EM
$571.2B
USD
Market cap · 2026–06 · week 25
🇺🇸 United States, Spring
Country
Oil & Gas
Sector
Integrated Oil & Gas · Senior · Upstream · Oil-weighted · Oil · Asia · 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:
Exxon Mobil Corporation is a senior integrated oil and gas producer headquartered in Spring, Texas, operating globally across the full hydrocarbon and chemicals value chain. The portfolio is organized into four business lines: Upstream exploration and production, Energy Products (refining and fuels), Chemical Products, and Specialty Products, complemented by a Low Carbon Solutions business. Key upstream assets include the Permian Basin in West Texas and New Mexico, the Stabroek Block offshore Guyana, global LNG operations, and the Kearl oil sands joint venture in Canada. The advantaged-asset core of Permian, Guyana, and LNG currently supplies about two-thirds of global production and is expected to grow as a share of the mix. The business model integrates upstream resource extraction with downstream refining, chemical manufacturing, and specialty products to capture value across the chain and dampen single-segment volatility. Processing and production infrastructure spans large refineries, chemical plants, LNG trains such as the Golden Pass export project, and oil sands extraction and froth-treatment facilities. The enterprise leverages scale, proprietary technology, and a global footprint to sustain competitiveness. It remains exposed to commodity price cycles, evolving greenhouse-gas regulation, and geopolitical and security risks across its operating regions.
Strategy:
Strategic focus centers on building an industry-leading portfolio underpinned by advantaged, low cost-of-supply growth projects, particularly in the Permian Basin, offshore Guyana, and LNG expansion opportunities in Qatar, Mozambique, Papua New Guinea, and the United States. The enterprise intends to increase Permian Basin production to approximately 2.5 million oil-equivalent barrels per day by 2030 and anticipates eight floating production, storage and offloading vessels in operation on the Stabroek Block by year-end 2030, having taken a 2025 final investment decision on the Hammerhead development. Capital allocation is prioritized toward low cost-of-supply opportunities and disciplined expense management, targeting $20 billion of structural cost savings between 2019 and 2030, of which an estimated cumulative $15.1 billion had been realized through 2025. A core objective is to advance lower-emission investments through the Low Carbon Solutions business, focused on carbon capture and storage, hydrogen and ammonia, lower-emission fuels, and lithium. The organization continues to expand advanced recycling capacity to convert hard-to-recycle plastic waste into feedstock, reinforcing its specialty and chemical growth ambitions.
Management:
Executive leadership is headed by Chairman of the Board and Chief Executive Officer Darren W. Woods, who has held the combined role since January 1, 2017. The senior team includes Senior Vice President and Chief Financial Officer Neil A. Hansen, appointed effective February 1, 2026, and Senior Vice President Jack P. Williams, Jr., who has served in that role since June 1, 2014. The Board of Directors oversees corporate strategy and enterprise risk management, including cybersecurity and environmental compliance, and discharges its responsibilities through standing committees covering audit and compensation among other functions. Governance practices emphasize rigorous internal control over financial reporting and a structured enterprise risk-management system designed to identify and manage risk across the upstream, downstream, chemical, and specialty businesses. The Board oversees cybersecurity risk through a dedicated program detailed in the company's risk-management disclosures, reflecting the Corporation's regular exposure to attempted disruptions from state-sponsored and other actors. The framework is anchored by Corporate Governance Guidelines and a Code of Ethics and Business Conduct that set expectations for directors, officers, and employees, and the chief executive officer also serves as the chief operating decision maker for segment-performance review.
Sustainability:
The organization's sustainability framework includes an announced ambition to achieve net-zero Scope 1 and 2 greenhouse-gas emissions across its operated assets by 2050, supported by asset-level emission-reduction roadmaps first completed in 2022. A near-term milestone targets net-zero Scope 1 and 2 emissions in the integrated Permian Basin operated assets, including the acquired Pioneer assets, by 2035. By 2030, the company plans corporate-wide reductions in greenhouse-gas intensity, methane intensity, and flaring intensity relative to a 2016 baseline, alongside an objective to eliminate routine flaring in line with the World Bank Zero Routine Flaring initiative and to reach near-zero methane emissions from operated assets. The enterprise is scaling advanced recycling, expanding capacity at its Baytown facility to process hard-to-recycle plastic waste toward a targeted global recycling capacity, and is developing carbon capture and storage, hydrogen, ammonia, and lithium projects through its Low Carbon Solutions business. Additional lower-emission and specialty initiatives span projects to produce hydrogen and ammonia, lower-emission fuels, Proxxima resin systems, carbon materials, and lithium. These initiatives are intended to position the Corporation to play a leading role in the energy transition as supportive policy and technology develop, while management cautions that net-zero pathways remain dependent on policy support and technological advancement that society has not yet achieved.
Structure:
A transformational structural change occurred on May 3, 2024, when the Corporation acquired Pioneer Natural Resources Company in an all-stock transaction, issuing 545 million shares with a fair value of approximately $63 billion and assuming debt with a fair value of about $5 billion, significantly expanding its Permian Basin footprint. On November 2, 2023, the entity acquired Denbury Inc., a developer of carbon capture, utilization, and storage solutions with enhanced oil recovery and Gulf Coast and Rocky Mountain operations, through the issuance of 46 million shares valued at approximately $4.8 billion. The corporate structure includes numerous joint ventures and equity companies, including a 25% interest in Tengizchevroil, LLP in Kazakhstan, a 16.8% working interest in the Kashagan field, and a 7.5% interest in the Caspian Pipeline Consortium that exports the associated production. In the Kearl oil sands joint venture, Imperial Oil Limited holds a 70.96% interest and ExxonMobil Canada Properties the remaining 29.04%, with the Corporation holding a 69.6% interest in Imperial Oil. In November 2025, the company completed the divestment of Esso Société Anonyme Française SA and ExxonMobil Chemical France SAS, including the associated refinery and related assets.
Hedge:
The Corporation uses commodity-based contracts, including derivatives, to manage commodity price risk and to generate returns from trading activities, recognizing in earnings all gains and losses on derivatives for which hedge accounting is not applied. It operates a program to hedge certain fixed-rate debt instruments against changes in fair value due to changes in the designated benchmark interest rate, using fixed-for-floating interest rate swaps under fair value hedge accounting, with swap settlement dates corresponding to the interest payments on the hedged debt. At December 31, 2025, the net notional position of derivative instruments comprised a short position of 449 million MMBTUs of natural gas and a short position of 27 million barrels of petroleum products, alongside a long position of 6 million barrels of crude oil. These positions reflect both trading activity and the management of price exposure across the integrated portfolio.
Source:
Exxon Mobil Corporation - 10-K Filing - 2025
Portfolio Aggregate · 2 projects
Portfolio mode — asset rows are for context only; tab totals use the company aggregation.
ExxonMobil Worldwide Upstream
Portfolio
United States
Oil
5/5
Natural gas
5/5
Oil Gas
Type
Operating
Status
🇺🇸 United States
Country
Project information
As at 31 December 2025
Aggregation level:
Company portfolio
Aggregation level:
Company portfolio
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Conventional Oil Gas
Extraction:
Conventional Oil Gas
Description
As at 31 December 2025
Worldwide proved-reserves and production rollup for Exxon Mobil Corporation (consolidated subsidiaries plus equity companies). Total proved reserves of 19.3 GOEB at YE2025 (vs 19.6 GOEB YE2024); 7.0 GOEB (36%) proved undeveloped. In 2025, ~1.4 GOEB transferred from proved undeveloped to developed; extensions/discoveries added ~2.1 GOEB (primarily US and Guyana); ~1.0 GOEB reclassified out of proved (primarily US); asset sales 0.1 GOEB; production 1.8 GOEB. $19.0B invested in 2025 to progress proved undeveloped development ($18.8B oil & gas producing activities). 2025 upstream production 4.7 Moebd — highest in over 40 years; ~2/3 of global production from Permian, Guyana and LNG. 12% of YE2025 proved reserves under PSC arrangements. PUDs held >5 years concentrated in Australia (Gorgon-Jansz compression) and UAE (Upper Zakum).
