$1.6B
USD
Market cap · 2026–06 · week 25
🇳🇱 Netherlands, Houston
Country
Oil & Gas
Sector
Oilfield Services · Mid-Tier · Upstream · Europe · South America · USA
Metal Pilot is under active development and this page may change daily. Much of the content was AI-generated and may be incomplete or inaccurate. Treat all details as a starting point, and verify anything material against the issuer's official disclosures before investing.
Overview:
Expro Group Holdings N.V. is a mid-tier oilfield services company headquartered in Houston, Texas, with operations in over 50 countries. The company provides a broad portfolio of services across the well life cycle, including well construction, well flow management, subsea well access, and well intervention and integrity solutions. The business model focuses on delivering cost-effective, technology-enabled services to national oil companies, international oil companies, and independent exploration and production companies in both onshore and offshore environments. Key capabilities include tubular running services, cementing, well testing, early production facilities, and subsea test tree assemblies. The organization leverages its global footprint across North and Latin America, Europe and Sub-Saharan Africa, the Middle East and North Africa, and Asia-Pacific to support customer operations. The business is subject to commodity-price cycles and the capital expenditure budgets of its exploration and production customer base.
Strategy:
Strategic focus centers on advancing the products and services portfolio to provide customers with cost-effective, innovative solutions to produce oil, natural gas, and geothermal resources more efficiently and with a lower carbon footprint. The enterprise intends to exceed industry expectations regarding safety and operational performance while sustaining a relentless drive for efficiency and better utilization of existing assets. Capital allocation is prioritized to support above-market revenue growth, strong profitability, and sustained generation of free cash flow. The organization's approach involves leveraging the power of data to improve business practices and deliver more value to customers. The company also remains selective in pursuing low-carbon opportunities, including early-stage carbon capture and storage and flare reduction, to support operators' drive for increased sustainability.
Management:
Executive leadership is headed by President and CEO Michael Jardon, who has served in various technical and executive roles at Expro, Vallourec, and Schlumberger Limited since 1992. The Board of Directors is led by Chairman Robert W. Drummond. Key executives include Chief Financial Officer Sergio Maiworm, who previously served as CFO at Talos Energy, and Chief Operating Officer Alistair Geddes. The Board oversees corporate strategy through several committees, including the Audit Committee, the Compensation Committee, and the Environmental, Social and Governance Committee.
Sustainability:
The organization's sustainability framework is guided by its core values of People, Performance, Partnerships, and Planet. A key environmental initiative involves providing flare reduction and other emissions management solutions to assist customers in lowering their carbon footprint. The company tracks safety performance through Lost Time Injury Frequency and Total Recordable Case Frequency rates, achieving an LTIF of 0.00 and a TRCF of 0.37 in 2025. Social programs include employee-driven regional online wellness hubs and an Employee Assistance Program providing 24/7 health and wellbeing support globally. The enterprise maintains a comprehensive Code of Conduct and requires annual compliance certification from all employees worldwide.
Structure:
A significant structural change occurred in May 2024 when the company acquired CTL UK Holdco Limited (Coretrax) for approximately $186.7 million, expanding its portfolio of well construction and well intervention solutions. Previously, in October 2023, the entity acquired Professional Rental Tools, LLC (PRT Offshore) for $90.8 million to enhance its subsea well access sector capabilities. The corporate structure includes two material joint ventures: a 50% equity interest in COSL - Expro Testing Services (Tianjin) Co. Ltd (CETS) operating in China, and a 49% equity interest in PV Drilling Expro International Co. Ltd. (PVD-Expro) operating in Vietnam. In July 2025, the company entered into a new $500 million senior secured revolving credit facility to support general corporate purposes and future acquisitions.
Hedge:
The company maintains an unhedged posture regarding commodity prices, as it does not produce hydrocarbons. Foreign-exchange risk is managed by seeking to naturally hedge exposure, offsetting non-USD denominated inflows with non-USD denominated local expenses, particularly for exposures to the British pound and Norwegian kroner, and the company generally does not enter into forward hedging agreements. Interest-rate exposure on the variable-rate revolving credit facility is monitored, but no interest-rate swaps were outstanding as of December 31, 2025.
