Drilling rigs and frac spreads (services)
It is the economic heart of Vaca Muerta —frac and drilling take up ~85% of the cost of a USD 14M well— but also the most concentrated: Halliburton and SLB together hold ~70% of the stages and a frac spread costs USD 50-110M with captive contracts (Halliburton, 5-year exclusive with YPF). You don't enter by competing head-on in mass pumping, but from the side: the deficit of e-frac/dual-fuel equipment under take-or-pay with a mid-sized operator, internalization via JV (SPI/Pluspetrol and AESA/YPF have already proven it) and high-margin, low-rivalry satellite services (snubbing, long-reach coiled tubing). Import liberalization and the end of the PAÍS Tax make bringing in equipment cheaper; the megaprojects' RIGI sustains demand.
The agenda that moves the niche is mixed: the RIGI (federal and provincial) creates the well engine, import liberalization makes equipment cheaper —cutting both ways— and the Neuquén promotion regime is the service supplier's entry door. Each rule opens in the reforms panel on the home page, with its status and primary source.
enablesRIGI: more time and more sectorsExtends the RIGI window by a year: more firm megaprojects in Vaca Muerta = more wells = more sustained demand for drilling and frac.see the reform →enablesGoodbye CIBU: used-machinery imports freed upImporting used machinery and heavy equipment no longer goes through the prior certificate (CIBU) → lowers the capex of adding a high-spec spread or a rig, the most expensive part of entering.see the reform →enablesPAÍS Tax: it rose, fell and expiredWithout the PAÍS Tax, bringing in imported equipment gets cheaper: it lowers the capex of the operator and of the supplier that internalizes.see the reform →touchesImporting without a prior permit: from the SIRA to the informational SEDILiberalization cuts both ways: it makes importing equipment cheaper (reinforcing service demand) but adds imported competition for those who only resell domestic hardware. Net favorable to the service niche.see the reform →enablesInvest in Neuquén: the 'Neuquén RIGI' that starts at USD 500,000The 'Neuquén RIGI' starts at USD 500,000 —the size of a services SME—: Turnover Tax and Stamp exemption + fiscal stability for the supplier that locates in the basin.see the reform →This market does not float on its own: concrete megaprojects drive it. These are the ones moving demand for this niche — each with its investment and status.
YPF mega-development: plateau of 240,000 bbl/d in 2032, 1,152 wells. A signal of the scale jump in Neuquén upstream leveraged on already-secured…
see the project →Development of the asset Pluspetrol bought from ExxonMobil. Peak of 100,000 bbl/d + 12 MMm3/d, +600 wells. Includes GyP's mandatory 10% carry.
see the project →Target plateau ~45,000 bbl/d in 2027 (producing ~27,000-28,000 by 2026). Approved into RIGI ~Jun 30, 2026 (20th under the regime, 1st upstream oil)…
see the project →Development of ~70,000 bbl/d, ~380 wells, 35-year concession. GyP 10% carry.
see the project →Who splits the market, where you get in, what pays and what could break it.
already in
split
2026 leader, ~2-to-1 edge over the runner-up; ~1,500 fracs/month. Exclusive 5-year contract with YPF: 4 Zeus e-frac spreads (5,000 HHP/unit, +17% speed; first arrives in October) + OCTIV AutoFrac.
Led the 2025 cumulative (~39%) but fell to 2nd in 2026. Vista ally.
Moved into frac in addition to tubing.
Fourth player.
New entrant via internalization (bought Weatherford's frac). Living proof of the 'operator internalizes its service' model.
Less pronounced duopoly in drilling.
Don't compete head-on in mass pumping: a frac spread costs USD 50-110M and the contracts are captive. You enter from the side:
Deficit of e-frac/dual-fuel equipment. The basin grows +22%/year and there is a shortage of latest-generation spreads: 1-2 electric or dual-fuel spreads under a take-or-pay contract with a mid-sized operator (Vista, PAE, Pluspetrol) or as a JV.
Internalization as an entry model. SPI (Pluspetrol) and AESA (YPF) have already proven that an operator can create its own services arm and capture the duopoly's margin — a gap for an operator-driller/fracturer JV.
High-spec drilling with MPD (Managed Pressure Drilling) and extra-long wells (+4,000 m): few rigs qualify.
High-margin, low-rivalry satellite services: snubbing, long-reach coiled tubing (up to 8,000 m), plug milling, fishing and cleanout in long laterals — niches with 1-3 providers.