Portfolio Aggregate
Multiple effective dates · 1P
| Commodity | Production | Reserves & Resources | Production value (est.) |
|---|---|---|---|
|
Oil
|
825.63 mmboe/yr
|
8 187 mmboe 1P
|
$66.9B (71%)
USD 81.08 / bbl
|
|
Natural gas
|
513.55 mmboe/yr
|
6 068 mmboe 1P
|
$9.7B (10%)
USD 3.16 / mcf
|
|
NGL
|
223.38 mmboe/yr
|
2 437 mmboe 1P
|
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
|
|
Bitumen
|
140.53 mmboe/yr
|
2 330 mmboe 1P
|
$7.0B (7%)
≈ $50 / bbl pre-upgrade
|
|
Synthetic crude
|
24.82 mmboe/yr
|
288 mmboe 1P
|
$2.0B (2%)
≈ $80 / bbl
|
Commodity
Production
Reserves & Resources
Production value (est.)
Oil
825.63 mmboe/yr
8 187 mmboe 1P
$66.9B (71%)
USD 81.08 / bbl
Commodity
Production
Reserves & Resources
Production value (est.)
Natural gas
513.55 mmboe/yr
6 068 mmboe 1P
$9.7B (10%)
USD 3.16 / mcf
Commodity
Production
Reserves & Resources
Production value (est.)
NGL
223.38 mmboe/yr
2 437 mmboe 1P
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
Commodity
Production
Reserves & Resources
Production value (est.)
Bitumen
140.53 mmboe/yr
2 330 mmboe 1P
$7.0B (7%)
≈ $50 / bbl pre-upgrade
Commodity
Production
Reserves & Resources
Production value (est.)
Synthetic crude
24.82 mmboe/yr
288 mmboe 1P
$2.0B (2%)
≈ $80 / bbl
Oil
825.63 mmboe/yr
8 187 mmboe 1P
$66.9B (71%)
USD 81.08 / bbl
Natural gas
513.55 mmboe/yr
6 068 mmboe 1P
$9.7B (10%)
USD 3.16 / mcf
NGL
223.38 mmboe/yr
2 437 mmboe 1P
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
Bitumen
140.53 mmboe/yr
2 330 mmboe 1P
$7.0B (7%)
≈ $50 / bbl pre-upgrade
Synthetic crude
24.82 mmboe/yr
288 mmboe 1P
$2.0B (2%)
≈ $80 / bbl
Portfolio Aggregate — Assumptions & Disclaimers
- When a Portfolio Aggregate row exists, individual asset rows are not summed into it — that would double-count.
- The aggregate typically comes from the annual reserves statement and may use a different effective date than individual asset rows.
- Production value (est.) is attributable annual production × the resolved commodity price (compact USD with an optional mix share in parentheses when multiple commodities contribute; short price label on the second line). Estimated lifetime is not shown on this table — use per-asset Oil & Gas sections for reserve life.
- Portfolio-level rollups are convenient for company-vs-company comparisons but can mask asset-level concentration risk: a single producing field or mine may account for the majority of the rollup figure.
Oil & Gas inventory & footprint
Multiple effective dates
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
-
|
-
|
-
|
-
|
733 drilled
FY 2025
|
518 WIP
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
-
-
-
-
733 drilled
FY 2025
518 WIP
-
-
-
-
733 drilled
FY 2025
518 WIP
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Reserves & resources — detail
As at 31 December 2025
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Oil
|
1P
|
Net
|
Sec
|
6 285 mmboe
|
460 mmboe
|
−302 mmboe
|
0
|
156 mmboe
|
314 mmboe
|
−16 mmboe
|
−531 mmboe
|
−547 mmboe
|
0
|
861 mmboe
|
6 052 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Natural gas
|
1P
|
Net
|
Sec
|
4 024.5 mmboe
|
332.83 mmboe
|
−289.67 mmboe
|
0
|
1.17 mmboe
|
44.33 mmboe
|
−71.17 mmboe
|
−337.33 mmboe
|
−408.5 mmboe
|
0
|
452.83 mmboe
|
3 660.33 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
NGL
|
1P
|
Net
|
Sec
|
1 176 mmboe
|
272 mmboe
|
−110 mmboe
|
0
|
2 mmboe
|
164 mmboe
|
−5 mmboe
|
−99 mmboe
|
−104 mmboe
|
0
|
268 mmboe
|
1 236 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Oil
|
1P
|
Net
|
Sec
|
6 052 mmboe
|
967 mmboe
|
606 mmboe
|
0
|
877 mmboe
|
2 450 mmboe
|
−74 mmboe
|
−679 mmboe
|
−753 mmboe
|
0
|
3 203 mmboe
|
7 749 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Natural gas
|
1P
|
Net
|
Sec
|
3 660.33 mmboe
|
459 mmboe
|
−74.33 mmboe
|
0
|
674 mmboe
|
1 058.67 mmboe
|
−33.83 mmboe
|
−367.83 mmboe
|
−401.67 mmboe
|
0
|
1 460.33 mmboe
|
4 317.33 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
NGL
|
1P
|
Net
|
Sec
|
1 236 mmboe
|
489 mmboe
|
−128 mmboe
|
0
|
730 mmboe
|
1 091 mmboe
|
−15 mmboe
|
−148 mmboe
|
−163 mmboe
|
0
|
1 254 mmboe
|
2 164 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Oil
|
1P
|
Net
|
Sec
|
7 749 mmboe
|
988 mmboe
|
−430 mmboe
|
0
|
38 mmboe
|
596 mmboe
|
−72 mmboe
|
−728 mmboe
|
−800 mmboe
|
0
|
1 396 mmboe
|
7 545 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Natural gas
|
1P
|
Net
|
Sec
|
4 317.33 mmboe
|
546.67 mmboe
|
−185 mmboe
|
0
|
39 mmboe
|
400.67 mmboe
|
−48.33 mmboe
|
−390.67 mmboe
|
−439 mmboe
|
0
|
839.67 mmboe
|
4 279 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
NGL
|
1P
|
Net
|
Sec
|
2 164 mmboe
|
513 mmboe
|
−373 mmboe
|
0
|
41 mmboe
|
181 mmboe
|
−12 mmboe
|
−194 mmboe
|
−206 mmboe
|
0
|
387 mmboe
|
2 139 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
ExxonMobil Worldwide Upstream (Portfolio)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
6 285 mmboe
+ Ext. & disc.
460 mmboe
+ Revisions
−302 mmboe
+ Improved rec.
0
+ Purchases
156 mmboe
Combined added
314 mmboe
− Divestitures
−16 mmboe
− Production
−531 mmboe
Combined used
−547 mmboe
± Conv. to developed
0
Net change
861 mmboe
Closing
6 052 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
4 024.5 mmboe
+ Ext. & disc.
332.83 mmboe
+ Revisions
−289.67 mmboe
+ Improved rec.
0
+ Purchases
1.17 mmboe
Combined added
44.33 mmboe
− Divestitures
−71.17 mmboe
− Production
−337.33 mmboe
Combined used
−408.5 mmboe
± Conv. to developed
0
Net change
452.83 mmboe
Closing
3 660.33 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 176 mmboe
+ Ext. & disc.
272 mmboe
+ Revisions
−110 mmboe
+ Improved rec.
0
+ Purchases
2 mmboe
Combined added
164 mmboe
− Divestitures
−5 mmboe
− Production
−99 mmboe
Combined used
−104 mmboe
± Conv. to developed
0
Net change
268 mmboe
Closing
1 236 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
ExxonMobil Worldwide Upstream (Portfolio)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
6 052 mmboe
+ Ext. & disc.
967 mmboe
+ Revisions
606 mmboe
+ Improved rec.
0
+ Purchases
877 mmboe
Combined added
2 450 mmboe
− Divestitures
−74 mmboe
− Production
−679 mmboe
Combined used
−753 mmboe
± Conv. to developed
0
Net change
3 203 mmboe
Closing
7 749 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 660.33 mmboe
+ Ext. & disc.
459 mmboe
+ Revisions
−74.33 mmboe
+ Improved rec.
0
+ Purchases
674 mmboe
Combined added
1 058.67 mmboe
− Divestitures
−33.83 mmboe
− Production
−367.83 mmboe
Combined used
−401.67 mmboe
± Conv. to developed
0
Net change
1 460.33 mmboe
Closing
4 317.33 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 236 mmboe
+ Ext. & disc.
489 mmboe
+ Revisions
−128 mmboe
+ Improved rec.
0
+ Purchases
730 mmboe
Combined added
1 091 mmboe
− Divestitures
−15 mmboe
− Production
−148 mmboe
Combined used
−163 mmboe
± Conv. to developed
0
Net change
1 254 mmboe
Closing
2 164 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
ExxonMobil Worldwide Upstream (Portfolio)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
7 749 mmboe
+ Ext. & disc.
