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David HortonTechnical Advisor
CFS Technology Developments
© 2009 Halliburton. All Rights Reserved. 2
• CFS-488 Viscosifying Polymer
• CFS-485 Microemulsion Technology
• CFS-461 Emulsion Prevention
• Utilizing our Technology
Current Developments
© 2009 Halliburton. All Rights Reserved. 3
CFS-488Polymeric Viscosifier
© 2009 Halliburton. All Rights Reserved. 4
CFS-488CFS-488: A viscosifying polymer for utilization in drilling fluids and brines.
Primary function is viscosity and suspension
Other advantages:Reservoir friendlyAcid solubleEfficient brine solubilityCombines properties of HEC acid solubility and suspension of Xanthan gum
© 2009 Halliburton. All Rights Reserved. 5
CFS-488 RheologyCFS-488 Performance vs Xanthan at 1.5 lb/bbl in
FreshwaterPolymer CFS-488 BARAZAN D PLUS
Fann 35 dial reading600 30 24300 23 19200 18 18100 13 156 7 93 6 7
PV 7 5YP 16 14
10 s gel 8 810 min gel 13 10
CFS-488 BARAZAN D PLUS
BARAZAND PLUS
Static settling test of polymer fluidsfor 4 hr with 80 lb/bbl 20/40 meshsand.
CFS-488
Which one is better?
© 2009 Halliburton. All Rights Reserved. 6
CFS-488 Extreme Low-end Rheology
Comparison of various polymers in a 13.5 lb/gal CaCl2 / CaBr2 (20 oF blend)
Excellent performance in divalent brines
Shear thinning curve shows superior low-end rheology for improved suspension
1 % Biopolymers in 13.5 lb/gal CaBr2
10
100
1000
10000
100000
1000000
0.01 0.1 1 10 100
Shear Rate (s-1)
Visc
osity
(cP)
CFS-488
HEC
XAN
SCL
© 2009 Halliburton. All Rights Reserved. 7
CFS-488 Acid Degradation
Acid degradation testing of CFS-488 shows rapid breakdown of polymer under acidic conditions
Preferred property for ease of removal from reservoir with minimal formation damage
Acid Degradation Testing
0
20
40
60
80
100
25 75 125 175 225 275 325 375 425
Time (m)
Visc
osity
(cp)
pH 3
pH 8
FANN 50 testing at 175 oF and 100 rpm1 % polymer in 10.0 lb/gal NaBr
© 2009 Halliburton. All Rights Reserved. 8
CFS-488 Cake Clean-up
10 micron disc
3 Hours of treatment with N-FLOW 325 (10 % vol) at 120 oF
© 2009 Halliburton. All Rights Reserved. 9
Field ApplicationCFS-488 was mixed in fresh water at 2ppb concentration. Full yield of the sweep occurred within 20 minutes.
No de-foamer was added.No “fish-eyes” occurred.Rheology of the sweep:PV (cp@120F)
YP (lb/100 sq ft)
Gel (10sec)
Gel (10min)
600 (rpm)
300 (rpm)
200 (rpm)
100 (rpm)
6 (rpm)
3 (rpm)
10
32
13
27
52
42
33
21
9
6
*Fann 35 Model
© 2009 Halliburton. All Rights Reserved. 10
CFS-488 Sweep Performance
A 15bbl sweep achieved efficient hole cleaning.Foaming was observed to be less than that of previous xanthan sweeps.Customer was pleased withproduct performance.
sweep foaming
sweep returns at shaker
© 2009 Halliburton. All Rights Reserved. 11
CFS-488 Utilization
Extreme low-end rheology aids hole cleaning and suspension.Acid degradation allows for effective wellboreclean-up.Effective solubility in any brine overcomes technical challenges.
© 2009 Halliburton. All Rights Reserved. 12
CFS-485Microemulsion Technology
© 2009 Halliburton. All Rights Reserved. 13
CFS-485 Microemulsion Technology
Cleans casing and water-wets surfacesDisplacements
Removes oils in place of solventsLeaves surfaces fully water-wetMeets GoM Environmental standards
© 2009 Halliburton. All Rights Reserved. 14
True Microemulsion?
Windsor IOil and oil-in-water phase
Windsor IIOil external – Water internal(as in OBM)Kinetically stabilized macroemulsion
Windsor IIIBicontinuous (neither water –nor oil-external)Unstable microemulsion-requires shear
Windsor IVSingle phase microemulsionClear
I II III IV
© 2009 Halliburton. All Rights Reserved. 15
Why Does It Matter?
Windsor III - emulsionLarge amount of energy to create emulsionKinetically stable Cloudy (will separate)
Windsor IV - microemulsionNo energy input to createThermodynamically stable (the way nature wants it)Clear (will not separate)
IV
III
© 2009 Halliburton. All Rights Reserved. 16
OBM
CFSTM-485/ Densified Viscosified
Brine
Viscosified
Thinner
DensifiedViscosified
Brine
Surfactant
Viscosified
Solvent
OBM
Thinner
CFS™-485 Conventional
Reduce Rig Operating Time
Reduces Spacer VolumesReduces mixing & pumping timesGoM Environmentally CompliantEliminates the use of Solvents Surfactant
Solvent
GoM Spacer Train
© 2009 Halliburton. All Rights Reserved. 17
CFS-485 Utilization
Casing cleaner alternative to solvent Easily mixed at rig siteReduces over-all spacer train volumesLeaves surfaces clean and water-wetMeets GoM Environmental standards
© 2009 Halliburton. All Rights Reserved. 18
CFS-461Emulsion Prevention
© 2009 Halliburton. All Rights Reserved. 19
Emulsion Blockage
Emulsions formed inside Formation. Some zones form water/oil emulsion naturally. Water-in-oil emulsion is viscous and blocks flow.
How do we prevent Emulsion Blockage?
Utilize chemical solutions Limit any excess emulsifier in IEF Control Filtrate Loss
© 2009 Halliburton. All Rights Reserved. 20
Emulsion Prevention
© 2009 Halliburton. All Rights Reserved. 21
CFS-461 A Green Alternative: Toxicity & Biodegradability assigned GOLD rating using CHARM classification.
•Prevents Emulsion from forming
•Encourages rapid break-out
© 2009 Halliburton. All Rights Reserved. 22
CFS-461 Utilization
Proper planning of IEFMinimize excess emulsifierMinimize filtrate invasion
Lab Test for proper concentrations in brineDo not over-treat“Green” alternative to previous technology
© 2009 Halliburton. All Rights Reserved. 23
Questions?