Source:
Expro Group Holdings N.V. - 10-K Filing - 2025
- The tables below list unit codes most often used in the Oil & Gas sector for this company. MetalPilot stores contained metal or product in the codes below; grade and tonnage use separate fields. In side-by-side comparison views (stock page Portfolio tab, watchlist By sector), heterogeneous source units are converted to each commodity's preferred display unit (for example Moz Au, kt Cu, MMbbl oil) before summing; the same canonical codes appear in project data.
- The Portfolio tab presents a project-level view of the company's reported assets, built from publicly disclosed information (technical reports, annual filings, MD&A, investor presentations, MRMR / R&R statements, NI 43-101 / NI 51-101 / SEC S-K 1300 / SEC S-K 1200 / JORC / SAMREC / PERC / PRMS / COGEH filings, and similar primary sources).
- Figures are grouped by project type (mining, oil & gas, royalty, stream, processing facility, development, portfolio aggregate) and are shown alongside the headline reserve base, headline production, headline grade / quality, cost benchmarks, estimated lifetime, commercial terms (for royalties / streams), operational capacity (for processing) and a single-figure rating where the underlying data supports one.
- Each data table on the Portfolio tab is followed by ONE Assumptions footnote describing the modelling choices for that table; KPI stat-card assumptions appear in the bottom block instead. All legal and section disclaimers are merged into a single disclaimer list at the bottom of the Portfolio tab.
- 1P/2P/3P — cumulative uncertainty. 1P = Proved (≥90%); 2P = Proved+Probable (≥50%, primary non-SEC metric); 3P adds Possible (≥10%). SEC filers often publish 1P only.
- Contingent (1C/2C/3C) = discovered, sub-commercial. Prospective (1U/2U/3U) = undiscovered. Neither feeds economic models without further work.
- Developed vs Undeveloped: PDP (producing), PDNP (developed non-producing), PUD (undeveloped). Reserves walk PUD→PDP is reclassification, not new discovery.
- BOE uses 6 Mcf gas : 1 bbl oil (thermal, not economic). Some issuers use 5.8:1 — read footnotes.
- Pricing case: Forecast vs Constant (NI 51-101/PRMS) or SEC 12-month average. Do not add cases together.
- Portfolio KPIs — company-level headline numbers aggregated from the featured projects (project counts, attributable annual production by commodity, attributable resource base by commodity, last filing date, operator share). USD value lines multiply attributable volumes by the resolved snapshot price.
- Portfolio snapshot — one-screen summary of the portfolio: counts by type and status, country mix, reporting standards used, operator share, primary commodity, attributable annual production summary and attributable resource base summary.
- Oil & Gas — one row per O&G project (typically a field, licence, play or basin asset), with columns for location, status, primary hydrocarbons, production (with rating), reserves & resources (with rating), costs and estimated lifetime.
- Royalty — one row per royalty interest held by the company. Columns cover the underlying project, operator, commodity, commercial terms (rate, type, cap, area-of-interest), attributable production, attributable reserves and estimated lifetime.
- Stream — one row per metal stream held by the company. Each row shows the underlying project, the streamed commodity, the headline stream percentage, the ongoing per-ounce / per-tonne payment, and attributable production / reserves.
- Processing facilities — one row per midstream / processing facility (pipeline, fractionator, LNG train, storage cavern, refinery, smelter, mill, heap-leach pad, CPP, etc.). Columns include nameplate capacity, contracted capacity, feedstock commodities and operational footprint.
- Development — projects in development status or in a pre-production lifecycle phase. The production column is re-labelled 'Targeted production (rating)' to highlight that the figures are plans, not actuals.
- Portfolio Aggregate — a single company-level row used when the company itself publishes a portfolio rollup (e.g. company-wide 2P barrels across all properties).
- Reserves & resources — detail — a leaf-category pivot showing every reserve and resource category disclosed across the projects.