988 mmboe
+ Revisions
−430 mmboe
+ Improved rec.
0
+ Purchases
38 mmboe
Combined added
596 mmboe
− Divestitures
−72 mmboe
− Production
−728 mmboe
Combined used
−800 mmboe
± Conv. to developed
0
Net change
1 396 mmboe
Closing
7 545 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
4 317.33 mmboe
+ Ext. & disc.
546.67 mmboe
+ Revisions
−185 mmboe
+ Improved rec.
0
+ Purchases
39 mmboe
Combined added
400.67 mmboe
− Divestitures
−48.33 mmboe
− Production
−390.67 mmboe
Combined used
−439 mmboe
± Conv. to developed
0
Net change
839.67 mmboe
Closing
4 279 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 164 mmboe
+ Ext. & disc.
513 mmboe
+ Revisions
−373 mmboe
+ Improved rec.
0
+ Purchases
41 mmboe
Combined added
181 mmboe
− Divestitures
−12 mmboe
− Production
−194 mmboe
Combined used
−206 mmboe
± Conv. to developed
0
Net change
387 mmboe
Closing
2 139 mmboe
Balance check
✓
2023
ExxonMobil Worldwide Upstream (Portfolio)
Oil
1P
Net
Sec
6 285 mmboe
460 mmboe
−302 mmboe
0
156 mmboe
314 mmboe
−16 mmboe
−531 mmboe
−547 mmboe
0
861 mmboe
6 052 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
1P
Net
Sec
4 024.5 mmboe
332.83 mmboe
−289.67 mmboe
0
1.17 mmboe
44.33 mmboe
−71.17 mmboe
−337.33 mmboe
−408.5 mmboe
0
452.83 mmboe
3 660.33 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
1P
Net
Sec
1 176 mmboe
272 mmboe
−110 mmboe
0
2 mmboe
164 mmboe
−5 mmboe
−99 mmboe
−104 mmboe
0
268 mmboe
1 236 mmboe
✓
2024
ExxonMobil Worldwide Upstream (Portfolio)
Oil
1P
Net
Sec
6 052 mmboe
967 mmboe
606 mmboe
0
877 mmboe
2 450 mmboe
−74 mmboe
−679 mmboe
−753 mmboe
0
3 203 mmboe
7 749 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
1P
Net
Sec
3 660.33 mmboe
459 mmboe
−74.33 mmboe
0
674 mmboe
1 058.67 mmboe
−33.83 mmboe
−367.83 mmboe
−401.67 mmboe
0
1 460.33 mmboe
4 317.33 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
1P
Net
Sec
1 236 mmboe
489 mmboe
−128 mmboe
0
730 mmboe
1 091 mmboe
−15 mmboe
−148 mmboe
−163 mmboe
0
1 254 mmboe
2 164 mmboe
✓
2025
ExxonMobil Worldwide Upstream (Portfolio)
Oil
1P
Net
Sec
7 749 mmboe
988 mmboe
−430 mmboe
0
38 mmboe
596 mmboe
−72 mmboe
−728 mmboe
−800 mmboe
0
1 396 mmboe
7 545 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
1P
Net
Sec
4 317.33 mmboe
546.67 mmboe
−185 mmboe
0
39 mmboe
400.67 mmboe
−48.33 mmboe
−390.67 mmboe
−439 mmboe
0
839.67 mmboe
4 279 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
1P
Net
Sec
2 164 mmboe
513 mmboe
−373 mmboe
0
41 mmboe
181 mmboe
−12 mmboe
−194 mmboe
−206 mmboe
0
387 mmboe
2 139 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | |||
|---|---|---|---|
| Oil · 1P · Net change (Δ %) | Natural gas · 1P · Net change (Δ %) | NGL · 1P · Net change (Δ %) | |
|
2023
|
861 mmboe (+14%)
|
452.83 mmboe (+11%)
|
268 mmboe (+23%)
|
|
2024
|
3 203 mmboe (+53%)
|
1 460.33 mmboe (+40%)
|
1 254 mmboe (+101%)
|
|
2025
|
1 396 mmboe (+18%)
|
839.67 mmboe (+19%)
|
387 mmboe (+18%)
|
2023
Oil · 1P · Net change (Δ %)
861 mmboe (+14%)
Natural gas · 1P · Net change (Δ %)
452.83 mmboe (+11%)
NGL · 1P · Net change (Δ %)
268 mmboe (+23%)
2024
Oil · 1P · Net change (Δ %)
3 203 mmboe (+53%)
Natural gas · 1P · Net change (Δ %)
1 460.33 mmboe (+40%)
NGL · 1P · Net change (Δ %)
1 254 mmboe (+101%)
2025
Oil · 1P · Net change (Δ %)
1 396 mmboe (+18%)
Natural gas · 1P · Net change (Δ %)
839.67 mmboe (+19%)
NGL · 1P · Net change (Δ %)
387 mmboe (+18%)
2023
861 mmboe (+14%)
452.83 mmboe (+11%)
268 mmboe (+23%)
2024
3 203 mmboe (+53%)
1 460.33 mmboe (+40%)
1 254 mmboe (+101%)
2025
1 396 mmboe (+18%)
839.67 mmboe (+19%)
387 mmboe (+18%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
ExxonMobil Refining & Chemical Portfolio
Portfolio · Operating
United States
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Company portfolio
Aggregation level:
Company portfolio
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
United States
Country:
United States
Facility kind:
-
Facility kind:
-
Licensed capacity:
4113
Licensed capacity:
4113
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Worldwide refining and chemical manufacturing rollup. ExxonMobil's share of refining capacity totaled 4,113 thousand barrels per day at year-end 2025 across the United States (1,967 kbd), Canada (434 kbd), Europe (853 kbd), Asia Pacific (659 kbd) and the Middle East (200 kbd), with worldwide chemical capacity of 13.1 Mt/yr ethylene, 12.5 Mt/yr polyethylene and 4.1 Mt/yr polypropylene.
Portfolio Aggregate · Processing facilities
As at 31 December 2025
| Commodity | Capacity |
|---|---|
|
Oil
|
4 113 mbbl/Per Day
Nameplate
|
Commodity
Capacity
Oil
4 113 mbbl/Per Day
Nameplate
Oil
4 113 mbbl/Per Day
Nameplate
Portfolio Aggregate · Processing facilities — Assumptions & Disclaimers
- Scope: company-wide processing / midstream rollups (refining, pipelines, fractionation, storage, LNG). They are split from the upstream Portfolio Aggregate so each table only shows columns it can populate.
- Capacity is the consolidated nameplate / contracted / licensed capacity from the project record, not period throughput. Production, reserves and production value are intentionally omitted — processing rollups carry no contained-volume × price economics in this model.
- When a Portfolio Aggregate row exists, individual facility rows are not summed into it — that would double-count.
- Nameplate / licensed capacity is an engineering maximum; sustained utilisation may be lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, fractionation spreads) are commodity-specific and may not be visible on this page.
Operating · 19 projects
Bacalhau
Asset
Brazil, Offshore Brazil
Oil Gas
Type
Operating
Status
🇧🇷 Brazil, Offshore Brazil
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Offshore
Extraction:
Offshore
Description
As at 31 December 2025
Deepwater development offshore Brazil. Bacalhau Phase 1 commenced operations in 2025 with the start-up of its floating production, storage and offloading (FPSO) vessel.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Gorgon-Jansz LNG
Asset · Operating
Australia, Western Australia
Oil Gas
Type
Operating
Status
🇦🇺 Australia, Western Australia
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
No
Operator:
No
Extraction:
Lng
Extraction:
Lng
Description
As at 31 December 2025
LNG project offshore Western Australia (Chevron-operated; ExxonMobil non-operating interest). Development activities progressed on the Jansz-Io Compression Project in 2025 and the Gorgon Stage 3 project was fully funded. ExxonMobil's Australian proved undeveloped gas reserves are associated with future compression for the Gorgon-Jansz project and have remained undeveloped five years or more due to infrastructure capacity constraints. Australia and Papua New Guinea together account for 22.5 Mt/yr of LNG capacity.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Upper Zakum
Asset · Operating
United Arab Emirates, Abu Dhabi
Oil Gas
Type
Operating
Status
🇦🇪 United Arab Emirates, Abu Dhabi
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
No
Operator:
No
Extraction:
Offshore
Extraction:
Offshore
Description
As at 31 December 2025
Producing offshore field in the United Arab Emirates under phased development. Ongoing activities continued in 2025 on the phased development of the field. Proved undeveloped reserves associated with an approved development plan and continued drilling investment have remained undeveloped for five years or more due to the time required to complete development of this very large project.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Kearl
Asset · Ownership 70.96%
Canada, Alberta, Athabasca Oil Sands
Bitumen
Oil Gas
Type
Operating
Status
🇨🇦 Canada, Alberta (Athabasca Oil Sands)
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
70.96
Ownership %:
70.96
Operator:
Yes
Operator:
Yes
Extraction:
Oil Sands Mining
Extraction:
Oil Sands Mining
Description
As at 31 December 2025
Open-pit oil sands mining joint venture ~40 miles north of Fort McMurray, Alberta, in the Athabasca oil sands deposit. Six oil sands leases covering ~49 thousand acres. Bitumen is extracted and processed through bitumen extraction and froth treatment trains; the bitumen-diluent blend is shipped to refineries and third parties. Imperial Oil Limited holds 70.96% and ExxonMobil Canada Properties 29.04% (Exxon Mobil Corporation holds 69.6% of Imperial Oil and 100% of ExxonMobil Canada Properties). 2025 average net production ~264 kbd.
