Frac Spread Count, Explained: The Completion Number Behind the Rig Count

Every Friday, two numbers land within hours of each other. Baker Hughes reports how many rigs are drilling, and Primary Vision reports how many frac spreads are completing wells. The rig count gets the headlines. The frac spread count is the number that tells you what oil production does next, because a drilled well produces nothing until a frac spread has fractured it. On November 6, 2026, the two counts read 604 rigs and 195 frac spreads. This page explains what the second number is, how it is built, what it has done since 2014, and how to read it alongside the rig count every week.

1. What a frac spread is

After a rig drills a well, the hole is cased and cemented, and then a different set of equipment arrives to complete it. A frac spread, also called a frac fleet, is that equipment: the high-pressure pumps that push fluid down the well, the blenders that mix water, sand, and chemicals, and the monitoring units that watch pressure and rate. It comes with the crew that runs it, usually supplied by a pressure pumping company working for the operator that owns the well.

A spread is not a well, and it is not a rig. One spread works on one well at a time and moves on to the next when the fracture treatment is done. The count does not weight spreads by size, so a fleet of large spreads and a fleet of small ones count the same. That is a limitation to keep in mind, and it is covered in section 8.

It is also worth saying what a frac spread is not, because the name invites confusion. It has nothing to do with the crack spread in refining, the fractionation spread in natural gas liquids, or any price difference. It is a count of equipment sets doing hydraulic fracturing, and only that.

2. What the Frac Spread Count measures

The Frac Spread Count is published by Primary Vision, an energy data firm. It was introduced in 2014, during the expansion of the U.S. shale boom, and it is the highest daily value of active frac spreads for a given week. Primary Vision tracks, for every spread, the days active, the location, the pressure pumper, the operator, and in most cases the volumes of water, proppant, and chemicals pumped. The national number is given away free, updated by 10 a.m. every Friday. Basin-level detail, forecasts, and the companion Frac Job Count, which tracks individual completions rather than spreads, are paid products.

The count covers the United States and Alberta. It is used by economists, market analysts, and commodity traders to monitor completion activity in the unconventional oil and gas sector, and it is the standard complement to the Baker Hughes rig count in weekly drilling dashboards: OilPrice publishes the two side by side every Friday, and the weekly history table on its rig count page is the source for the figures in this page.

3. The November 2026 snapshot

For the week ending November 6, 2026, the frac spread count was 195, up four from 191 the week before. The rig count in the same week was 604, up one. U.S. crude output for the week ending October 30, the latest EIA weekly estimate, was 14.00 million barrels a day, a record. The three numbers together describe an industry completing wells about as fast as it drills them, with output at a record on the wells already completed.

The 2026 range tells the year's story in miniature. The count bottomed at 145 in early February, when the rig count was also near its low, then recovered through the spring and summer to 200 by late June and early July. It sagged to 178 in early September, the same weeks the rig count paused at 588, then climbed to its yearly high of 203 on October 9. Since then it has moved sideways between 191 and 203 while the rig count crept from 603 to 604. Completions are not chasing drilling higher; they are holding a plateau while drilling edges up.

4. Rigs vs frac spreads: the well lifecycle

A shale well passes through four stages, and the two counts sit at different points on that line:

1. Drill. A rig drills the wellbore. The rig count measures this stage.
2. Wait. The drilled well sits as a DUC, a drilled-but-uncompleted well, until a frac spread is scheduled. The DUC inventory measures this stage.
3. Complete. A frac spread fractures the well. The frac spread count measures this stage.
4. Produce. The well is hooked up and flows. Production data measures this stage, with a lag of weeks to months.

The lead times are what make the two counts complementary rather than redundant. A rig added today produces oil several months from now. A frac spread added today produces oil in weeks, because the well it works on is already drilled. That is why traders and analysts treat the frac spread count as the better near-term supply signal: it sits one step closer to the oil.

The two counts also answer different questions about intent. The rig count answers "how much drilling are operators committing to?" The frac spread count answers "how much of what is already drilled are operators choosing to finish now?" An operator that wants to raise output fast completes DUCs. An operator that wants to raise output later drills. When both counts rise together, as they did through the spring of 2026, the industry is doing both. When they split, the split itself is the information.

5. Frac spreads and the DUC inventory

The DUC inventory is the arithmetic that ties the two counts together. Every week, rigs add drilled wells and frac spreads remove them by completing them. If completions outpace drilling, the DUC count falls. If drilling outpaces completions, it rises.

The history shows how large that buffer can get. As the PetroEyes DUC explainer documents from the EIA series, the DUC inventory ran from 4,505 wells in 2013 to a peak of 8,894, then back to 4,510 as the series ended in the EIA Drilling Productivity Report, whose final edition was released May 13, 2024. A large DUC inventory means completions can surge without any new drilling at all, which is exactly what happened in 2021: production responded to completions off the backlog while the rig count was still low.

The weekly check is simple. Compare the direction of the frac spread count with the direction of the rig count. Spreads rising while rigs are flat means the DUC inventory is being drawn down, a finite boost. Rigs rising while spreads are flat means the DUC inventory is being rebuilt, and near-term production will lean on wells already completed. In the week ending November 6, rigs rose one and spreads rose four: both moving together, neither borrowing from the other.