- Reserves walk — gross (disclosed) — year-by-year reconciliation of the opening balance to the closing balance, broken into Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production and Conversion to developed.
- Reserves walk — net change by year — per-year summary of net additions and net deductions across the portfolio.
- NPV (grouped) — all NPV rows captured from the filings, grouped by commodity, resource category, development status and pricing case. Each NPV figure is shown with its discount rate, basis (before-tax / after-tax), currency and value scale.
- Ownership percentage means the company's working-interest share of the asset: its slice of the project before royalties and before government take. It is shown on a 0–100 scale.
- Mines, oil and gas fields, and processing facilities — this is how much of the asset belongs to the company under that working-interest idea. One hundred percent is fully owned; a lower number usually means partners share the rest.
- Royalties and streaming agreements — the percentage is often not the story; what matters economically is usually the royalty or stream rate, shown elsewhere alongside these figures.
- Oil and gas — read this as gross working interest only. Do not treat it as net production or net wells after royalties; when filings distinguish gross from net, that shows up in how the resource numbers themselves are labelled.
- Below 100% — the short summary for each project names other owners and their stakes when the source says who they are.
- NRI vs WI (O&G). Working interest (WI) is the obligation to pay a share of costs; net revenue interest (NRI) is the share of revenue after royalties and overriding-royalty interests. A 100% WI well rarely produces 100% NRI; typical onshore U.S. NRI is 75–87.5% of WI depending on the lease royalty.
- Operator vs non-operator. The operator runs day-to-day operations; non-operating partners pay their WI share of costs but do not run the asset. Some Portfolio rows show operator share where disclosed.
Oil equivalent (BOE)
Oil equivalent (BOE)
-
See commodity documentation in the domain package.
Oil
Generic crude (undifferentiated)
WTI
Use West Texas Intermediate directly as a coarse benchmark when the filing does not split product quality.
Natural gas
Pipeline natural gas
Henry Hub
Henry Hub is the reference US benchmark for US pipeline gas; use it directly when the disclosure is Hub-indexed.
NGL
NGL barrel (mixed NGLs)
Mont Belvieu NGL basket vs WTI
NGL barrels often track a fraction of crude; order-of-magnitude context is commonly cited around two-fifths to three-fifths of WTI.
Shale gas
Gas from shale / tight reservoirs
Henry Hub plus regional basis
Regional hubs price as Henry Hub plus or minus basis; shale supply broke tight coupling to oil, so do not back-solve shale gas from WTI.
Light oil
Light sweet crude
WTI / Brent
WTI and Brent are often treated as roughly 1:1 for light sweet barrels when a single anchor is enough.
Heavy oil
Heavy sour crude
WCS vs WTI
Western Canadian Select–style heavy blends often trade on the order of $10–20/bbl below WTI when differentials are in a normal range.
Bitumen
Oil-sands bitumen blend
WCS vs WTI
Same broad idea as heavy oil: bitumen blends anchor to wide differentials versus light sweet benchmarks such as WTI.
Synthetic crude
Upgraded oil-sands synthetic crude (SCO)
SCO vs WTI
Synthetic crude typically tracks WTI within a few dollars — sometimes near par, sometimes a small premium or discount.
Condensate
Field condensate / diluent
US condensate vs WTI
Field condensate can trade below WTI; some multi-year averages have been in the high single-digit dollars per barrel under WTI.
Coal bed methane
Coalbed methane (CBM)
Regional hub vs Henry Hub
CBM is usually quoted off a regional benchmark versus Henry Hub; it is a distinct product stream from tight shale gas in many filings.
- The Commodity column shows normalized labels; values are stored as snake_case CommodityCode strings in pkg/domain and project resource rows (for example shale_gas, oil_equivalent).
- Benchmarks and typical relationship cells are informal market context for reading disclosures — they are not MetalPilot price inputs.
- API gravity — lower = heavier. Light crude is ≥ 31.1° API (≤ 870 kg/m³); heavy is 22.3–31.1° API; extra-heavy is < 22.3°. Bitumen is ≤ 10° API.