Oil & Gas metrics
As at 31 December 2025
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Bitumen
|
96.36 mmboe/yr
5/5
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Bitumen
96.36 mmboe/yr
5/5
-
-
Bitumen
96.36 mmboe/yr
5/5
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
As at 31 December 2025
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
49k net acres
49k developed
|
-
|
-
|
-
|
-
|
-
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
49k net acres
49k developed
-
-
-
-
-
49k net acres
49k developed
-
-
-
-
-
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
PNG LNG
Asset · Ownership 33%
Papua New Guinea, Papua New Guinea
Oil Gas
Type
Operating
Status
🇵🇬 Papua New Guinea, Papua New Guinea
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
33
Ownership %:
33
Operator:
Yes
Operator:
Yes
Extraction:
Lng
Extraction:
Lng
Description
As at 31 December 2025
Integrated LNG project in Papua New Guinea (ExxonMobil 33% interest in Papua New Guinea Liquefied Natural Gas Global Company LDC). The Papua LNG growth project optimized its development plan in 2025 to enhance cost competitiveness. Australia and Papua New Guinea together account for 22.5 Mt/yr of LNG capacity.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Coral South FLNG
Asset · Ownership 25%
Mozambique, Offshore Mozambique (Area 4)
Oil Gas
Type
Operating
Status
🇲🇿 Mozambique, Offshore Mozambique (Area 4)
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
25
Ownership %:
25
Operator:
No
Operator:
No
Extraction:
Lng
Extraction:
Lng
Description
As at 31 December 2025
Floating LNG development offshore Mozambique in which ExxonMobil continued to participate during 2025 (25% interest in Coral FLNG S.A.). Part of the Corporation's Mozambique LNG expansion portfolio alongside the Rovuma LNG project.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Syncrude
Asset · Ownership 25%
Canada, Alberta, Athabasca Oil Sands
Synthetic crude
Oil Gas
Type
Operating
Status
🇨🇦 Canada, Alberta (Athabasca Oil Sands)
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
25
Ownership %:
25
Operator:
No
Operator:
No
Operator name:
Syncrude joint venture (Imperial Oil 25% interest)
Operator name:
Syncrude joint venture (Imperial Oil 25% interest)
Extraction:
Oil Sands Mining
Extraction:
Oil Sands Mining
Description
As at 31 December 2025
Joint venture recovering shallow oil sands deposits by open-pit mining and upgrading crude bitumen into high-quality 32° API light sweet synthetic crude oil, in the Athabasca oil sands deposit. Imperial Oil Limited owns a 25% interest in the JV (Exxon Mobil Corporation holds 69.6% of Imperial Oil). 2025 share of net synthetic crude production ~68 kbd; share of net acreage ~55 thousand acres.
Oil & Gas metrics
As at 31 December 2025
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Synthetic crude
|
24.82 mmboe/yr
4/5
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Synthetic crude
24.82 mmboe/yr
4/5
-
-
Synthetic crude
24.82 mmboe/yr
4/5
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
As at 31 December 2025
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
55k net acres
55k developed
|
-
|
-
|
-
|
-
|
-
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
55k net acres
55k developed
-
-
-
-
-
55k net acres
55k developed
-
-
-
-
-
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Tengiz / Korolev (Tengizchevroil)
Asset · Ownership 25%
Kazakhstan, Atyrau
Oil Gas
Type
Operating
Status
🇰🇿 Kazakhstan, Atyrau
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
25
Ownership %:
25
Operator:
No
Operator:
No
Operator name:
Tengizchevroil LLP
Operator name:
Tengizchevroil LLP
Extraction:
Conventional Oil Gas
Extraction:
Conventional Oil Gas
Description
As at 31 December 2025
Onshore Tengiz and Korolev oil fields in western Kazakhstan, operated by Tengizchevroil LLP (ExxonMobil 25% interest). The Tengiz Expansion Project was completed in 2025 and production ramped up to nameplate capacity. Crude exports primarily via the Caspian Pipeline Consortium (ExxonMobil 7.5% interest) to Black Sea loading facilities.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Kashagan
Asset · Ownership 16.8%
Kazakhstan, Caspian Sea (Atyrau)
Oil Gas
Type
Operating
Status
🇰🇿 Kazakhstan, Caspian Sea (Atyrau)
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
16.8
Ownership %:
16.8
Operator:
No
Operator:
No
Extraction:
Offshore
Extraction:
Offshore
Description
As at 31 December 2025
Offshore Caspian field in Kazakhstan in which the Corporation holds a 16.8% working interest. Oil production is exported primarily through the Caspian Pipeline Consortium (CPC) to tanker-loading facilities on the Russian Black Sea coast.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
United States Upstream
Play
United States, United States
Oil
5/5
Natural gas
5/5
Oil Gas
Type
Operating
Status
🇺🇸 United States, United States
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Unconventional Shale
Extraction:
Unconventional Shale
Producing wells (net):
17593
Producing wells (net):
17593
Description
As at 31 December 2025
Consolidated U.S. upstream operations — onshore and offshore lower 48 (led by the Permian Basin of West Texas and New Mexico) and Alaska. 2025 development focused on liquids-rich onshore opportunities, bringing total U.S. net production to 2.1 million oil-equivalent barrels per day. Includes producing assets from the May 2024 Pioneer Natural Resources acquisition. Equity-company interests (YE2025 proved developed: 5 mmbbl crude, 3 mmbbl NGL, 48 bcf gas) are excluded from this consolidated row.
Oil & Gas metrics
Multiple effective dates · 1P
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Oil
|
366.82 mmboe/yr
5/5
|
3 110 mmboe 1P
5/5
|
reserves 8.5 yrs
|
|
Natural gas
|
203.55 mmboe/yr
5/5
|
2 797.83 mmboe 1P
5/5
|
reserves 13.7 yrs
|
|
NGL
|
187.61 mmboe/yr
5/5
|
2 063 mmboe 1P
5/5
|
reserves 11 yrs
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
366.82 mmboe/yr
5/5
3 110 mmboe 1P
5/5
reserves 8.5 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
203.55 mmboe/yr
5/5
2 797.83 mmboe 1P
5/5
reserves 13.7 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
187.61 mmboe/yr
5/5
2 063 mmboe 1P
5/5
reserves 11 yrs
Oil
366.82 mmboe/yr
5/5
3 110 mmboe 1P
5/5
reserves 8.5 yrs
Natural gas
203.55 mmboe/yr
5/5
2 797.83 mmboe 1P
5/5
reserves 13.7 yrs
NGL
187.61 mmboe/yr
5/5
2 063 mmboe 1P
5/5
reserves 11 yrs
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
Multiple effective dates
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
7.17M net acres · 71% developed
5.08M developed · 2.09M undeveloped
|
17.6k net producing
|
-
|
-
|
698 drilled
FY 2025
|
492 WIP
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
7.17M net acres · 71% developed
5.08M developed · 2.09M undeveloped
17.6k net producing
-
-
698 drilled
FY 2025
492 WIP
7.17M net acres · 71% developed
5.08M developed · 2.09M undeveloped
17.6k net producing
-
-
698 drilled
FY 2025
492 WIP
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Reserves & resources — detail
As at 31 December 2025
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 204 mmboe
|
355 mmboe
|
−398 mmboe
|
0
|
156 mmboe
|
113 mmboe
|
−12 mmboe
|
−203 mmboe
|
−215 mmboe
|
0
|
328 mmboe
|
2 102 mmboe
|
✓
|
|
United States Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
2 274.17 mmboe
|
321.67 mmboe
|
−324.17 mmboe
|
0
|
1.17 mmboe
|
−1.33 mmboe
|
−69.5 mmboe
|
−159.5 mmboe
|
−229 mmboe
|
0
|
227.67 mmboe
|
2 043.83 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 102 mmboe
|
804 mmboe
|
−176 mmboe
|
0
|
877 mmboe
|
1 505 mmboe
|
−18 mmboe
|
−316 mmboe
|
−334 mmboe
|
0
|
1 839 mmboe
|
3 273 mmboe
|
✓
|
|
United States Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
2 043.83 mmboe
|
447.17 mmboe
|
−151.83 mmboe
|
0
|
674 mmboe
|
969.33 mmboe
|
−13.83 mmboe
|
−192.17 mmboe
|
−206 mmboe
|
0
|
1 175.33 mmboe
|
2 807.17 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
3 273 mmboe
|
890 mmboe
|
−652 mmboe
|
0
|
38 mmboe
|
276 mmboe
|
−72 mmboe
|
−367 mmboe
|
−439 mmboe
|
0
|
715 mmboe
|
3 110 mmboe
|
✓
|
|
United States Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
2 807.17 mmboe
|
461.5 mmboe
|
−247 mmboe
|
0
|
39 mmboe
|
253.5 mmboe
|
−41.33 mmboe
|
−221.5 mmboe
|
−262.83 mmboe
|
0
|
516.33 mmboe
|
2 797.83 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
United States Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 204 mmboe
+ Ext. & disc.
