shale drilling with potassium formate brine - chevron encana presentation
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Chevron and Encana inrease their drilling rates in shale with potassium formate brineTRANSCRIPT
Using formate brine and water based fluids drilling fluids to improve drilling performanceA case study in PipestoneRyan Siemens and Elie MeyerDrilling EngineersCalgary | September 16 | 2014
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This presentation of Encana Corporation (“Encana”) on using formate brine and water based fluids drilling fluids to improve drilling performance (this “Presentation”) is for general information purposes only.
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Agenda
• Pipestone well design• 2013 Invert performance summary• Introduction to brine fluids• Why use potassium formate brine• Special operational considerations• Design and results of field trial• Potassium formate 1.0 performance• Potassium formate 2.0 performance• Cost of utilization• Challenges and limitations
Sour service pipe design
Halfway 18 % - Doig 11% - Montney 8%
Mud 90/10 invert (oil-based mud) for hole stability and lubricity
LWD resistivity utilized to geosteer
244.5mm J-55 Surface Casing
~600m
177.8mm L-80 Intermediate Casing
Set at ~70°(Surface to ~2550m)
TVD 2400-2700 m
222mm intermediate hole
Liner Hanger Packer Set at ~35°
2200m leg~41 days Spud to RR
Pipestone well designHorizontal open hole set packers
2013 Invert performance summary
Introduction to brine fluids• Salt
– Ionic compounds that result from the neutralization reaction of an acid and a base
• Brine– Dissolved solution of salts, most commonly solvent is water
• pH– The ratio of hydroxide ions to hydronium ions determines a
solution pH • Formate Brine
– Formate brines are the aqueous solutions of the alkalimetalsalts of formic acid. These salts are readily soluble in water, yielding high-density brines
• Sodium formate• Potassium formate• Cesium formate
What is the brine advantage?
Solids (%)
Yield Pt.(Pa)
Plastic Vis.(mPa.s)
Thermal Cap.(J/g.°C)
ThermalCond. (W/m.K)
Water/brine 0-1 0 -1 1 - 2 0.6 4.2
Oil/invert 10-18 4 - 8 10 - 40 0.2 2
Why potassium formate brines?Corrosion & lubricity
Halide brine corrosion damageW. Canadian examples
Corrosion testing results
Formation compatibility testing
distilled water – potassium formate – calcium bromide – calcium chloride
Solids control setupBead recovery unit & davelin tank
FluidSolidsBeads
Temperature limitation
Temperature limitationResults
Potassium formate trial pad
Potassium formate parametersRate of penetration, length of runs
13 m/hr. vs. 24 m/hr.236 m vs. 850 m
Potassium formate parametersStandpipe pressure
~6000 kPa25%
Potassium formate parametersRotary torque
Increase bead concentration
Potassium formate trial pad
8-11 days
Potassium formate trial padNormalized lateral meterage
4-7 days~40%
Potassium formate 1.0 performance2014 Q2 time depth vs. 2013 invert
Potassium formate 1.0 performance2014 Q2 time depth vs. 2013 invert
10 days~30%
Potassium formate 1.0 performance2014 Q2 time depth vs. 2013 invert – normalized lateral
Potassium formate 1.0 performance2014 Q2 time depth vs. 2013 invert – normalized lateral
10 days~40%
Potassium formate 2.0 performanceFloc/formate vs. invert in intermediate section
2.5 days~30%
But isn’t formate too expensive?Comparing fluid cost
125 %
250 %
320 %
360 %
100 %
Cost of serviceMud cost & total service cost
• tank farm• bead unit• davlin tank• agitator
• Invert surcharge
17 %
27 %
Total drilling well costInvert vs. formate 2013 - 2014
11 %
27 %
Total drilling well costLaterals greater than 2000 m invert vs. formate
27 %
Total drilling well costFormate in lateral vs. floc/formate in intermediate
12 %
Challenges & limitations
Lubricity
Increased drag
Limitation to well length
Switching to invert at toe
Using invert for
liner install
Key Contributors & References
Encana drilling team– Nathan Gullacher– Don Poffenroth– James Highet– Ryan Siemens– Bill Mulloy– Elie Meyer– Lois McCorriston
External– Nick Legacy (DMK)– Chris Kostiuk (DMK)– Kelly Burake (DMK)– Wade Wondrasek (Paramount)
Formate Technical Manual (Cabot)Pertrofrom Technical Manual (ADDCON)SPE 27143 – 105733 – 145562
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