- Sulphur — sweet vs sour. Sweet crude has ≤ 0.5% sulphur; sour > 0.5%. Refineries price the discount on sour crude into the differential.
- WTI vs Brent vs WCS. WTI (West Texas Intermediate, Cushing OK) is the U.S. light-sweet benchmark; Brent (North Sea) is the global light-sweet benchmark; WCS (Western Canadian Select) is the heavy/sour benchmark for Canadian production.
BOE
Barrel of oil equivalent
Combined oil + gas energy reporting. Computed at 6 Mcf gas : 1 bbl oil (thermal, not economic). Read footnotes for non-6:1 conventions.
Mboe
Thousand BOE
Oil & gas sub-field scale. Oilfield M = 1,000.
MMboe
Million BOE
Corporate or field BOE totals. Oilfield MM = 1,000,000.
Mcfe
Thousand cubic feet equivalent
Gas + liquids on an energy-equivalent basis (typically 1 bbl ≈ 6 Mcf).
Bcfe
Billion cubic feet equivalent
Large combined-stream reserves or production (1 Bcfe = 10⁶ Mcfe; same 6:1 bbl rule as Mcfe).
bbl
Barrel (~158.99 L)
Crude and liquid hydrocarbon volumes. 1 bbl = 42 US gallons ≈ 0.15899 m³.
Mbbl
Thousand barrels
Mbbl — sub-field liquid scale (M = Roman numeral 1,000 in oilfield convention).
MMbbl
Million barrels
Standard oil reserves / resources (MM = million in oilfield convention). Often used interchangeably with MMSTB in North American filings.
STB
Stock tank barrel
Oil at surface standard conditions (60 °F / 14.7 psi). Eliminates ambiguity from temperature / pressure swings underground.
MSTB
Thousand stock tank barrels
MSTB — sub-field liquid scale.
MMSTB
Million stock tank barrels
MMSTB — SPE-PRMS style oil reserves; the international canonical unit for liquid hydrocarbons.
Mcf
Thousand cubic feet
Natural gas volume (Mcf). Equivalent to Mscf in practice; Mscf adds the explicit standard-conditions note.
MMcf
Million cubic feet
MMcf — gas at field or corporate scale.
scf
Standard cubic foot
Gas at surface standard conditions (60 °F / 14.7 psi).
Mscf
Thousand standard cubic feet
Mscf — same order as Mcf; international / PRMS gas reporting.
MMscf
Million standard cubic feet
MMscf — field- or corporate-scale standard gas volumes.
Bcf
Billion cubic feet
Large gas-field reserves. 1 Bcf ≈ 0.167 MMboe at 6:1.
Bscf
Billion standard cubic feet
BSCF — reserves under standard conditions; international reporting.
Tcf
Trillion cubic feet
Basin-scale or national gas resources. 1 Tcf ≈ 167 MMboe at 6:1.
Tscf
Trillion standard cubic feet
TSCF — basin-scale standard gas resources.
GJ
Gigajoule (10⁹ J)
Thermal coal energy content; LNG energy reporting; 1 GJ ≈ 0.948 MMBtu.
Count
Count
See project resource documentation.
Other
Other / nonstandard
Verbatim source label; pair with commodity and original_classification when the unit is not yet mapped.
- Compound product names (LCE, U₃O₈, V₂O₅, Li₂O) belong on the commodity field, not inside contained_unit. Example: "kt LCE" → unit kt with commodity LCE; "Mlb U₃O₈" → unit mlb with commodity U3O8.
- In oilfield shorthand, M often means thousand and MM means million (e.g. mcf = thousand cubic feet; mmcf = million cubic feet). Metric codes (Mt, Moz, Mlb) always use M = million — context decides.
- The schema may also carry cpht on resource rows for diamond recovered grade; the same symbol is listed under Grade units.
- This tab highlights sector-typical units; the schema and importers still accept the full contained_unit enum from the domain package.
