🛢️ Phoenix 5602 13-17 3B

OASIS PETROLEUM NORTH AMERICA LLC · Williams County, ND · File #41544 · Generated 2026-02-13 12:33

API: 3310506420
Target Formation: Middle Bakken
Permit Explained: Yes

📋 Permit Cycle Assessment

The permit for Phoenix 5602 13-17 3B (File No. 41544) issued 04/08/2025 (dirt work date) is supported by contemporaneous permitting documentation that justifies and conditions the approval. The core justifications are: (1) Approved waiver of open hole logging requirement (05/15/2025) based on offset well data sufficiency, eliminating a standard drilling condition; (2) NDIC Field Order No. 32567 pool definition and non-routine setback stipulation (150' lateral setback based on wet shoe liner design), which directly conditions well geometry approval; (3) Anti-collision assessment documenting 1.2+ separation factors and real-time survey protocols required for horizontal drilling in a multi-well pad environment. The MWD survey certification (07/05/2025) retrospectively validates that the executed well remained within the stipulated setback and pool parameters established by the permit. Standard conditions (closed mud system, remote shutoff devices) are present but not elevated as they are routine APD language. No evidence of permit conditions imposed post-approval or independent of pre-drilling submissions.

🔍 Permit Cycle Signals (5)

Open Hole Log Waiver approved under NDAC 43-02-03-31. Offset well (Straw POW 5602 42-17, File No. 28007) within 1 mile has sufficient open logs to establish formation tops; GR-CBL to run TD to ground level.

Direct

📄 Sundry Form 247811, Page 2
📅 05/15/2025 (Exact confidence)

Regulatory waiver of standard logging requirement tied to offset well data sufficiency. Explicitly conditions drilling approval via approved exemption.

APD Stipulation: Bakken Setback enforced via Commission Order No. 32567. South setback based on production liner cemented in lateral with wet shoe and frac-out capability. Wellbore must remain ≥150' from north/south boundaries and ≥500' from east/west boundaries within 1920-acre spacing unit (Sections 17, 20, 29; T156N, R102W).

Direct

📄 Application for Permit for New Well - Horizontal, Page 1, Stipulations
📅 04/08/2025 (Inferred confidence)

Non-routine setback modification tied to specific well design (wet shoe liner). Conditioning factor for permit approval requiring directional control and cemented lateral design.

Bull Butte-Bakken Pool definition per NDIC Field Order: accumulation interval from 50 feet above top of Bakken to above top of Birdbear Formation. Defines productive horizon and containment perimeter.

Supporting

📄 Application for Permit for New Well - Horizontal, Page 1, Stipulations
📅 04/08/2025 (Inferred confidence)

Pool definition establishes regulatory framework for drilling and production within target. Required prior to permit issuance.

MWD Survey Certification by Total Directional Services (Bryant Grinnell). Survey data (0–26,440 MD feet) confirms actual wellbore trajectory stayed within designed parameters. Landed curve at 10,945' MD / 10,341.42' TVD (~21.5' into Middle Bakken). TD reached 26,440' MD / 10,348' TVD.

Supporting

📄 MWD Survey Certification, Directional Survey Report, Pages 1–5
📅 07/05/2025 (Exact confidence)

Post-drilling certified survey validates well executed within stipulated setback and pool parameters. Demonstrates compliance with permit trajectory and design targets.

Anti-collision assessment completed. Separation factors ≥1.2 maintained during intermediate drilling and lateral. Real-time corrected surveys every 93'–100', increasing frequency near lateral crossings. Gamma ray used to identify existing wellbore locations and avoid collisions.

Supporting

📄 Anticollision Report, Page 1; Well File Supporting Documents (Operational Procedures)
📅 10/30/2024 (Inferred confidence)

Anti-collision protocol satisfies operational safety requirement tied to horizontal drilling in multi-well pad. Demonstrates risk mitigation required for permit execution.

📖 Historical Context (3)

Well file notification (Form 4, File 238834, dated 03/28/2025) of updated production facility location per NDAC 43-02-03-48.1: flowline directed to centralized facility on different pad rather than immediate pad location. Flowline routes span multiple sections (1,756'–6,706' outside pad limits through private and state lands).
📄 Supplemental Information Sundry Form 238834, Pages 1–2; Flowline layout diagrams Exhibit A · 📅 03/27/2025
Consolidation of production infrastructure creates ongoing operational constraint affecting future maintenance, testing, and modification of surface facilities. Flowline routing across multiple landowners and sections binds the well to external infrastructure outside its direct control, requiring coordination with pad infrastructure for production operations.

Fresh Water Tank deployment notification (Form 4, File 285461, effective 12/09/2025): temporary 40K-bbl, 150' diameter AST/Poseidon tank from Rhinokore scheduled 12/03/2025–01/25/2026. Tank feeds Phoenix and Ellis 5602 frac and coil operations (6 wells total). Coordinates: 48.34244°N, 103.84168°W.
📄 Sundry Notice for Well File No. 41544 (Form ID 285461), Pages 1–2 · 📅 12/03/2025
Temporary facilities create time-bound operational dependency for completion/stimulation phase. Tank location and water supply logistics affect frac scheduling and may require renewal or modification if completion operations extend beyond scheduled removal date.

Cores and samples preservation requirement letter (State Geologist, North Dakota DMR, dated per standard notice): Operator must collect drill cuttings at specified intervals (30' max in vertical/build; 200' max in lateral), wash, dry, and box samples for shipment to ND Geological Survey Core Library within 30 days of drilling completion. Samples began collection at Base of Last Charles Salt (9,000' MD).
📄 Cores and Samples Letter, North Dakota Century Code Section 38-08-04; NDAC 43-02-03-38.1 · 📅 Unknown
Regulatory obligation persisting beyond permit issuance. Sample collection and archival requirements impose timeline constraints (30-day shipment deadline post-drilling) and operational logistics affecting wellsite protocols through drilling completion.

🔧 Operator Pattern

Oasis Petroleum (now subsidiary of Chord Energy) operates multi-well pads in Bull Butte field with consolidated production infrastructure and standardized anti-collision protocols. Well file demonstrates proactive regulatory compliance: early waiver requests, pre-drilling anti-collision analysis, and centralized facility planning.
Phoenix 5602 13-17 3B is part of 6-well pad (Phoenix and Ellis series 2B, 3B, 4B) with coordinated drilling from single location. Pre-permit infrastructure notifications (03/2025) and centralized CTB facility diagrams show integrated development planning. Anti-collision report references offset wells operated by Oasis (SOMERSET 5602 12-17H, DRIESBACH 5602 44-32H in adjacent sections), indicating systematic well placement within operator-controlled acreage blocks.

Confidence: High
Permit documentation is complete with clear approval chain: APD issued 04/08/2025 (dirt work date), waiver approved 05/15/2025 (pre-spud), well spud 05/21/2025, drilling completed 07/05/2025, survey certified 07/05/2025. Field Order and pool definition are foundational regulatory instruments predating this well. All setback stipulations are tied to specific well design (wet shoe, 26,440' MD lateral). Anti-collision report dated 10/30/2024 shows pre-drilling technical validation. No contradictions between permit requirements and actual execution. MWD survey confirms wellbore stayed within stipulated parameters. Historical signals (flowline, tank, samples) are clearly separated from permit cycle and do not obscure permit justification.