File #41973 | DEVON ENERGY WILLISTON, L.L.C | Williams County
API
3310506604
Target Formation
Middle Bakken
Permit Explained
Yes
Permit Cycle Assessment
The well file contains contemporaneous documentation that directly explains and justifies the permit-cycle actions. The primary driver is defective cement on the 7" casing (8,650'-10,050' MD), identified by cement bond log dated 01/06/2026. DMR approved a time-limited deferral of remediation (until 02/01/2027) contingent on: (1) mechanical integrity testing (9,800 psi, 30-min hold, no leak-off); (2) RCBL validation of 4.5" liner isolation; (3) frac string deployment from surface per regulatory standard; (4) 175-foot minimum offset from intermediate shoe during perforation/stimulation; (5) post-flowback remedial work (squeeze cement and scab liner installation) with mandatory post-squeeze CBL prior to final casing work. Verbal approval and three successive sundries (Casing/Cement Waiver 01/27/2026, Continued Stimulation 01/12/2026, and Drill Cuttings Waiver 01/29/2026) provide explicit regulatory authorization and protective measures. The cement deficiency is the sole non-routine trigger; all other conditions are standard for horizontal Bakken development.
Permit Cycle Signals (4)
Defective 7" casing cement (8,650'-10,050') documented on CBL; no cement below ~8,650' at shoe. Regulator (DMR) approved deferral of remediation and permitted stimulation operations subject to protective conditions. (01/26/2026 to 01/27/2026)
This defective cement triggered non-standard permitting conditions. DMR CBL review on 1/6/26 interpreted cement indicators at 7" shoe, but operator initially proposed delaying remediation. Approval was conditioned on specific protective measures (frac string from surface, 175' offset from intermediate shoe, post-stimulation remedial plan) that directly condition the well's completion and stimulation authority.
Verbal approval to proceed with stimulation of four-well pad with explicit stipulations tied to defective cement deficiency and correlative rights protection. Three mandatory precautions specified: (1) frac string from surface per 43-02-03-27.1, (2) 175' offset from 7" casing shoe for nearest stage, (3) sundry for remedial work required prior to completion of remediation. (Relative | January 2026)
Regulator-issued verbal approval with three explicit operational stipulations. This is direct evidence that the cement deficiency triggered non-routine completion geometry constraints (frac string requirement, offset distance mandate) that would not appear in routine APD approvals.
Sundry Form FORM ID 292297 (01/12/2026): Operator request to perform stimulation prior to remediation, with detailed mechanical integrity validation (7" casing pressured to 9,800 psi for 30 min, no leak-off; RCBL confirms high-quality cement in 4.5" lateral to 13,000' MD; cement indications at 7" shoe). Approved by regulator with condition: perfs no closer than 175' from intermediate shoe; remediation (squeeze and scab liner) required after initial flowback; post-squeeze CBL required prior to scab liner installation. (01/12/2026)
This is the primary permit document that explicitly justifies deviation from standard cementing requirements. It documents the technical case (MIT, RCBL data) and regulator approval of a time-bound deferral of remediation tied to specific post-stimulation milestones (ESP drawdown, CBL re-run, scab liner installation).
Drill Cuttings Sampling Waiver (Sundry FORM ID 295151, approved 01/29/2026): Operator requested waiver for 30' sample collection from Base of Last Salt to planned curve KOP. Justification: offset well Thunderbolt 10-12 1H (File #41970) on same pad already has samples sufficient for formation top establishment. Waiver approved; 30' sampling to resume in curve section and continue through lateral. (01/28/2026 to 01/29/2026)
This is a routine regulatory waiver tied to multi-well pad operations (correlative geology across offset well on same pad). Included as supporting signal demonstrating regulator flexibility tied to pad-scale operational efficiency, not a constraint on this permit's approval.
