🛢️ TUNNOCK 5303 12-2 5B

OASIS PETROLEUM NORTH AMERICA LLC · Williams County, ND · File #42929 · Generated 2026-08-22 01:48

API: 3310506832
Target Formation: Middle Bakken
Confidence: High

📊 Signals (7)

Tier	Signal	Date	Service Impact
Tier 2	Approval conditional on 150' north/south and 500' east/west setbacks within 2560-acre spacing unit, with south setback based on production liner cemented in lateral with wet shoe and ability to frac out shoe 📄 Stipulations section, page 1 Specific setback conditions tied to completion design (wet shoe) indicate regulatory accommodation for planned frac operations; competitors should note spacing unit boundaries and completion constraints.	Unknown	Completions / Frac
Tier 2	Wet shoe configuration detailed: 400' uncemented annulus at liner toe, over-displaced by 7 bbls to enable wireline pump-down perforating for toe initiation 📄 Wet Shoe section, page 8 Non-standard cement design to facilitate cost-effective toe initiation (avoiding tubing/tractor) reveals operator completion efficiency intent.	Unknown	Completions / Frac
Tier 3	Drill-back notification affidavit shows email sent to Devon Energy on 2/11/2026 regarding wellbores entering adjacent spacing unit 📄 Affidavit Affirming Drill-Back Notification, page 10 Formal drill-back notice to a major competitor (Devon) demonstrates proactive regulatory compliance and reveals lateral extent into adjacent unit.	2026-02-11	General Oilfield Services
Tier 3	Anticipated commencement date: July 15, 2025; drilling days: approximately 30⏰ TIME-SENSITIVE 📄 Anticipated Starting Dates, page 6 Specific start date and duration provided in planning documents, indicating firm operational timeline.	2025-07-15	Drilling Rigs
Tier 3	CBL required on 9-5/8" intermediate (Dakota water string) prior to setting 7" casing, plus standard CBL on 7" casing 📄 Page 2 Extra cement bond log requirement on intermediate string beyond routine indicates regulatory concern over Dakota aquifer protection or casing integrity.	Unknown	General Oilfield Services
Tier 3	Operator acknowledges providing 21-31 days prior written notice to operators of wells in same/adjacent pool within 2640' of completion interval 📄 Operator Assertions, page 7 Formalized long-lead notification to competitors (like Devon Energy) reveals planned frac interference management and potential for coordinated completions.	Relative	Completions / Frac
Tier 3	Operator must contact NDIC Field Inspector Jessica Gilkey prior to location construction⏰ TIME-SENSITIVE 📄 Construction Commencement Notification, page 1 Pre-construction contact with a named inspector (Jessica Gilkey) is mandated, indicating heightened regulatory oversight or site-specific conditions.	Relative	General Oilfield Services

💡 Operator Intent

Optimize completion cost and efficiency by using wet shoe design to enable wireline pump-down perforating instead of more expensive tubing/tractor methods

Wet shoe configuration description explicitly states purpose: 'allows the operator to pump-down the first stage perforating guns on wireline, avoiding the more expensive option of perforating on tubing or with a tractor.'
Minimize surface footprint and regulatory complexity by using an indirect heater with setback exemption (Case No. 28949 Order No. 31500) allowing placement within 60' of wellhead and 21' of oil tank

Facility Statement notes: 'This indirect heater has a setback exemption from the NDIC under Case No. 28949 Order No. 31500 and can be set within 60 feet of the well head and 21 feet of the oil tank.'
Aggressively manage anti-collision risks in densely drilled area through real-time survey correction, gamma ray signature monitoring, and 1.2 separation safety factor

Anti-Collision Statement details multiple precautions: real-time corrected surveys, 1.2 separation factor, gamma ray signatures to identify existing wellbores, and increased survey frequency near lateral crossings.

🔧 Service Operator Relevance

Pad Construction & Earthwork

Construction must begin after permit publication (3 business day wait) and requires prior contact with NDIC Inspector Jessica Gilkey. Earthwork quantities detailed: ~8,100 CY topsoil stripping, ~62,900 CY excavation, ~70,600 CY embankment. Timing tied to July 15, 2025 spud.

Cementing & Logging

Non-routine CBL requirements on 9-5/8" and 7" casing strings create additional logging runs. Wet shoe cement design demands precise over-displacement (7 bbls) and 400' uncemented annulus. Cement top job required if fallback >10' below ground.

Directional Drilling & Surveying

Anti-collision measures mandate real-time survey correction, 1.2 separation factor, and increased survey frequency near crossings. Survey program uses OWSG MWD + IFR1 + Multi-Station Correction tool. Close approaches to multiple existing wells (e.g., JAFFA, TUNNOCK siblings) require careful planning.

Stimulation & Completion

Wet shoe design enables wireline pump-down perforating for toe initiation. Operator must notify adjacent operators (Devon) 21-31 days before completion. No diesel-based stimulation fluids will be used. Frac design will be based on post-completion production rates.

Waste Management & Disposal

Closed mud system with no cuttings pit required. Drill cuttings must go to licensed disposal facilities (list provided). Filter sock leak-proof container must be on site from spud through flowback. Solid waste transporters need DEQ permits.