🛢️ TEAL 5692 13-22 3BW

Oasis Petroleum North America LLC · Mountrail County County, ND · File #42669 · Generated 2026-02-13 12:33

API: 3306105647
Target Formation: Middle Bakken
Permit Explained: Yes

📋 Permit Cycle Assessment

The permit approval (File No. 42669, effective February 1, 2026) is directly explained by Commission Order 32914 stipulation imposed due to the well's U-turn horizontal geometry and proximity to spacing unit boundaries. Regulator explicitly tied approval to Oasis' geometric design (similar to case 30304) and made approval conditional on pre-completion submission of as-built directional survey, cementing details, and fracture stimulation procedures. Supporting documentation—including anti-collision analysis, wet shoe liner justification for modified setbacks, and facility design waivers—demonstrates technical defensibility of the non-routine configuration. All permit conditions are time-sensitive and condition drilling and completion operations.

🔍 Permit Cycle Signals (4)

Commission Order 32914 stipulation requiring as-built directional survey, production liner and cementing details, and fracture stimulation procedures prior to completion of U-turn horizontal well where wellbore is closer than 500 feet to spacing unit boundary

Direct

📄 Letter from Todd L Holwege, Sr. Permit Manager, dated January 26, 2026
📅 2026-01-26 (Exact confidence)

Regulator-imposed stipulation tied to specific well geometry risk (U-turn configuration with portions <500 ft from spacing boundary). Conditions approval on submission of technical documentation before completion operations commence.

Wet shoe production liner configuration with intentional over-displacement to create 400 feet uncemented annulus at toe; permits pump-down perforating via wireline (stage 1 perforations at MD 23,038–23,278 feet)

Supporting

📄 APD Stipulations section and 'Details of Standard WetShoe' technical sheet
📅 Unknown (Missing confidence)

Justifies modified south setback at Total Depth (150 feet instead of larger setback) based on ability to frac out wet shoe and control fracture initiation. Non-routine liner design tied to permit setback variance.

Anti-collision analysis completed using certified well planners, real-time corrected surveys with 1.2 industry-standard separation safety factor, gamma ray identification in target zone, and survey frequency increasing to every 93–100 feet approaching lateral crossings

Supporting

📄 APD Stipulations 'ANTI-COLLISION STATEMENT' and Anticollision Report dated January 12, 2026
📅 2026-01-12 (Inferred confidence)

Demonstrates pre-drilling risk mitigation for complex U-turn geometry in proximity to existing MALLARD and ROSS offset wells. Confirms technical rigor supporting approval of non-standard well configuration.

Indirect heater setback exemption under Case No. 28949 Order No. 31500 permitting placement within 60 feet of wellhead and 21 feet of oil tank (in lieu of heated treater)

Supporting

📄 APD 'FACILITY STATEMENT' section
📅 Unknown (Missing confidence)

Pre-existing regulatory waiver referenced in facility design; reduces setback constraints on surface equipment, supporting pad layout approval.

📖 Historical Context (4)

Multiple offset wells in immediate vicinity (MALLARD 5692 wells at various numbers and laterals, ROSS wells); anti-collision report flags Level 3 separation warnings on at least 8 offset well comparisons, indicating persistent geometric constraint
📄 Anticollision Report dated January 12, 2026; well location plat showing MALLARD and ROSS wellbores within section · 📅 2026-01-12
Offset well density and separation-factor violations (SF <1.0 on MALLARD 5692 31-22 5T, 31-22 6B, 31-22 8B) mean drilling execution must maintain real-time survey discipline and potential drilling pauses/adjustments to maintain safe clearance. Constraint persists through spud and drilling phases.

Filter sock and solid waste disposal requirement per NDAC 43-02-03-19.2 (letter dated May 30, 2025); leak-proof on-site container required from spud through completion, with listed approved disposal facilities by county
📄 Letter from Mark F. Bohrer, Assistant Director, dated May 30, 2025 · 📅 2025-05-30
Operational obligation effective from spud date forward; compliance required throughout drilling, cleanup, and completion phases. Non-compliance may trigger enforcement action or well suspension.

Diesel-based hydraulic stimulation fluids prohibition (CAS Registry Nos. 68334-30-5, 68476-34-6, 68476-30-2, 68476-31-3, 8008-20-6); applied to this well
📄 APD permit stipulations under 'DIESEL BASED STIMULATION FLUIDS/COMPOUNDS' · 📅 Unknown
Restricts chemical selection in fracture stimulation design; operator must pre-approve all fluid systems for completion phase. Violation during frac operations could trigger regulatory enforcement.

Closed mud system with no cuttings pit requirement; perimeter berm required; remote or automatic shutoff devices on all equipment
📄 APD permit stipulations under 'Permit Review Policy' and 'Conditions of Approval' · 📅 Unknown
Operational and environmental controls active from construction through drilling; non-compliance subject to field inspector enforcement. Contact NDIC Field Inspector Dylan Roach (701-770-1981) required prior to conductor setting.

🔧 Operator Pattern

Oasis Petroleum demonstrates established operational infrastructure in Mountrail County Bakken development with multi-well pads (TEAL 5692 pad contains 3BW, 2BX, 4BX, and prior 13-22H); utilizes certified well planning, advanced survey correction, and pre-drilling technical analysis to navigate complex offset well geometries.
Anti-collision reports show comprehensive offset database and risk evaluation across 8+ nearby laterals. Multiple well designs on single pad indicate coordinated development strategy. No permit deviations or non-compliance signals noted in file.

Confidence: High
Permit approval letter is explicit and dated (January 26, 2026). Commission Order 32914 is clearly referenced and tied to specific well geometry condition. Supporting technical documents (anti-collision report, planning reports, facility statements) are complete and dated. Setback stipulations and operational conditions are clearly stated in APD. No conflicting or missing foundational approvals detected.