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Economic benefits from using formate brines - Latest paper

Economic benefits from using formate brines - Latest paper. Economic benefits from using formate brines - Good well performance and recovery of reserves. “ High production rates with low skin” * “ We selected formate brine to minimise well control problems

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Economic benefits from using formate brines - Latest paper

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  1. Economic benefits from using formate brines - Latest paper

  2. Economic benefits from using formate brines - Good well performance and recovery of reserves • “High production rates with low skin” * • “ We selected formate brine to minimise well control problems and maximise well productivity”* * Quotes by Statoil relating to Kvitebjoern wells (SPE 105733)

  3. Economic benefits from using formate brines - More efficient and safer drilling • Better/safer drilling environment saves rig-time costs • Stable hole: see LWD vs. WL calipers in shale • Elimination of well control* and stuck pipe • incidents • Good hydraulics, low ECD • Good ROP in hard abrasive rocks • * See next slide for details “ a remarkable record of zero well control incidents in all 15 HPHT drilling operations and 20 HPHT completion operations”

  4. Formate Brines : Allow fast solids-free drilling Solids-free formate brines drill deep horizontal well sections much faster than muds like OBM – and cause less formation damage

  5. Economic benefits from using formate brines - Improved well control and safety • Elimination of barite and its sagging problems • Elimination of oil-based fluids and their gas solubility problem • Low solids brine  Low ECD (SG 0.04-0.06) and swab pressures • Inhibition of hydrates • Ready/rapid surface detection of well influx • Elimination of hazardous zinc bromide brine

  6. Economic benefits from using formate brines - More efficient/faster completions • - Drill-in and completing with • formate brine allows open hole • completion with screens • - Clean well bores mean no tool/seal • failures or blocked screens • - Completion time 50% lower than • wells drilled with OBM • “ fastest HPHT completion operation ever performed in North Sea (12.7 days)”

  7. Economic benefits from using formate brines - Operational efficiencies Flow check fingerprint for a Huldra well • No differential sticking • Pipe and casing running speeds are fast • Mud conditioning and flow-check times are short • Displacements simplified, sometimes eliminated

  8. Economic benefits from using formate brines - Good reservoir definition if Cs present in fluid • High density filtrate and no barite • Filtrate Pe up to 259 barns/electron • Unique Cs feature - makes filtrate invasion • highly visible against formation Pe of 2-3 b/e • LWD can “see” the filtrate moving (e.g. see • the resistivity log on far right – drill vs ream • Good for defining permeable sands (see • SAND-Flag on log right ) • Consistent and reliable net reservoir definition • from LWD and wireline

  9. Economic benefits from using formate brines - Good reservoir imaging • Highly conductive fluid • Clear resistivity images • Information provided: • - structural dip • - depositional environment • - geological correlations

  10. Formate brines – Summary of economic benefits provided to users Formate brines improve oil and gas field development economics by : • Reducing well delivery time and costs • Improving well/operational safety and reducing risk • Maximising well performance • Providing more precise reservoir definition

  11. Managed pressure drilling and completion of fractured carbonates with formate brine SPE 165761 (2012) “ Experience with Formate Fluids for Managed Pressure Drilling and Completion of Sub-Sea Carbonate Gas Development Wells” • Petronas - Kanowit field – 2 sub-sea gas wells • Managed pressure drilling in fractured carbonate • with K formate brine improved economics by: • - Minimising fluid losses • - Reducing fluid cost (use K formate instead of Cs formate) • - Improving production by 50% • - Eliminating need for stimulation (no acidising)

  12. Kanowit SS-1 : Production profile from start-up - natural clean-up – no stimulation • 100 MMscfd gas and 4,000 bpd condensate after 5 hours • >150 MMscfd gas and > 6,000 bpd condensate after 9 hours

  13. Kanowit SS-1 : Multi-rate well test results Both wells can produce > 150 MMscfd gas and > 6,000 bpd condensate The maximum potential flow rate figures are 50% higher than the technical potential predicted in the original field development plan.

  14. Formate brines as packer fluids in GOM

  15. BP High Island – Formate brine used as a packer fluid for 6 years • 177ºC, 14,000 psi • S13Cr tubing failed from CaCl2 packer fluid • Well worked over and re-completed with Cs formate • 1.4 g/cm3 Na/K formate used as packer fluid • Tubing retrieved 6 years later • Tubing was in excellent condition.

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