Why It Matters
North Dakota’s state budget is heavily dependent on oil and gas revenue, making production levels a critical economic indicator for lawmakers and residents alike. Despite crude oil prices approaching $100 per barrel — a threshold that historically triggered aggressive drilling campaigns — North Dakota’s energy sector is showing little sign of acceleration, raising questions about the long-term structure of the state’s most important industry.
The restrained response signals a fundamental shift in how the Bakken oil patch operates, with implications for state tax collections, infrastructure investment, and employment across western North Dakota’s oil-producing counties.
What Happened
Domestic crude oil benchmark prices have been hovering just below $100 per barrel as of late March 2026, driven in part by ongoing conflict in the Middle East and the closure of the Strait of Hormuz to shipping traffic. A decade ago, prices at that level would have set off a drilling frenzy across the Bakken formation.
Instead, North Dakota’s drilling activity has remained essentially flat. Approximately 25 drilling rigs and eight frack crews are currently active in the state — numbers that have not meaningfully changed in response to the price surge. State regulators from the North Dakota Department of Mineral Resources addressed the situation during a monthly press conference and in remarks to state lawmakers last week.
David Tabor, senior field operations manager for the Department of Mineral Resources, said the industry’s largest players are unlikely to make rapid operational changes until oil prices stabilize at elevated levels over a sustained period. Nathan Anderson, the department’s director, told lawmakers that price projections remain heavily tied to geopolitical developments, particularly the duration of the conflict involving Iran and how long the Strait of Hormuz remains closed.
By the Numbers
$100 per barrel — The approximate current price of domestic crude oil benchmarks, a level not seen in years and one that historically prompted significant drilling expansion in the Bakken.
25 drilling rigs — The number of active drilling rigs currently operating in North Dakota, a figure that has remained largely unchanged despite the price environment.
8 frack crews — The number of active hydraulic fracturing crews in the state, also holding steady with no near-term ramp-up expected.
2,835 inactive wells — The number of wells in North Dakota classified as inactive, defined as reporting zero production for three months or more. These represent the most immediate opportunity for operators to boost output without new drilling investment.
Less than one week — The estimated time required to bring an inactive well back into production, making reactivation a faster and lower-cost option than drilling new wells.
Zoom Out
North Dakota’s muted response to high oil prices reflects a broader national trend in the American energy industry. Following years of investor pressure demanding capital discipline and consistent returns over growth-at-all-costs strategies, major oil companies across the country have largely abandoned the reactive drilling cycles that characterized the shale boom of the 2010s.
Industry consolidation has accelerated this shift. A wave of mergers and acquisitions in recent years has concentrated Bakken production among a smaller number of large publicly traded companies, including some of the largest energy firms in the country. These corporations set annual capital budgets well in advance and are generally reluctant to deviate from them based on short-term price movements, even dramatic ones.
Similar patterns have been observed in other major producing states, including Texas and New Mexico, where the Permian Basin has also seen measured responses to price spikes compared to historical boom periods. The era of the small independent driller rushing to capitalize on every price uptick has largely given way to a more institutionalized, budget-driven industry.
What’s Next
Regulators and industry observers expect North Dakota oil companies to first pursue optimization of existing assets before committing capital to new wells. Tabor specifically predicted that reactivation of idle wells from the state’s pool of 2,835 inactive sites would be among the earliest responses if companies decide to increase output.
North Dakota lawmakers are expected to continue monitoring oil price developments closely, given the direct connection between production volumes, tax receipts, and the state’s budget outlook. Anderson and Tabor indicated that a sustained period of price stability — rather than a sudden spike — would be the more likely trigger for any meaningful increase in drilling activity. Any shift in operational plans would most likely be reflected in updated 2027 capital budgets as major operators make those decisions later this year.