulative production Oct 2010 • - 7.9 billion m3 gas • Production suspended since late • 2010 • - EU sanctions against Iran SPE European Formation Damage conference, 5-7 June 2013

  24. Jura – Production of gas and condensate since May 2008 (DECC data) • Estimated (2008) proved and probable reserves of 170 million boe – no published segmentation by hydrocarbon type • Good initial production from 2 wells • - 1.87 billion m3 gas produced during Y2 • Cumulative production @ June 2012 • - 6.58 billion m3 gas • - 1.1 million m3 condensate • = 46 million boe in total • = 27% production of est. RR after 4 years SPE European Formation Damage conference, 5-7 June 2013

  25. Conclusions – Cat 1 HPHT wells - Drilled and completed in high-angle open hole with formate brines Tune and Huldra fields produced 100% of recoverable gas and condensate reserves within 10 years – average 3.5 billion m3 gas/well Gas – 90% in 7-8 years Condensate – 90% in 5-7 years Provides evidence that drilling and completing HPHT gas production wells in open hole with formate brines can be a successful strategy Formate Brine Seminar - Stavanger, 22 November 2012

  26. Conclusions – Cat 2 HPHT wells - Drilled and completed in open- and cased-hole with formate brines Kvitebjørn field has produced 70 % of the original estimated reserves by end of Year 8 – despite production constraints • Gas production has been at a steady 6-7 billion m3/year for last 4 years – already produced 3 billion m3 gas per well • Need more time to see how the production progresses towards upgraded recoverable reserves estimate • Good chance to compare durability of open- hole versus cased-hole HPHT wells ? Formate Brine Seminar - Stavanger, 22 November 2012

  27. Conclusions – Cat 3 HPHT wells - drilled with OBM and completed in cased-hole with formate brines (no pill) Braemar and Glenelg are both small rich-gas condensate fields drained by single cased wells perforated in formate brines without kill pills. Low brine losses. • Braemar reached original est. RR figure by Year 9 • Glenelg following same gas production track and already exceeded 2 million m3 condensate production by Year 5 Formate Brine Seminar - Stavanger, 22 November 2012

  28. Conclusions – Cat 3 HPHT wells - drilled with OBM and completed in cased-hole with formate brines (no pill) West Franklin is a «200 million boe» gas condensate field currently drained by 2 cased wells, perforated in formate brines. Large brine volume pushed into reservoir from well F9y • No cumulative production data available but was apparently producing >30,000 boe/day in the 4 years before Elgin gas leak in March 2012 • West Franklin Phase 2 development in progress Too early to get a picture of long-term production performance Formate Brine Seminar - Stavanger, 22 November 2012

  29. Conclusions – Cat 3 HPHT wells - drilled with OBM and completed in cased-hole with formate brines+ kill pill Rhum and Jura are lean gas condensate fields drained by 3 and 2 cased wells respectively, perforated in formate brines with kill pills • Rhum : 35% recovery of gas reserves by Year 5, before production suspended • Jura : 27% recovery of gas reserves after 4 years Too early to get a picture of long-term production performance Formate Brine Seminar - Stavanger, 22 November 2012

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