355 mmboe
+ Revisions
−398 mmboe
+ Improved rec.
0
+ Purchases
156 mmboe
Combined added
113 mmboe
− Divestitures
−12 mmboe
− Production
−203 mmboe
Combined used
−215 mmboe
± Conv. to developed
0
Net change
328 mmboe
Closing
2 102 mmboe
Balance check
✓
United States Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 274.17 mmboe
+ Ext. & disc.
321.67 mmboe
+ Revisions
−324.17 mmboe
+ Improved rec.
0
+ Purchases
1.17 mmboe
Combined added
−1.33 mmboe
− Divestitures
−69.5 mmboe
− Production
−159.5 mmboe
Combined used
−229 mmboe
± Conv. to developed
0
Net change
227.67 mmboe
Closing
2 043.83 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
United States Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 102 mmboe
+ Ext. & disc.
804 mmboe
+ Revisions
−176 mmboe
+ Improved rec.
0
+ Purchases
877 mmboe
Combined added
1 505 mmboe
− Divestitures
−18 mmboe
− Production
−316 mmboe
Combined used
−334 mmboe
± Conv. to developed
0
Net change
1 839 mmboe
Closing
3 273 mmboe
Balance check
✓
United States Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 043.83 mmboe
+ Ext. & disc.
447.17 mmboe
+ Revisions
−151.83 mmboe
+ Improved rec.
0
+ Purchases
674 mmboe
Combined added
969.33 mmboe
− Divestitures
−13.83 mmboe
− Production
−192.17 mmboe
Combined used
−206 mmboe
± Conv. to developed
0
Net change
1 175.33 mmboe
Closing
2 807.17 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
United States Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 273 mmboe
+ Ext. & disc.
890 mmboe
+ Revisions
−652 mmboe
+ Improved rec.
0
+ Purchases
38 mmboe
Combined added
276 mmboe
− Divestitures
−72 mmboe
− Production
−367 mmboe
Combined used
−439 mmboe
± Conv. to developed
0
Net change
715 mmboe
Closing
3 110 mmboe
Balance check
✓
United States Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 807.17 mmboe
+ Ext. & disc.
461.5 mmboe
+ Revisions
−247 mmboe
+ Improved rec.
0
+ Purchases
39 mmboe
Combined added
253.5 mmboe
− Divestitures
−41.33 mmboe
− Production
−221.5 mmboe
Combined used
−262.83 mmboe
± Conv. to developed
0
Net change
516.33 mmboe
Closing
2 797.83 mmboe
Balance check
✓
2023
United States Upstream (Play)
Oil
1P
Net
Sec
2 204 mmboe
355 mmboe
−398 mmboe
0
156 mmboe
113 mmboe
−12 mmboe
−203 mmboe
−215 mmboe
0
328 mmboe
2 102 mmboe
✓
United States Upstream (Play)
Natural gas
1P
Net
Sec
2 274.17 mmboe
321.67 mmboe
−324.17 mmboe
0
1.17 mmboe
−1.33 mmboe
−69.5 mmboe
−159.5 mmboe
−229 mmboe
0
227.67 mmboe
2 043.83 mmboe
✓
2024
United States Upstream (Play)
Oil
1P
Net
Sec
2 102 mmboe
804 mmboe
−176 mmboe
0
877 mmboe
1 505 mmboe
−18 mmboe
−316 mmboe
−334 mmboe
0
1 839 mmboe
3 273 mmboe
✓
United States Upstream (Play)
Natural gas
1P
Net
Sec
2 043.83 mmboe
447.17 mmboe
−151.83 mmboe
0
674 mmboe
969.33 mmboe
−13.83 mmboe
−192.17 mmboe
−206 mmboe
0
1 175.33 mmboe
2 807.17 mmboe
✓
2025
United States Upstream (Play)
Oil
1P
Net
Sec
3 273 mmboe
890 mmboe
−652 mmboe
0
38 mmboe
276 mmboe
−72 mmboe
−367 mmboe
−439 mmboe
0
715 mmboe
3 110 mmboe
✓
United States Upstream (Play)
Natural gas
1P
Net
Sec
2 807.17 mmboe
461.5 mmboe
−247 mmboe
0
39 mmboe
253.5 mmboe
−41.33 mmboe
−221.5 mmboe
−262.83 mmboe
0
516.33 mmboe
2 797.83 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | ||
|---|---|---|
| Oil · 1P · Net change (Δ %) | Natural gas · 1P · Net change (Δ %) | |
|
2023
|
328 mmboe (+15%)
|
227.67 mmboe (+10%)
|
|
2024
|
1 839 mmboe (+87%)
|
1 175.33 mmboe (+58%)
|
|
2025
|
715 mmboe (+22%)
|
516.33 mmboe (+18%)
|
2023
Oil · 1P · Net change (Δ %)
328 mmboe (+15%)
Natural gas · 1P · Net change (Δ %)
227.67 mmboe (+10%)
2024
Oil · 1P · Net change (Δ %)
1 839 mmboe (+87%)
Natural gas · 1P · Net change (Δ %)
1 175.33 mmboe (+58%)
2025
Oil · 1P · Net change (Δ %)
715 mmboe (+22%)
Natural gas · 1P · Net change (Δ %)
516.33 mmboe (+18%)
2023
328 mmboe (+15%)
227.67 mmboe (+10%)
2024
1 839 mmboe (+87%)
1 175.33 mmboe (+58%)
2025
715 mmboe (+22%)
516.33 mmboe (+18%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
Australia/Oceania Upstream
Play
Australia, Australia and Oceania
Natural gas
4/5
Oil
3/5
Oil Gas
Type
Operating
Status
🇦🇺 Australia, Australia and Oceania
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Offshore
Extraction:
Offshore
Producing wells (net):
46
Producing wells (net):
46
Description
As at 31 December 2025
Consolidated Australia/Oceania upstream operations — Gorgon-Jansz LNG (Jansz-Io Compression progressing; Gorgon Stage 3 fully funded in 2025), Bass Strait and PNG. Australia and Papua New Guinea account for 22.5 Mt/yr of LNG capacity. Material proved undeveloped gas (2,653 bcf) is associated with future compression for the Gorgon-Jansz LNG project (undeveloped >5 years due to infrastructure capacity constraints).