Percent (%)
Percent (%)
Generic grade when the payable element is obvious from the commodity column (e.g. Fe % in iron ore, Cu % in copper-only deposits). Use a specific unit (pctli2o, pctu3o8) when there is any ambiguity.
Other
Other / nonstandard
Source-specific grade; document the basis in original_classification or notes.
Btu/lb
BTU per pound (Btu/lb)
Natural-gas and thermal-coal heating value. Coal rank proxy (sub-bituminous ~8,000 Btu/lb; bituminous 11,000 – 14,000; anthracite >14,000).
- Use pctli2o and pctu3o8 when the source reports % Li₂O or % U₃O₈ explicitly; reserve generic percent for deposits where the payable metal is obvious from context.
- For ppm grades, the commodity column carries the element or compound (for example vanadium as V₂O₅) so the grade row stays unambiguous.
- Grade-on-grade conversions: 1 g/t ≈ 0.029 oz/short ton; 10,000 ppm = 1%; 10 kg/t = 1%; 1% U₃O₈ ≈ 0.848% U metal; 1% Li₂O ≈ 0.464% Li metal.
Metric tonne (t)
Metric tonne (1,000 kg)
Ore, waste, and plant throughput mass. Not the same as the U.S. short ton.
Thousand tonnes (kt)
Thousand metric tonnes
Base-metal deposits, coal seams at mine scale, fertilizers.
Million tonnes (Mt)
Million metric tonnes
Iron ore, coal, large porphyry tonnage. Metric Mt is always 10⁶ t (M = million in metric).
Cubic metre (m³)
Cubic metre (m³)
Brine cells, small heap-leach volumes.
Million cubic metres (Mm³)
Million cubic metres (Mm³)
Salar brine volumes, reservoir void space.
Cubic kilometre (km³)
Cubic kilometre (km³)
Basin-scale brine or aquifer models.
Acre-foot (ac-ft)
Acre-foot (~1,233 m³)
U.S. / South American brine and water-resource reporting.
- Tonnage and brine/reservoir volumes describe the orebody or fluid cell, not contained metal; contained metal is the product of tonnage × grade (with unit-aware conversions where needed).
- Brine and ISR deposits often report m³, Mm³, km³, or acre-feet instead of rock mass when the disclosure is volumetric.
- A short ton (US) is ~907 kg — about 7.4% less than a metric tonne. Legacy U.S. filings that report "Mt" of coal often mean Mst (million short tons).
- The conversions below appear regardless of sector — they are the ones readers most often need when reading a filing next to a table screenshot.
- Troy oz → Grams — × 31.1035 — precious-metal reserves use troy ounces.
- Avoirdupois oz → Grams — × 28.3495 — the everyday ounce; different unit from troy oz.
- Pound (lb) → Kilograms — × 0.45359 — avoirdupois pound.
- Short ton (st) → Metric tonnes (t) — × 0.90718 — a short ton is ~7.4% less than a metric tonne.
- g/t → oz / short ton — × 0.02917 — precious-metal grade conversion.
- ppm → % — × 10⁻⁴ — 10,000 ppm = 1%.
- kg / t → % — × 0.1 — 10 kg/t = 1%.
- Acre-foot → Cubic metres (m³) — × 1,233.5 — brine and water disclosures.
- Oil & gas conversions cover BOE thermal equivalence, volumetric crude conversions and the API-gravity / SG link.
- Mcf (gas) → Boe (energy) — × 1/6 — 6 Mcf gas ≈ 1 boe (thermal, not economic).
- Bbl → Cubic metres (m³) — × 0.15899 — 1 bbl ≈ 158.99 L.
- Tonnes LNG → Boe — × ~7.4 — thermal; varies with LNG composition.
- GJ → MMBtu — × 0.94782 — energy conversion.
- API gravity → Specific gravity — SG = 141.5 / (131.5 + API) — heavy < 22.3° API, light ≥ 31.1° API.
- Mcfe → MMboe → — — × 10⁻⁶ × (1/6) — combined-stream conversion.
- A 1 Bcm natural-gas reservoir is ≈ 35.3 Bcf ≈ 5.88 MMboe.