Historical Non-Routine Signals (4)
APD approval dated 05/30/2025 (FORM 4, File #41973) permits four-well pad development (Thunderbolt 10-12 1H, 2H, 3H, 4H) in 1,920-acre spacing unit (Sections 10, 11, 12, T155N, R103W) within Bakken Pool. Setback requirement: 500' north/south, 150' east/west. Condition: well must be drilled in conjunction with offset well meeting 1,220' setback from spacing unit boundaries to justify spacing unit justification. (2025-05-30)
This spacing unit configuration and setback covenant are forward-operative constraints on all wells on the pad. The 1,220' setback requirement tied to an adjacent well justification must be maintained during and after completion of the Thunderbolt 10-12 4H to preserve spacing unit legal standing. Any future workover or additional drilling must respect these geometric and jurisdictional boundaries.
Tubing/Packer Waiver (Sundry FORM ID 252303, approved 06/09/2025): Operator requested variance to NDAC 43-02-03-21 (tubing/packer requirement) with seven operational assurances: (1) new surface casing (29# and 32# API 11,220 psi burst rating); (2) safety factor 0.85 of API burst; (3) damage detection via monitoring; (4) lower rates/pressures during flowback; (5) low corrosion/erosion of completion fluid and formation fluids; (6) production equipment installation post-flowback; (7) 300# gauge on surface casing during flowback. Approved contingent on these design and operational controls. (2025-06-09)
This waiver allows alternative completion practices (elimination of tubing/packer during initial flowback) provided the operator maintains the specified design margins and monitoring protocols during the flowback phase and initial production. It affects equipment specifications (surface casing rating) and operational procedures (gauge installation, monitoring discipline) that must persist through completion and early production. Failure to maintain monitoring or pressure containment during flowback could trigger compliance violations under the waiver terms.
Suspension of Drilling (Sundry FORM ID 252295, approved 06/11/2025): Operator requested 90-day suspension permit to allow two-stage drilling: (1) small rig for surface hole with freshwater mud and surface casing setting (3-5 day mobilization); (2) main rig mobilization within 90 days to drill to TD. Condition: no saltwater used in surface casing operations; plug or mechanical seal required at casing top; operator responsible for P&A and site reclamation if main rig does not arrive within 90 days. Surface hole intentional deviation prohibited. (2025-06-11)
This suspension waiver established a contractual and regulatory obligation to complete drilling within a time window (spud to main rig mobilization = 90 days maximum). The well was spud 10/20/2025 (reported in drilling notification); suspension waiver expired ~01/18/2026. The subsequent cement deficiency and permit-cycle signals (01/12–01/29/2026) indicate main rig drilling completed on schedule. The surface casing prohibition against intentional deviation persists as a drilling constraint in any future remedial work on the surface or intermediate sections.
Open Hole Log Waiver (Sundry FORM ID 252287, approved 06/06/2025): Operator requested waiver of open hole logging requirement (DMR Rule 43-02-03-31) citing offset well Myron 9-4 3H (File #28232) within 1 mile with sufficient open log data for formation tops. Condition: GR-CBL run from TD to ground level required; resumption of 30' sampling in curve section and lateral. (2025-06-06)
This waiver reduced pre-completion logging burden (no full open-hole suite required) but mandated GR-CBL from TD to surface. The CBL data became critical evidence in the defective cement identification and subsequent remediation approval. Any future re-evaluation of cement quality or formation pressure integrity will depend on the available GR-CBL baseline established under this waiver.
Historical Operator Profile
Total Wells:N/A
Active Wells:N/A
Notable Patterns:None identified
Confidence Assessment
Level: High Rationale: The well file contains clear, dated regulatory documents (sundries, inspection comments, permit approvals) with explicit regulator signatures and approval authorities. The defective cement issue is documented across three separate permit-cycle documents (CBL report dated 01/06/2026, verbal inspection approval, and two sundries with effective dates 01/12/2026 and 01/27/2026). Technical data (MIT results, RCBL interpretation, pressure test) is contemporaneous with permit actions and directly cited by regulator in approval language. The temporal sequence is unambiguous: drilling completion by 10/28/2025, CBL run 01/06/2026, regulatory approvals 01/12–01/29/2026. No dates are inferred or missing in the permit-cycle chain of custody.