| Tier | Signal | Date | Service Impact |
|---|---|---|---|
| Tier 2 |
Waiver approved for tubing/packer requirement, with assurances on casing integrity and monitoring for flowback. 📄 Sundry Form 257134 Allows deferral of production equipment installation until after flowback, optimizing capital timing. |
2025-07-07 | Regulatory / Permitting |
| Tier 2 |
Wet shoe design with frac-out capability for toe section. 📄 Wellbore Schematic Enables frac operations without dedicated toe prep, simplifying completion. |
Unknown | Completions / Frac |
| Tier 3 |
Lateral drilled in one run with Reed RH54-A1 bit and Baker mud motor, steered via Starsteer software. 📄 Geological Summary Single-run lateral completion suggests efficient BHA and steering technology. |
2025-11-25 | Directional Drilling |
| Tier 3 |
Formation tops deviated from prognosis: Base of Last Salt 1' high, Mission Canyon 3' low, Lodgepole 3' low. 📄 Geological Summary and Formation Tops table Adjustments to landing target from 9,436' to 9,430' TVD indicate real-time geological steering. |
2025-11-22 | General Oilfield Services |
| Tier 3 |
Waiver approved for filter sock container exemption, citing no filtration use during drilling phase. 📄 Sundry Form 257127 Reduces regulatory compliance costs by avoiding container maintenance on site. |
2025-07-10 | Regulatory / Permitting |
| Tier 3 |
Waiver approved for open hole logs, relying on offset well data within 1 mile. 📄 Sundry Form 257109 Avoids redundant logging, citing proximity to existing logged well. |
2025-07-07 | Regulatory / Permitting |
| Tier 3 |
Waiver approved for drill cutting samples in vertical section, collecting from adjacent well instead. 📄 Sundry Form 257116 Shares sampling burden across pad wells, reducing per-well costs. |
2025-07-07 | Regulatory / Permitting |