Oil & Gas metrics
Multiple effective dates · 1P
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Natural gas
|
78.05 mmboe/yr
5/5
|
951.67 mmboe 1P
4/5
|
reserves 12.2 yrs
|
|
Oil
|
6.57 mmboe/yr
3/5
|
60 mmboe 1P
3/5
|
reserves 9.1 yrs
|
|
NGL
|
2.56 mmboe/yr
4/5
|
8 mmboe 1P
2/5
|
reserves 3.1 yrs
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
78.05 mmboe/yr
5/5
951.67 mmboe 1P
4/5
reserves 12.2 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
6.57 mmboe/yr
3/5
60 mmboe 1P
3/5
reserves 9.1 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
2.56 mmboe/yr
4/5
8 mmboe 1P
2/5
reserves 3.1 yrs
Natural gas
78.05 mmboe/yr
5/5
951.67 mmboe 1P
4/5
reserves 12.2 yrs
Oil
6.57 mmboe/yr
3/5
60 mmboe 1P
3/5
reserves 9.1 yrs
NGL
2.56 mmboe/yr
4/5
8 mmboe 1P
2/5
reserves 3.1 yrs
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
Multiple effective dates
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
2.70M net acres · 39% developed
1.04M developed · 1.66M undeveloped
|
46 net producing
|
-
|
-
|
1 drilled
FY 2025
|
1 WIP
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
2.70M net acres · 39% developed
1.04M developed · 1.66M undeveloped
46 net producing
-
-
1 drilled
FY 2025
1 WIP
2.70M net acres · 39% developed
1.04M developed · 1.66M undeveloped
46 net producing
-
-
1 drilled
FY 2025
1 WIP
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Reserves & resources — detail
As at 31 December 2025
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Australia/Oceania Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
1 001.33 mmboe
|
0
|
56.5 mmboe
|
0
|
0
|
56.5 mmboe
|
0
|
−81.5 mmboe
|
−81.5 mmboe
|
0
|
138 mmboe
|
976.33 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
66 mmboe
|
0
|
3 mmboe
|
0
|
0
|
3 mmboe
|
0
|
−8 mmboe
|
−8 mmboe
|
0
|
11 mmboe
|
61 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Australia/Oceania Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
976.33 mmboe
|
0.17 mmboe
|
16.17 mmboe
|
0
|
0
|
16.33 mmboe
|
0
|
−79.5 mmboe
|
−79.5 mmboe
|
0
|
95.83 mmboe
|
913.17 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
61 mmboe
|
0
|
1 mmboe
|
0
|
0
|
1 mmboe
|
0
|
−7 mmboe
|
−7 mmboe
|
0
|
8 mmboe
|
55 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Australia/Oceania Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
913.17 mmboe
|
80.83 mmboe
|
38 mmboe
|
0
|
0
|
118.83 mmboe
|
0
|
−80.33 mmboe
|
−80.33 mmboe
|
0
|
199.17 mmboe
|
951.67 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
55 mmboe
|
6 mmboe
|
6 mmboe
|
0
|
0
|
12 mmboe
|
0
|
−7 mmboe
|
−7 mmboe
|
0
|
19 mmboe
|
60 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Australia/Oceania Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 001.33 mmboe
+ Ext. & disc.
0
+ Revisions
56.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
56.5 mmboe
− Divestitures
0
− Production
−81.5 mmboe
Combined used
−81.5 mmboe
± Conv. to developed
0
Net change
138 mmboe
Closing
976.33 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
66 mmboe
+ Ext. & disc.
0
+ Revisions
3 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
3 mmboe
− Divestitures
0
− Production
−8 mmboe
Combined used
−8 mmboe
± Conv. to developed
0
Net change
11 mmboe
Closing
61 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Australia/Oceania Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
976.33 mmboe
+ Ext. & disc.
0.17 mmboe
+ Revisions
16.17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
16.33 mmboe
− Divestitures
0
− Production
−79.5 mmboe
Combined used
−79.5 mmboe
± Conv. to developed
0
Net change
95.83 mmboe
Closing
913.17 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
61 mmboe
+ Ext. & disc.
0
+ Revisions
1 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
1 mmboe
− Divestitures
0
− Production
−7 mmboe
Combined used
−7 mmboe
± Conv. to developed
0
Net change
8 mmboe
Closing
55 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Australia/Oceania Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
913.17 mmboe
+ Ext. & disc.
80.83 mmboe
+ Revisions
38 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
118.83 mmboe
− Divestitures
0
− Production
−80.33 mmboe
Combined used
−80.33 mmboe
± Conv. to developed
0
Net change
199.17 mmboe
Closing
951.67 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
55 mmboe
+ Ext. & disc.
6 mmboe
+ Revisions
6 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
12 mmboe
− Divestitures
0
− Production
−7 mmboe
Combined used
−7 mmboe
± Conv. to developed
0
Net change
19 mmboe
Closing
60 mmboe
Balance check
✓
2023
Australia/Oceania Upstream (Play)
Natural gas
1P
Net
Sec
1 001.33 mmboe
0
56.5 mmboe
0
0
56.5 mmboe
0
−81.5 mmboe
−81.5 mmboe
0
138 mmboe
976.33 mmboe
✓
Australia/Oceania Upstream (Play)
Oil
1P
Net
Sec
66 mmboe
0
3 mmboe
0
0
3 mmboe
0
−8 mmboe
−8 mmboe
0
11 mmboe
61 mmboe
✓
2024
Australia/Oceania Upstream (Play)
Natural gas
1P
Net
Sec
976.33 mmboe
0.17 mmboe
16.17 mmboe
0
0
16.33 mmboe
0
−79.5 mmboe
−79.5 mmboe
0
95.83 mmboe
913.17 mmboe
✓
Australia/Oceania Upstream (Play)
Oil
1P
Net
Sec
61 mmboe
0
1 mmboe
0
0
1 mmboe
0
−7 mmboe
−7 mmboe
0
8 mmboe
55 mmboe
✓
2025
Australia/Oceania Upstream (Play)
Natural gas
1P
Net
Sec
913.17 mmboe
80.83 mmboe
38 mmboe
0
0
118.83 mmboe
0
−80.33 mmboe
−80.33 mmboe
0
199.17 mmboe
951.67 mmboe
✓
Australia/Oceania Upstream (Play)
Oil
1P
Net
Sec
55 mmboe
6 mmboe
6 mmboe
0
0
12 mmboe
0
−7 mmboe
−7 mmboe
0
19 mmboe
60 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | ||
|---|---|---|
| Natural gas · 1P · Net change (Δ %) | Oil · 1P · Net change (Δ %) | |
|
2023
|
138 mmboe (+14%)
|
11 mmboe (+17%)
|
|
2024
|
95.83 mmboe (+10%)
|
8 mmboe (+13%)
|
|
2025
|
199.17 mmboe (+22%)
|
19 mmboe (+35%)
|
2023
Natural gas · 1P · Net change (Δ %)
138 mmboe (+14%)
Oil · 1P · Net change (Δ %)
11 mmboe (+17%)
2024
Natural gas · 1P · Net change (Δ %)
95.83 mmboe (+10%)
Oil · 1P · Net change (Δ %)
8 mmboe (+13%)
2025
Natural gas · 1P · Net change (Δ %)
199.17 mmboe (+22%)
Oil · 1P · Net change (Δ %)
19 mmboe (+35%)
2023
138 mmboe (+14%)
11 mmboe (+17%)
2024
95.83 mmboe (+10%)
8 mmboe (+13%)
2025
199.17 mmboe (+22%)
19 mmboe (+35%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
Asia Upstream
Play
United Arab Emirates, Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
Oil
5/5
Natural gas
4/5
Oil Gas
Type
Operating
Status
🇦🇪 United Arab Emirates, Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Conventional Oil Gas
Extraction:
Conventional Oil Gas
Producing wells (net):
327
Producing wells (net):
327
Description
As at 31 December 2025
Consolidated Asia upstream operations — UAE (Upper Zakum phased development), Qatar (45.7 Mtpa gross LNG capacity participation; North Field East and North Field Production Sustainment), Kazakhstan (Tengiz and Kashagan partnerships; Tengiz Expansion Project completed and ramped to nameplate in 2025), Iraq, Malaysia, Indonesia; exited Thailand in 2025. Equity companies (incl. TCO 25%, QatarEnergy LNG ventures, Barzan) hold large additional reserves: YE2025 proved developed 462 mmbbl crude, 134 mmbbl NGL, 4,782 bcf gas; undeveloped 163 mmbbl crude, 161 mmbbl NGL, 4,866 bcf gas.
