TECHNICAL DATA SHEET Curable resin-coated sand proppant Features Benefits • • • • CARBOBOND resin-coating reinforces premium Northern White substrate 100% encapsulation of the substrate Full compatibility with complicated fluid systems Closure stress spread over larger contact point, reducing effective stress per grain • Provides excellent crush resistance and conductivity under downhole conditions • • • Eliminates proppant flowback to prevent equipment damage Reduces costs of additional chemicals, cleanouts and disposal Prevents fines from being released if pack is over stressed Resin-coated sand engineered for maximized production The novel CARBOBOND® RCS resin-coated sand proppant is specially designed to strengthen the premium frac sand substrate to help increase conductivity and production. As the cost-effective CARBOBOND RCS is customized for each application, it can be pumped as designed, thus eliminating additional chemical costs. Long-term conductivity 2 lb/ft2, 250°F, with 2% KCI | Between Ohio sandstone Reference conductivity, md-ft @ 250˚F (121°C) 20/40 30/50 40/70 2,000 (14) 4,715 (1,437) 2,460 (750) 1,430 (436) 4,000 (28) 4,160 (1,268) 2,305 (703) 1,300 (396) 6,000 (41) 2,720 (829) 1,800 (549) 1,020 (311) 8,000 (55) 1,615 (492) 1,125 (343) 635 (194) 10,000 (69) 795 (242) 540 (165) 275 (84) 20/40 4,000 30/50 3,000 40/70 2,000 1,000 Reference permeability, Darcies @ 250˚F (121°C) Closure stress psi (MPa) Conductivity, md-ft Closure stress psi (MPa) 5,000 20/40 30/50 40/70 0 2,000 (14) 260 140 80 2,000 (14) 4,000 (28) 230 130 70 6,000 (41) 155 105 60 8,000 (55) 95 65 35 10,000 (69) 50 35 15 Reference conductivity and permeability are measured with a single phase fluid under laminar flow conditions in accordance with API RP 19D. In an actual fracture, the effective conductivity will be much lower due to non-Darcy and multiphase flow effects. For more information, please refer to SPE Paper #106301 - “Determining Realistic Fracture Conductivity and Understanding its Impact on Well Performance –Theory and Field Examples.” 4,000 (28) 6,000 (41) 8,000 (55) Closure stress, psi (MPa) 10,000 (69) Curable resin-coated sand proppant Bond strength performance Unconfined compressive strength 250 (121) Closure stress Time Bond strength psi (mPa) psi (MPa) hr 20/40 30/50 40/70 1,800 0 (0) 1,000 (6.895) 24 <50 (0.345) <50 (0.345) <50 (0.345) 1,600 4 857 (5.909) 1,050 (7.239) 1,323 (9.122) 1,400 12 1,093 (7.536) 1,337 (9.218) 1,522 (10.494) 1,200 24 1,208 (8.329) 1,415 (9.756) 1,604 (11.059) 48 1,315 (9.067) 1,441 (9.935) 1,727 (11.907) UCS, psi Fluid temp °F (°C) Unconfined compressive strength 2,000 250°F, 40/70 250°F, 30/50 250°F, 20/40 1,000 800 600 For bottomhole static temperature (BHST) less than 150°F/65°C use CARBOBOND Low Temperature Chemical Activator (LTCA) to enhance bond strength. LTCA may also be beneficial in cold weather conditions. 400 0 12 0 Pack strength performance Closure stress psi (MPa) 24 Shut-in-time, hr Crush resistance, % by weight fines generated 20/40 30/50 40/70 6,000 (41.4) 1.13 0.41 0.26 8,000 (55.2) 3.20 1.42 0.57 10,000 (69.0) 6.30 2.44 0.99 12,000 (82.7) 10.20 4.49 1.76 15,000 (103.0) 17.80 8.93 3.12 Physical and chemical properties Typical chemical properties Resin type Proprietary Phenolic Equilibrium pH 8.9 - 9.3 Residual acidity per gal 50% NaOH/1000 gal 2% KCI Typical physical properties Available sizes 20/40, 30/50, 40/70 Substrate Premium frac sand Physical state Solid, particulate Apparent specific gravity 2.55 ± 0.05 Specific volume (cm /g) 0.047 Weight % Bulk density [lb/ft3] (g/cm3) 87 ± 4 1.40 ± 0.06 Water < 0.2 Roundness ≥ 0.7 Alkaline water* uncured < 1.0 Sphericity ≥ 0.7 Alkaline water* cured < 0.2 Water with 2% KCI < 0.2 Particle size distribution uncoated sand substrate Meets or exceeds API RP 19C Light brine < 0.3 Turbidity, (NTU) [FTU] < 250 12% HCI/3% HF Acid < 1.0 Coating efficiency (weight %) > 99.8 Oil < 1.0 Bond strength See included chart Long-term conductivity See included chart Shelf-life (years) Solubility: ISO 13503-2 < 0.1 > 3 estimated *66°C, unbuffered 2% KCl, adjusted to pH = 11, 1.4 kg/L added Compatibility: Compatible with most commonly used fracturing fluids, both water and oil. Testing with fluids prior to pumping is advised. Some fluids may require adjustment of pH control, breaker or foamer loading. Avoid prolonged exposure to highly alkaline fluids, i.e., pH > 12 and > 2¼ gal 50% NaOH/1000 gal (2.2 L/m3). All data represents typical values. Talk to CARBO to find out how we can help you enhance your production. carboceramics.com © 2014 CARBO Ceramics Inc. All Rights Reserved. 1001_87.4 3 36 48