Almost all mass pumping is captive: Halliburton+SLB ~70% of stages with multi-year contracts (Halliburton 5-year exclusive with YPF), Tenaris/Calfrac the rest; drilling Nabors+H&P ~54%. A frac spread costs USD 50-110M. Not addressable head-on. estim
Addressable: deficit of e-frac/dual-fuel spreads under take-or-pay with a mid-sized operator, internalization (operator-driller JV, SPI/Pluspetrol model), high-spec/MPD drilling and low-rivalry satellite services (snubbing, long-reach CT). Tens to low hundreds of USD M. estim
Realistic for an entrant: NOT an own frac spread (capital + captive contracts), but a high-spec niche or an internalization JV with a mid-sized operator. thesis
effect
High-value technical employment (frac/drilling crews, equipment maintenance), operator training. It is the heart of the shale's direct employment. thesis
calculate it
Concentration HIGH. Frac: Halliburton+SLB ~70% of stages (6,806 of 9,714 Jan-Apr 2026); fleet of ~a dozen spreads across 5 firms. Drilling: Nabors+H&P ~54%. Being eroded by internalization (SPI debuts, AESA) and Tenaris's entry.
The obvious name is not always the client, and the market is shifting: the operator that internalizes skips the supplier. Three different doors — knowing which is yours is the first step of the sale:
Halliburton and SLB concentrate the bulk of the stages (see the split above); YPF contracted Halliburton 5-year exclusive — its stages line up almost exactly with the supplier's.
Nabors (12 rigs, 3 to Vista), H&P (8, to YPF/Chevron/Tecpetrol) and DLS Archer (added rigs with YPF) — 37 of the country's 44 active drillers operate in Vaca Muerta.
SPI (Servicios Petroleros Integrados, of Pluspetrol) absorbed Weatherford's frac spread, bases and personnel — the operator became its own supplier. AESA does the same inside YPF.
It's not 'what breaks it': it's the dashboard to enter at the right moment. These are the data that signal, before the rest, that demand for drilling and frac equipment is accelerating.
Every meter drilled is a billed rig-day, and wells being drilled (not completed ones) are the fleet of rigs working right now: it is the direct gauge of the drilling leg (~40% of the TAM) and leads the frac, because drilling happens before fracturing. The Secretariat of Energy publishes it monthly, by province and company (series since 2009).
Secretariat of Energy — 'Oil and gas well drilling' dataset, official, monthly, by province ↗To anticipate it even earlier: the rig count (active drilling rigs — ~37 of the country's 44 operate in Vaca Muerta) precedes the well by 1-3 months and is tracked by sector consultancies (Dreizzen's Aleph Energy, Fucello's Fundación Contactos Energéticos) reported by the trade press; and the additions of e-frac/dual-fuel spreads (Halliburton's four Zeus units) signal capacity jumps. The frac stages per month (Annex IV of the Secretariat of Energy) confirm the tempo of the other half of the TAM.
SPI (Pluspetrol) and AESA (YPF) already internalize; if this becomes widespread, the third-party service market shrinks. thesis
Halliburton+SLB with Zeus/OCTIV e-frac raise the technological and efficiency barrier; the sub-scale entrant is left out. thesis
Import liberalization and the end of the PAÍS Tax are already in force: they make importing equipment cheaper —lowering the operator's capex and reinforcing service demand— but add imported competition for the LOCAL equipment supplier. Net favorable to the service/operation niche, adverse to those who only resell domestic hardware. verif the trigger
The TAM is built from a few live variables, with two converging bottom-up methods (well capex and frac stages). Each variable carries its freshness stamp — what changes often and what barely moves.
The number rests on a few variables. Change one and it recalculates itself; each carries its freshness seal — how often it is worth revisiting. estim
Every figure is checked against its source before we publish it. Here we show what backs it — and where the verified data ends and our estimate begins.
The figure holds up via two converging paths: ~470-500 wells at USD 14M each —of which drilling + frac are ~85%—, and 23,896 frac stages at ~USD 210-270k effective per stage (the ~300k of the 18-stage witness well drops at 50-stage scale). On the front we report only the pure service (~USD 2,500-3,500M), excluding sand, water and chemicals —counted as their own niches— so as not to add the same thing twice. The fine split between drilling and frac is the softest part and we mark it as an estimate.
12registered sources2official or agencies2of high reliabilityEvery data point on the site links to its source.
Get on board the takeoff
This week’s updates: the map of drilling rigs and frac spreads (services) and the niches opening up, related courses and new provinces as they launch. Free.