Oil & Gas metrics
Multiple effective dates · 1P
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Oil
|
162.43 mmboe/yr
5/5
|
2 960 mmboe 1P
5/5
|
reserves 18.2 yrs
|
|
Natural gas
|
58.89 mmboe/yr
5/5
|
366.5 mmboe 1P
4/5
|
reserves 6.2 yrs
|
|
NGL
|
10.22 mmboe/yr
5/5
|
67 mmboe 1P
4/5
|
reserves 6.6 yrs
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
162.43 mmboe/yr
5/5
2 960 mmboe 1P
5/5
reserves 18.2 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
58.89 mmboe/yr
5/5
366.5 mmboe 1P
4/5
reserves 6.2 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
10.22 mmboe/yr
5/5
67 mmboe 1P
4/5
reserves 6.6 yrs
Oil
162.43 mmboe/yr
5/5
2 960 mmboe 1P
5/5
reserves 18.2 yrs
Natural gas
58.89 mmboe/yr
5/5
366.5 mmboe 1P
4/5
reserves 6.2 yrs
NGL
10.22 mmboe/yr
5/5
67 mmboe 1P
4/5
reserves 6.6 yrs
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
Multiple effective dates
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
637k net acres · 66% developed
422k developed · 215k undeveloped
|
327 net producing
|
-
|
-
|
5 drilled
FY 2025
|
2 WIP
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
637k net acres · 66% developed
422k developed · 215k undeveloped
327 net producing
-
-
5 drilled
FY 2025
2 WIP
637k net acres · 66% developed
422k developed · 215k undeveloped
327 net producing
-
-
5 drilled
FY 2025
2 WIP
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Reserves & resources — detail
As at 31 December 2025
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asia Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 794 mmboe
|
0
|
30 mmboe
|
0
|
0
|
30 mmboe
|
−4 mmboe
|
−153 mmboe
|
−157 mmboe
|
0
|
187 mmboe
|
2 667 mmboe
|
✓
|
|
Asia Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
510.17 mmboe
|
0
|
20.17 mmboe
|
0
|
0
|
20.17 mmboe
|
−1.5 mmboe
|
−63.17 mmboe
|
−64.67 mmboe
|
0
|
84.83 mmboe
|
465.67 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asia Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 667 mmboe
|
0
|
603 mmboe
|
0
|
0
|
603 mmboe
|
−7 mmboe
|
−154 mmboe
|
−161 mmboe
|
0
|
764 mmboe
|
3 109 mmboe
|
✓
|
|
Asia Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
465.67 mmboe
|
0
|
20.67 mmboe
|
0
|
0
|
20.67 mmboe
|
−0.83 mmboe
|
−62.17 mmboe
|
−63 mmboe
|
0
|
83.67 mmboe
|
423.33 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asia Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
3 109 mmboe
|
0
|
13 mmboe
|
0
|
0
|
13 mmboe
|
0
|
−162 mmboe
|
−162 mmboe
|
0
|
175 mmboe
|
2 960 mmboe
|
✓
|
|
Asia Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
423.33 mmboe
|
0
|
11.33 mmboe
|
0
|
0
|
11.33 mmboe
|
−2.33 mmboe
|
−65.83 mmboe
|
−68.17 mmboe
|
0
|
79.5 mmboe
|
366.5 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Asia Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 794 mmboe
+ Ext. & disc.
0
+ Revisions
30 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
30 mmboe
− Divestitures
−4 mmboe
− Production
−153 mmboe
Combined used
−157 mmboe
± Conv. to developed
0
Net change
187 mmboe
Closing
2 667 mmboe
Balance check
✓
Asia Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
510.17 mmboe
+ Ext. & disc.
0
+ Revisions
20.17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
20.17 mmboe
− Divestitures
−1.5 mmboe
− Production
−63.17 mmboe
Combined used
−64.67 mmboe
± Conv. to developed
0
Net change
84.83 mmboe
Closing
465.67 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Asia Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 667 mmboe
+ Ext. & disc.
0
+ Revisions
603 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
603 mmboe
− Divestitures
−7 mmboe
− Production
−154 mmboe
Combined used
−161 mmboe
± Conv. to developed
0
Net change
764 mmboe
Closing
3 109 mmboe
Balance check
✓
Asia Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
465.67 mmboe
+ Ext. & disc.
0
+ Revisions
20.67 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
20.67 mmboe
− Divestitures
−0.83 mmboe
− Production
−62.17 mmboe
Combined used
−63 mmboe
± Conv. to developed
0
Net change
83.67 mmboe
Closing
423.33 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Asia Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 109 mmboe
+ Ext. & disc.
0
+ Revisions
13 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
13 mmboe
− Divestitures
0
− Production
−162 mmboe
Combined used
−162 mmboe
± Conv. to developed
0
Net change
175 mmboe
Closing
2 960 mmboe
Balance check
✓
Asia Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
423.33 mmboe
+ Ext. & disc.
0
+ Revisions
11.33 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
11.33 mmboe
− Divestitures
−2.33 mmboe
− Production
−65.83 mmboe
Combined used
−68.17 mmboe
± Conv. to developed
0
Net change
79.5 mmboe
Closing
366.5 mmboe
Balance check
✓
2023
Asia Upstream (Play)
Oil
1P
Net
Sec
2 794 mmboe
0
30 mmboe
0
0
30 mmboe
−4 mmboe
−153 mmboe
−157 mmboe
0
187 mmboe
2 667 mmboe
✓
Asia Upstream (Play)
Natural gas
1P
Net
Sec
510.17 mmboe
0
20.17 mmboe
0
0
20.17 mmboe
−1.5 mmboe
−63.17 mmboe
−64.67 mmboe
0
84.83 mmboe
465.67 mmboe
✓
2024
Asia Upstream (Play)
Oil
1P
Net
Sec
2 667 mmboe
0
603 mmboe
0
0
603 mmboe
−7 mmboe
−154 mmboe
−161 mmboe
0
764 mmboe
3 109 mmboe
✓
Asia Upstream (Play)
Natural gas
1P
Net
Sec
465.67 mmboe
0
20.67 mmboe
0
0
20.67 mmboe
−0.83 mmboe
−62.17 mmboe
−63 mmboe
0
83.67 mmboe
423.33 mmboe
✓
2025
Asia Upstream (Play)
Oil
1P
Net
Sec
3 109 mmboe
0
13 mmboe
0
0
13 mmboe
0
−162 mmboe
−162 mmboe
0
175 mmboe
2 960 mmboe
✓
Asia Upstream (Play)
Natural gas
1P
Net
Sec
423.33 mmboe
0
11.33 mmboe
0
0
11.33 mmboe
−2.33 mmboe
−65.83 mmboe
−68.17 mmboe
0
79.5 mmboe
366.5 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | ||
|---|---|---|
| Oil · 1P · Net change (Δ %) | Natural gas · 1P · Net change (Δ %) | |
|
2023
|
187 mmboe (+7%)
|
84.83 mmboe (+17%)
|
|
2024
|
764 mmboe (+29%)
|
83.67 mmboe (+18%)
|
|
2025
|
175 mmboe (+6%)
|
79.5 mmboe (+19%)
|
2023
Oil · 1P · Net change (Δ %)
187 mmboe (+7%)
Natural gas · 1P · Net change (Δ %)
84.83 mmboe (+17%)
2024
Oil · 1P · Net change (Δ %)
764 mmboe (+29%)
Natural gas · 1P · Net change (Δ %)
83.67 mmboe (+18%)
2025
Oil · 1P · Net change (Δ %)
175 mmboe (+6%)
Natural gas · 1P · Net change (Δ %)
79.5 mmboe (+19%)
2023
187 mmboe (+7%)
84.83 mmboe (+17%)
2024
764 mmboe (+29%)
83.67 mmboe (+18%)
2025
175 mmboe (+6%)
79.5 mmboe (+19%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
Canada/Other Americas Upstream
Play
Canada, Canada and Other Americas
Oil
5/5
Bitumen
5/5
Oil Gas
Type
Operating
Status
🇨🇦 Canada, Canada and Other Americas
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Oil Sands Mining
Extraction:
Oil Sands Mining
Producing wells (net):
5050
Producing wells (net):
5050
Description
As at 31 December 2025
Consolidated Canada/Other Americas upstream operations — Canada onshore Alberta (Kearl and Syncrude oil sands mining, in-situ bitumen) and offshore Newfoundland and Labrador, plus Guyana (Stabroek block) and Brazil (Bacalhau start-up). Canada contributed 519 koebd net in 2025; Other Americas crude production was 320 kbd in 2025 (285 kbd 2024; 178 kbd 2023). Other Americas holds proved developed reserves of 486 mmbbl crude and 228 bcf gas, and proved undeveloped reserves of 587 mmbbl crude and 162 bcf gas at YE2025.
