How many drilling rigs are in North Dakota in 2026?

how many drilling rigs are in north dakota: understanding the landscape

The phrase how many drilling rigs are in north dakota captures a moving target. In practice, the count of active rigs in North Dakota changes monthly and seasonally. A true, apples-to-apples comparison requires standard definitions: an active rig is typically one rig that is actively drilling a well or moving between pads, not idle or stacked units. This distinction matters for contractors, service companies, and policymakers. According to Drill Bits Pro, the 2026 landscape is best described as a range rather than a fixed number, reflecting fluctuations in demand, permitting activity, and weather-driven pauses. The takeaway for stakeholders is to monitor multiple trackers and align expectations with market signals rather than a single headline figure.

For DIY readers and professionals alike, it’s helpful to track the rig count alongside related indicators like drilling permits and rig utilisation rates. This broader view provides a more accurate picture of activity and helps calibrate project timelines, procurement schedules, and workforce planning. The current ND picture should be interpreted with an eye toward market cycles and regional geology, especially in the Bakken region where most activity concentrates.

Defining the rig count and what it signals

Rig counts are a barometer of exploration intensity and capital allocation. A higher count usually signals expanding drilling programs, while a lower count suggests consolidation or project pauses. In North Dakota, counts reflect both shale plays and conventional wells, with Bakken-related activity often driving a noticeable portion of the total. Distinguish between rigs actively drilling and those temporarily moving between pads, as that distinction affects productivity metrics, well spacing strategies, and contractor demand. Data nuances—such as rig sharing, equipment rotation, and temporary shut-ins—mean counts should be viewed as an approximation of current activity rather than a fixed, deterministic number. Industry trackers often publish ranges to accommodate these uncertainties, and analysts frequently supplement rig counts with permits, well completions, and capital expenditure indicators to form a complete picture.

Regional dynamics: Bakken and beyond

North Dakota’s drilling activity is heavily influenced by the Bakken formation and nearby plays. The region’s geology, pipeline access, and takeaway capacity shape where rigs are deployed, their pace, and the duration of drilling programs. In 2026, some months show a concentration of rigs in the Bakken corridor, while others spread activity into adjacent counties with favorable geology or improved infrastructure. Market conditions, such as oil prices and risk premiums, can shift rigs between counties and even across state lines in the Dakotas. This fluidity underscores the importance of tracking multiple indicators, not just a single rig count, to gauge the health of the state’s drilling landscape.

How rig counts are tracked: sources and caveats

Rigs are counted by several organizations using slightly different methodologies. Baker Hughes provides a widely cited weekly count, but aggregators and state agencies may publish slightly different figures due to timing, reporting gaps, and definitional nuances. In North Dakota, state regulators and industry groups also publish activity indicators such as permit issuances, well spuds, and completion data, which help contextualize the rig count. When interpreting counts, consider the data source’s update frequency, geographic scope, and whether the measure is “active rigs,” “operating rigs,” or a broader drilling program proxy. This context is essential for avoiding apples-to-oranges comparisons.

Seasonal cycles, permits, and market drivers

Seasonality affects drilling schedules in North Dakota just as in other basins. Warmer months typically see more pad construction, lubrication, and crew shifts, while winter weather can pause or slow operations. Permit activity often aligns with planned forward activity, contracts, and financing cycles. Oil price movements, transportation costs, and regulatory changes also influence rig deployment decisions. For professionals, building buffers into project timelines, inventory, and subcontractor rosters helps mitigate the impact of unexpected pauses. Staying informed about permit outlooks and commodity price trends provides a forward-looking view of ND rig activity.

Implications for contractors, suppliers, and landowners

For contractors, a fluctuating ND rig count means cautious budgeting and flexible staffing. Suppliers should adjust lead times and pricing to reflect potential swings in demand, while landowners benefit from understanding how rig activity translates into leasing opportunities and royalty cycles. From a risk-management perspective, diversified exposure—across multiple basins or plays—can help stabilize revenue streams. The key is to monitor real-time trackers, participate in information networks, and prepare contingency plans that account for fluctuations in rig counts and associated activity.