🛢️ AMBER 2203-3BH

KODA RESOURCES OPERATING, LLC · Divide County, ND · File #42352 · Generated 2026-08-25 04:30

API: 3302301687
Target Formation: Middle Bakken
Confidence: High

📊 Signals (6)

Tier	Signal	Date	Service Impact
Tier 2	Approval condition based on production liner cemented in lateral with a wet shoe and ability to frac out the shoe, indicating a specific completion design to meet north setback requirements. 📄 Page 1 of 10, Conditions of Approval Non-standard cementing/completion technique (wet shoe with frac-out capability) is mandated by regulator to achieve legal setback, implying specialized engineering.	2026-07-13	Completions / Frac
Tier 3	Regulatory requirement to contact NDIC Field Inspector Marc Binns prior to location construction, replacing previous inspector Gunther Harms, indicating inspector reassignment and potential new field oversight dynamics. 📄 Page 1 of 10, Permit Review Policy Change in assigned field inspector between permit versions (2025 vs 2026) may alter pre-construction coordination, inspection style, or compliance focus.	2026-07-13	General Oilfield Services
Tier 3	Permit modification to move surface hole location from 600' FNL 2518' FWL to 400' FNL 2503' FWL in Section 22, indicating pad layout optimization or surface constraint resolution. 📄 Page 6 of 10, PROPOSED WORK section Shows active engineering redesign after initial permit, suggesting pad reconfiguration, potential earthwork changes, or resolution of surface access/ownership issues.	2026-07-13	General Oilfield Services
Tier 3	Anti-collision report shows Level 2 and Level 3 separation warnings with multiple offset wells on pad (e.g., Amber 2203-1BH, Amber 2203-2BH), indicating high-density drilling with close wellbore proximity. 📄 KLX Anticollision Report summary High collision risk requires precise directional drilling and real-time monitoring. Shows pad development intensity and operational complexity.	2026-05-04	Directional Drilling
Tier 3	Two separate open hole log waivers approved (Oct 2025 and Jun 2026) citing offset wells AMBER 2234-6BH and AMBER 2234-7BH, indicating persistent strategy to reduce logging costs using nearby well data. 📄 WELL SUNDRY FORM sections (Form IDs 274917 and 319107) Operator repeatedly secures regulatory waivers to forego open hole logs, relying on offsets. Shows consistent cost-saving approach and confidence in subsurface predictability.	Relative	Regulatory / Permitting
Tier 3	Drilling program specifies produced Bakken salt water as drilling fluid for 6" production interval, indicating use of recycled produced water rather than fresh water or oil-based mud in lateral. 📄 Drilling Fluids Program section Non-standard fluid selection for lateral drilling. Reflects environmental/economic strategy to reuse produced water, requiring handling, treatment, and compatibility management.	Unknown	Mud / Fluids

💡 Operator Intent

Optimize multi-well pad development through sequential permit modifications and pad layout refinements.

Surface hole location moved after initial permit; anti-collision modeling includes multiple offsets; pad layout shows multiple well slots (Amber 2203-1BH through 4BH, SWD); earthwork calculations balance cut/fill across pad.
Reduce drilling costs and time by waiving open hole logging and using produced water as drilling fluid.

Two approved log waivers citing offset wells; drilling program specifies produced Bakken salt water for lateral section instead of more expensive fluids.
Ensure regulatory compliance for setbacks via specialized completion design, indicating focus on maximizing lateral length within legal constraints.

Approval conditioned on production liner with wet shoe and ability to frac out shoe to meet north setback; permit modification may also relate to optimizing wellbore positioning.

🔧 Service Operator Relevance

Directional Drilling / MWD

High-density pad with anti-collision warnings requires precise wellbore placement. KLX Directional already engaged, but potential for backup or additional services exists given complexity.

Cementing / Completion Services

Mandated wet shoe design with frac-out capability is non-routine. Specialized cementing expertise needed to achieve regulatory setback condition.

Earthmoving / Pad Construction

Permit modification changed surface location, implying revised pad layout. Earthwork quantities detailed (55,510 cu yds cut, 66,160 cu yds fill). Timing tied to pre-construction inspector contact.

Produced Water Handling / Transfer

Drilling program specifies produced Bakken salt water for lateral drilling, creating need for sourcing, transport, and onsite fluid management.