The U.S. oil and gas rig count climbed for the first time in three weeks, rising to 548 active rigs in the week ending April 2, 2026, according to the latest Baker Hughes data. Oil rigs increased by 2 to 411, while gas rigs added 3 to reach 130. Miscellaneous rigs held flat at 7. The uptick—modest as it is—signals that producers are beginning to respond to the sustained surge in crude prices driven by the ongoing geopolitical conflict in the Middle East, where Brent crude has traded above $100 per barrel for the better part of the past month.

Three-Week Skid Snapped as Price Signal Takes Hold

The prior three consecutive weeks of declining rig counts had raised questions about whether U.S. operators were pulling back on drilling ambitions despite elevated prices, or simply working through budget cycles and scheduling logistics before committing additional capital. The answer, at least for now, appears to be the latter. The combined net addition of 5 rigs—2 on the oil side and 3 for gas—is consistent with incremental, price-responsive deployment rather than a broad capital reallocation or a strategic step-change in activity levels.

Even so, the headline 548 figure sits 42 rigs below where the count stood a year ago, and oil rigs are down a striking 70 from year-ago levels. That persistent year-over-year gap underscores a structural reality in the current market: while elevated prices are sufficient to keep existing programs running and to add rigs at the margin, they have not yet triggered the kind of aggressive leasehold development that characterized prior upcycles. Operators are threading a needle between capturing near-term revenue at triple-digit crude prices and maintaining capital discipline for investors who remain wary of boom-and-bust spending patterns.

"Producers are not rushing back to the field the way they might have in 2012 or 2017. The discipline is real. But at $108 Brent, you are going to see incremental rigs move back into service—especially in the Permian and the Eagle Ford where the economics are compelling at any price above $60." — Senior upstream analyst, energy research firm

Permian and Eagle Ford Lead Regional Activity

On a basin level, the Permian Basin added 1 rig to reach 242 active units, continuing its role as the undisputed center of gravity for U.S. onshore drilling activity. Even at 242 rigs, the Permian sits 52 below its year-ago count, a gap that reflects the broader industry recalibration rather than any basin-specific deterioration. The shale play's cost structure remains among the most competitive in the world, and with WTI holding above $111 per barrel, well economics across the Delaware and Midland sub-basins are deeply in the money at essentially any reasonable cost assumption.

The Eagle Ford in South Texas was the standout performer this week, adding 3 rigs to bring its total to 45. That single-basin gain accounted for more than half of the national net increase and pushes Eagle Ford activity to levels not seen in several months. The play's lighter crude grades, which are particularly well-suited to Gulf Coast refinery configurations optimized for export, are attracting renewed operator attention as international buyers compete aggressively for non-Middle Eastern supply in the current environment.

Gas Rig Gain Outpaces Oil on LNG Demand Outlook

The 3-rig gain on the gas side is arguably the more consequential development in this week's data. Unlike oil rigs—which remain 70 below year-ago levels—gas rigs are now running 26 above where they were a year ago, a trend that reflects the structural shift in U.S. natural gas demand driven by liquefied natural gas export capacity additions along the Gulf Coast. Several large LNG export terminals that broke ground in 2023 and 2024 are approaching commissioning phases, and upstream operators are positioning to supply that incremental feed gas demand.

The combination of a Middle East supply shock that has redirected global LNG demand toward U.S. exporters and the physical expansion of U.S. export infrastructure has created a sustained investment thesis for gas-directed drilling that exists largely independently of the crude oil price cycle. That gas rigs have now climbed well above year-ago levels even as oil rigs lag behind suggests the market is rewarding exposure to the gas and LNG complex in ways that have not been seen since the early phases of the U.S. shale gas revolution.

Completion Activity Softens

While the rig count offered an encouraging headline, completion activity sent a more cautious signal. Primary Vision's Frac Spread Count fell by 5 crews during the week ending March 27, following a decline of 8 crews the prior week. The back-to-back drops in frac crew deployment suggest that the pipeline of wells drilled but uncompleted is not yet being converted to production at the pace that the rig count uptick might imply.

The divergence between rig additions and frac spread declines is not unusual in a market transitioning from contraction to expansion—operators drill wells ahead of completion, and frac crews are often the last link in the chain to ramp. But the consecutive weekly declines do introduce some uncertainty about how quickly the new drilling activity will translate into additional barrels flowing to the surface. For now, the completion market appears to be digesting the prior period of reduced activity before scaling back up.

Production Steady Near Historic High

U.S. crude oil production averaged 13.657 million barrels per day during the week ending March 27, holding flat from the prior week. The figure sits approximately 205,000 barrels per day below the all-time production high, a gap that is likely to narrow gradually as the current rig count recovery feeds through the well completion pipeline over the coming months.

The stability of output at near-record levels is itself a significant market fact: even amid weeks of declining rig counts, the productivity of existing wells and the DUC inventory buffer have kept U.S. production running at a level that has helped offset—partially, at least—some of the global supply disruption stemming from the Strait of Hormuz conflict. How long that production plateau can be maintained without sustained rig count growth is one of the key questions for energy markets in the months ahead.

Key Metrics at a Glance

  • Total U.S. Rig Count: 548 (up 5 week-over-week; down 42 year-over-year)
  • Oil Rigs: 411 (up 2 week-over-week; down 70 year-over-year)
  • Gas Rigs: 130 (up 3 week-over-week; up 26 year-over-year)
  • Miscellaneous Rigs: 7 (unchanged)
  • Permian Basin: 242 rigs (up 1 week-over-week; down 52 year-over-year)
  • Eagle Ford: 45 rigs (up 3 week-over-week; down 3 year-over-year)
  • Frac Spread Count: Down 5 crews week-over-week (Primary Vision, week ending March 27)
  • U.S. Crude Production: 13.657 million bpd (flat week-over-week; 205,000 bpd below all-time high)
  • Brent Crude: $108.60/bbl (+7.33% on the day)
  • WTI Crude: Above $111/bbl

What to Watch

The rig count is a lagging indicator of upstream sentiment, and this week's modest uptick will need to be sustained—and ideally accelerated—over the coming weeks to signal a genuine inflection in U.S. drilling activity. Markets will be watching the following closely:

  • Whether frac spread deployment recovers from back-to-back weekly declines, which would confirm that the completion bottleneck is clearing
  • EIA weekly production data for evidence that output is beginning to climb from its current plateau toward new all-time highs
  • Operator capital expenditure guidance in upcoming quarterly earnings, where management teams will face questions about whether they intend to accelerate programs in response to triple-digit prices
  • Any escalation or de-escalation in the Strait of Hormuz conflict, which remains the primary macro variable driving crude prices and, by extension, upstream investment decisions
  • Permian basin infrastructure capacity, where takeaway constraints have historically acted as a ceiling on activity expansion even when drilling economics are strongly positive

One week does not make a trend, but after three consecutive weeks of declines, the return to positive territory in the Baker Hughes count offers at least tentative evidence that U.S. producers are responding rationally to a price environment that few had modeled when they set their 2026 budgets in the fourth quarter of last year. How aggressively that response unfolds will shape both the domestic production outlook and the global supply picture for the remainder of the year.