- Operating Cost / boe (O&G) — total operating expense ÷ boe produced; excludes royalties and taxes.
- Cash Cost / boe — operating cost / boe + transportation + production taxes / royalties.
- F&D Cost — Finding & Development cost per boe.
- Reserve Replacement Cost — capex (organic + acquisitions) per boe of reserves added.
- All cost metrics are non-GAAP and defined differently across companies; the same metric label may mean different things at different issuers.
- WI (×x%) — Working interest: disclosed gross value multiplied by ownership %. Applies to mining / O&G / processing-facility rows whose reporting_basis is gross or unset.
- Royalty (×r%) — Royalty / stream rate: gross property value multiplied by the headline interest rate (NSR %, stream %, …). Applies to royalty / stream rows on gross or unset reporting_basis with interest_rate set.
- Net (×1.0) — Disclosure is already net of royalties (reporting_basis = company_net_after_royalty). No further adjustment.
- Gross WI (×1.0) — Disclosure is already on a working-interest basis (reporting_basis = company_gross_wi). No further adjustment.
- Fully owned WI rows render as plain WI (no parenthetical). See METALPILOT Part 2 §3 (Ownership and reporting-basis attribution) and pkg/calc/attribution.go (EffectiveOwnershipMultiplier / EffectiveOwnershipAttribution).
- "M" can mean thousand or million depending on context. Oilfield convention uses M = thousand and MM = million (MMcf, MMbbl, MSTB). Metric codes (Mt, Moz, Mlb) always use M = million.
- Troy ounce ≠ avoirdupois ounce. 1 troy oz = 31.1035 g; the everyday ounce is 28.3495 g. Precious-metal reserves are always troy.
- Short ton ≠ metric tonne. A short ton (US) = 907 kg; a metric tonne = 1,000 kg. Reading legacy "1 Mt" coal as metric when it was short tons over-states tonnage by ~10%.
- Gross vs net. Gross is usually the 100% property number; net is usually working-interest share before royalties. Check reporting_basis.
- Inferred / Contingent / Prospective volumes are not bookable reserves and do not feed Portfolio economic figures.
- SPE-PRMS — Society of Petroleum Engineers Petroleum Resources Management System. Defines 1P/2P/3P, 1C/2C/3C, 1U/2U/3U.
- NI 51-101 — CSA Standards of Disclosure for Oil and Gas Activities. Mandatory for TSX O&G issuers; dual Forecast + Constant disclosure.
- COGEH — Canadian Oil and Gas Evaluation Handbook. Technical companion to NI 51-101.
- SEC S-K 1200 / Rule 4-10 — U.S. SEC oil & gas disclosure for SEC-registered O&G issuers.
- 1P / Proved — Reserves recoverable with ≥90 % probability (P90). SEC standard is 'reasonable certainty'.
- 2P / Proved + Probable — Reserves recoverable with ≥50 % probability (P50). Primary metric for non-SEC O&G disclosure.
- 3P / Proved + Probable + Possible — Reserves recoverable with ≥10 % probability (P10).
- Contingent Resources — discovered, sub-commercial volumes pending contingencies (price, infrastructure, technology, regulation). Reported as 1C (low) / 2C (best) / 3C (high).
- Prospective Resources — undiscovered leads and prospects awaiting drilling. Reported as 1U (low) / 2U (best) / 3U (high).
- Development status (orthogonal axis): PDP = Proved Developed Producing, PDNP = Proved Developed Non-Producing, PUD = Proved Undeveloped.
- Pricing case: Forecast (NI 51-101 / COGEH), Constant (NI 51-101 / COGEH), or SEC (12-month first-of-month average). Forecast and Constant cases of the same reserve are not additive.
- BOE / Mcfe conversion uses a 6:1 thermal ratio (6 Mcf = 1 boe) unless the source declares otherwise. Thermal equivalence, not economic equivalence.
- Presented values are denominated in currency of the country where the company is headquartered. Values like market capitalization might differ from the values visible in other parts of the page, where the currency is always USD.