Independent fracture model design study evaluating Hallux Mannanase HT enzyme breaker across five completion designs in the Lower Spraberry. A calibrated fracture model was developed from an offset well pressure match, then used to forecast performance across slickwater, linear gel, crosslinked gel, and hybrid fluid systems — incorporating independent regained proppant pack permeability testing and rheology properties into all modeling.
The Spraberry analog well was completed using conventional 100% slickwater with 100 mesh proppant at 2,400 lbm/ft. A calibrated fracture model was developed from an offset well production history match to establish the baseline fracture geometry and production forecast.
Using that calibrated model, five completion designs were evaluated — ranging from slickwater (Design 1, baseline) to 8# linear gel, 8#LIN/15#XL crosslinked hybrid, and SW/LIN/XL hybrid systems. All designs except the slickwater baseline utilize Hallux Mannanase HT enzyme breaker.
Designs 4 and 5 transition from 100 mesh to 40/70 natural sand with hybrid fluid systems, increasing fracture conductivity while reducing clean water volume by 15–25%.
Independent Regained Conductivity Testing:
Slickwater Baseline (no breaker): 0.49 mD-ft fracture conductivity
Hallux Mannanase HT (Patented): 90–100% Proppant Pack Clean-Up
Regained proppant pack permeability testing results and rheology properties of the Mannanase HT enzyme breakers were incorporated into all the modeling.
Not all enzymes are created equally. Designs utilizing Hallux Mannanase HT enzyme breaker delivered 24–65% more production at 1 year compared to the slickwater baseline — with fracture conductivities of 0.84–1.98 mD-ft versus 0.49 mD-ft for slickwater, while reducing clean water volume by 15–25%. At current oil prices, this translates to $1.8–4.8 million per year in additional revenue per well.
Production forecasts show 24–65% production uplifts at 1 year when using Hallux Mannanase HT enzyme breaker compared to the slickwater baseline completion.
Clean water volume reduction range of 15–25% when adjusting pump schedules from slickwater to hybrid gel systems.
Production forecast shows Designs 3, 4, and 5 with the best performance using 8#LIN/15#XL and SW/LIN/XL hybrid fluid systems with MHT enzyme breaker. Design 5 shows the strongest result with 65.2% production uplift at 1 year using a higher proppant loading of 3,000 lbm/ft.
| Model Run | Design 1 (Baseline) | Design 2 | Design 3 | Design 4 | Design 5 |
|---|---|---|---|---|---|
| Pump Schedule | SW | 8# LIN | 8#LIN / 15#XL | SW / LIN / XL | SW / LIN / XL |
| Proppant Loading | 2,400 lbm/ft | 2,400 lbm/ft | 2,460 lbm/ft | 2,475 lbm/ft | 3,000 lbm/ft |
| Proppant Type | 100 Mesh | 100 Mesh | 100 Mesh | 40/70 Natural | 40/70 Natural |
| Breaker Type | — | Hallux Mannanase HT | Hallux Mannanase HT | Hallux Mannanase HT | Hallux Mannanase HT |
| Clean Fluid, bbl | 11,199 | 10,294 | 8,960 | 8,437 | 9,580 |
| Total Fracture Height, ft | 493 | 564 | 484 | 406 | 424 |
| Propped Height, ft | 253 | 294 | 218 | 148 | 156 |
| Created Frac Half-Length, ft | 504 | 415 | 306 | 271 | 284 |
| Propped Frac Half-Length, ft | 226 | 199 | 176 | 173 | 193 |
| Avg Hydraulic Frac Width, ft | 0.036 | 0.043 | 0.076 | 0.107 | 0.108 |
| Fracture Conductivity, mD-ft | 0.49 | 0.84 | 1.93 | 1.87 | 1.98 |
| 1-year EUR, Mbbl | 99.6 | 123.8 | 161.8 | 159.9 | 164.5 |
| 2-year EUR, Mbbl | 203.8 | 241.3 | 293.9 | 291.3 | 298.4 |
| 1-year Uplift | SW Baseline | 24.3% | 62.4% | 60.6% | 65.2% |
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Design 1 (SW Baseline) — 100% slickwater with 100 mesh proppant at 2,400 lbm/ft. Propped height 253 ft, propped half-length 226 ft, fracture conductivity 0.49 mD-ft.
Mannanase HT enzyme designs (D2–D5) show 24–65% production uplift at 1 year versus the slickwater baseline. Toggle to Revenue to see the incremental value at current EIA oil prices.