6. What moves the count

Four forces move the frac spread count week to week, roughly in this order of importance:

• The price operators expect to receive. Completions are the most deferrable spend in the shale budget: a drilled well can wait, a frac spread can be released. When the expected price falls toward the breakeven, completions are the first activity cut and the last restored. The Dallas Fed March 2026 survey put the average new-well breakeven at $66 a barrel, and WTI at $86.23 on November 10 sits comfortably above it, which is consistent with spreads holding near 195 rather than falling.
• Crew and equipment availability. A frac spread needs pumps, sand, water handling, and a crew. The Dallas Fed third-quarter 2026 survey found equipment utilization rising (index 41.9, up from 31.9) and supplier delivery times still lengthening (index 36.2). Tight crews cap how fast the count can rise even when the price is right.
• Season and weather. Completions slow in deep winter and around holidays, and they stop outright in a freeze. In February 2021 a winter storm across Texas cut the count from 161 to 41 in a single week, a record low at the time, and it took two to three weeks to restart the equipment and return to 160. The count measures field activity, so weather shows up in it immediately.
• The DUC inventory itself. A large DUC stock invites completions; a small one constrains them.

The count also moves on calendar effects that are easy to mistake for signal. Spreads are counted on their highest daily value in the week, so a holiday-shortened week can read lower without any change in intent, and a single large operator starting or stopping a multi-spread program can move the national number by several points. Four-week averages are the safer read for direction; single weeks are for the level.

7. A short history: 2014 to 2026

Primary Vision introduced the count in 2014, as the shale boom shifted from finding oil to finishing wells at scale. The early years are the high-water mark: the count ran near 270 to 300 through 2022, peaking at 300 in the week ending November 23, 2022. It slid through 2023 (240 to 295) and 2024 (272 in March down to 201 by late December) as drilling slowed and operators worked off the DUC backlog built during the pandemic years.

2025 was the low year. The count peaked at 215 in the week ending March 21, 2025, and fell to 154 by December 26. The rig count bottomed in the same period, and U.S. output held near 13.5 to 13.9 million barrels a day on the wells already flowing. 2026 is the recovery year: 145 in February, 200 by late June, 203 in October, 195 in November. The recovery in spreads (up 50 from the February low) is larger in percentage terms than the recovery in rigs (up 61 from the April low of 543, or 11 percent), which is the usual pattern - completions respond first because they are the cheaper, faster lever.

8. What the count cannot tell you

The frac spread count is a good instrument, and like every instrument it has blind spots. Five are worth knowing before you trade on it or forecast from it:

• It counts spreads, not wells or stages. A spread can complete more than one well in a week, and a well can take several stages. Two weeks with the same count can complete different numbers of wells.
• It does not weight by size. A 50,000-horsepower spread and a 20,000-horsepower spread each count as one. If the mix shifts toward bigger spreads, the count understates completion capacity, and the reverse if it shifts smaller.
• It does not measure intensity. Sand and water per foot, lateral length, and stage spacing all affect how much oil a completed well makes. The count says how many spreads are working, not how hard each one is working.
• The method is proprietary. Primary Vision describes what it tracks - pumper, operator, location, volumes - but the exact counting rules are not public. The national number is free and the history is published, so the series can be checked against output, but it cannot be independently reproduced from public data.
• Basin detail is paid. The free number is national. An analyst who needs the Permian-only count, or the count by operator, needs the subscription. National moves can hide basin moves in opposite directions.

None of this makes the count useless. It makes it a first check rather than a final answer. The right use is alongside the rig count, the DUC inventory, and reported production: four series that have to agree with each other before a forecast earns confidence.

9. How to read it each week

A short routine, in the order the data lands:

1. Friday, 10 a.m.: note the frac spread count and its four-week average. Direction of the average matters more than one week.
2. Friday, 1 p.m.: note the Baker Hughes rig count. Compare the two directions - together, or splitting?
3. Wednesday: read the EIA Weekly Petroleum Status Report for crude stocks and production. The November 2026 STEO put commercial crude stocks at 410 million barrels at the end of October, the lowest end-of-October level since 2014.
4. Monthly: check the DUC direction in the EIA Short-Term Energy Outlook regional tables. Spreads rising while DUCs fall is the drawdown pattern; spreads flat while DUCs rise is the rebuild pattern.
5. Write down one sentence on what surprised you. Surprises are where the learning is.

A worked read from the latest data: on October 9 the count was 203 with rigs at 603; on November 6 it was 195 with rigs at 604. Completions eased by eight spreads while drilling rose by one rig, and output held at 14.00 million barrels a day. The read is not "completions are collapsing" - 195 is near the yearly high - it is "completions have plateaued while drilling edges up." If the plateau holds and rigs keep rising, the DUC inventory should start rebuilding, and that is the number to watch next.

Data and sources: Primary Vision Frac Spread Count methodology from Primary Vision, Frac Spread Count 2.0 (June 2016), read November 11, 2026, and the Primary Vision research portal description of the count and the Frac Job Count. Weekly frac spread counts, rig counts, and U.S. output from the OilPrice rig count page, checked November 11, 2026. The February 2021 storm low (161 to 41) from OilPrice, February 24, 2021. Baker Hughes November 6, 2026 count as reported by OilPrice and Rigzone. EIA Drilling Productivity Report (final edition May 13, 2024). Dallas Fed Energy Survey, third quarter 2026, released September 30, 2026; breakeven figures from the March 2026 survey (breakeven.xlsx, updated March 25, 2026). EIA Short-Term Energy Outlook, November 2026, released November 10, 2026.