Oil & Gas metrics
Multiple effective dates · 1P
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Oil
|
139.06 mmboe/yr
5/5
|
1 195 mmboe 1P
5/5
|
reserves 8.6 yrs
|
|
Bitumen
|
140.53 mmboe/yr
5/5
|
2 330 mmboe 1P
5/5
|
reserves 16.6 yrs
|
|
Synthetic crude
|
24.82 mmboe/yr
4/5
|
288 mmboe 1P
4/5
|
reserves 11.6 yrs
|
|
Natural gas
|
1.64 mmboe/yr
2/5
|
87.83 mmboe 1P
3/5
|
reserves 25+ yrs
|
|
NGL
|
0.36 mmboe/yr
2/5
|
1 mmboe 1P
1/5
|
reserves 2.7 yrs
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
139.06 mmboe/yr
5/5
1 195 mmboe 1P
5/5
reserves 8.6 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Bitumen
140.53 mmboe/yr
5/5
2 330 mmboe 1P
5/5
reserves 16.6 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Synthetic crude
24.82 mmboe/yr
4/5
288 mmboe 1P
4/5
reserves 11.6 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
1.64 mmboe/yr
2/5
87.83 mmboe 1P
3/5
reserves 25+ yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
0.36 mmboe/yr
2/5
1 mmboe 1P
1/5
reserves 2.7 yrs
Oil
139.06 mmboe/yr
5/5
1 195 mmboe 1P
5/5
reserves 8.6 yrs
Bitumen
140.53 mmboe/yr
5/5
2 330 mmboe 1P
5/5
reserves 16.6 yrs
Synthetic crude
24.82 mmboe/yr
4/5
288 mmboe 1P
4/5
reserves 11.6 yrs
Natural gas
1.64 mmboe/yr
2/5
87.83 mmboe 1P
3/5
reserves 25+ yrs
NGL
0.36 mmboe/yr
2/5
1 mmboe 1P
1/5
reserves 2.7 yrs
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
Multiple effective dates
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
12.06M net acres · 11% developed
1.30M developed · 10.76M undeveloped
|
5 050 net producing
|
-
|
-
|
14 drilled
FY 2025
|
20 WIP
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
12.06M net acres · 11% developed
1.30M developed · 10.76M undeveloped
5 050 net producing
-
-
14 drilled
FY 2025
20 WIP
12.06M net acres · 11% developed
1.30M developed · 10.76M undeveloped
5 050 net producing
-
-
14 drilled
FY 2025
20 WIP
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Reserves & resources — detail
As at 31 December 2025
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Canada/Other Americas Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
945 mmboe
|
105 mmboe
|
32 mmboe
|
0
|
0
|
137 mmboe
|
0
|
−88 mmboe
|
−88 mmboe
|
0
|
225 mmboe
|
994 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Bitumen
|
1P
|
Net
|
Sec
|
2 420 mmboe
|
0
|
123 mmboe
|
0
|
0
|
123 mmboe
|
0
|
−129 mmboe
|
−129 mmboe
|
0
|
252 mmboe
|
2 414 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Synthetic crude
|
1P
|
Net
|
Sec
|
353 mmboe
|
0
|
26 mmboe
|
0
|
0
|
26 mmboe
|
0
|
−25 mmboe
|
−25 mmboe
|
0
|
51 mmboe
|
354 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
118 mmboe
|
11.17 mmboe
|
−33.5 mmboe
|
0
|
0
|
−22.33 mmboe
|
−0.17 mmboe
|
−8.83 mmboe
|
−9 mmboe
|
0
|
−13.33 mmboe
|
86.67 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Canada/Other Americas Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
994 mmboe
|
138 mmboe
|
116 mmboe
|
0
|
0
|
254 mmboe
|
−4 mmboe
|
−126 mmboe
|
−130 mmboe
|
0
|
384 mmboe
|
1 118 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Bitumen
|
1P
|
Net
|
Sec
|
2 414 mmboe
|
0
|
152 mmboe
|
0
|
0
|
152 mmboe
|
0
|
−137 mmboe
|
−137 mmboe
|
0
|
289 mmboe
|
2 429 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Synthetic crude
|
1P
|
Net
|
Sec
|
354 mmboe
|
0
|
−35 mmboe
|
0
|
0
|
−35 mmboe
|
0
|
−23 mmboe
|
−23 mmboe
|
0
|
−12 mmboe
|
296 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
86.67 mmboe
|
11.33 mmboe
|
3.67 mmboe
|
0
|
0
|
15 mmboe
|
−1.67 mmboe
|
−9.83 mmboe
|
−11.5 mmboe
|
0
|
26.5 mmboe
|
90.17 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Canada/Other Americas Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
1 118 mmboe
|
92 mmboe
|
124 mmboe
|
0
|
0
|
216 mmboe
|
0
|
−139 mmboe
|
−139 mmboe
|
0
|
355 mmboe
|
1 195 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Bitumen
|
1P
|
Net
|
Sec
|
2 429 mmboe
|
0
|
42 mmboe
|
0
|
0
|
42 mmboe
|
0
|
−141 mmboe
|
−141 mmboe
|
0
|
183 mmboe
|
2 330 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Synthetic crude
|
1P
|
Net
|
Sec
|
296 mmboe
|
0
|
17 mmboe
|
0
|
0
|
17 mmboe
|
0
|
−25 mmboe
|
−25 mmboe
|
0
|
42 mmboe
|
288 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
90.17 mmboe
|
4.33 mmboe
|
3.5 mmboe
|
0
|
0
|
7.83 mmboe
|
−4.67 mmboe
|
−5.5 mmboe
|
−10.17 mmboe
|
0
|
18 mmboe
|
87.83 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Canada/Other Americas Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
945 mmboe
+ Ext. & disc.
105 mmboe
+ Revisions
32 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
137 mmboe
− Divestitures
0
− Production
−88 mmboe
Combined used
−88 mmboe
± Conv. to developed
0
Net change
225 mmboe
Closing
994 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Bitumen
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 420 mmboe
+ Ext. & disc.
0
+ Revisions
123 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
123 mmboe
− Divestitures
0
− Production
−129 mmboe
Combined used
−129 mmboe
± Conv. to developed
0
Net change
252 mmboe
Closing
2 414 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
353 mmboe
+ Ext. & disc.
0
+ Revisions
26 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
26 mmboe
− Divestitures
0
− Production
−25 mmboe
Combined used
−25 mmboe
± Conv. to developed
0
Net change
51 mmboe
Closing
354 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
118 mmboe
+ Ext. & disc.
11.17 mmboe
+ Revisions
−33.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−22.33 mmboe
− Divestitures
−0.17 mmboe
− Production
−8.83 mmboe
Combined used
−9 mmboe
± Conv. to developed
0
Net change
−13.33 mmboe
Closing
86.67 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Canada/Other Americas Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
994 mmboe
+ Ext. & disc.
138 mmboe
+ Revisions
116 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
254 mmboe
− Divestitures
−4 mmboe
− Production
−126 mmboe
Combined used
−130 mmboe
± Conv. to developed
0
Net change
384 mmboe
Closing
1 118 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Bitumen
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 414 mmboe
+ Ext. & disc.
0
+ Revisions
152 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
152 mmboe
− Divestitures
0
− Production
−137 mmboe
Combined used
−137 mmboe
± Conv. to developed
0
Net change
289 mmboe
Closing
2 429 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
354 mmboe
+ Ext. & disc.
0
+ Revisions
−35 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−35 mmboe
− Divestitures
0
− Production
−23 mmboe
Combined used
−23 mmboe
± Conv. to developed
0
Net change
−12 mmboe
Closing
296 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
86.67 mmboe
+ Ext. & disc.
11.33 mmboe
+ Revisions
3.67 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
15 mmboe
− Divestitures
−1.67 mmboe
− Production
−9.83 mmboe
Combined used
−11.5 mmboe
± Conv. to developed
0
Net change
26.5 mmboe
Closing
90.17 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Canada/Other Americas Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 118 mmboe
+ Ext. & disc.
92 mmboe
+ Revisions
124 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
216 mmboe
− Divestitures
0
− Production
−139 mmboe
Combined used
−139 mmboe
± Conv. to developed
0
Net change
355 mmboe
Closing
1 195 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Bitumen
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 429 mmboe
+ Ext. & disc.
0
+ Revisions
42 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
42 mmboe
− Divestitures
0
− Production
−141 mmboe
Combined used
−141 mmboe
± Conv. to developed
0
Net change
183 mmboe
Closing
2 330 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
296 mmboe
+ Ext. & disc.
0
+ Revisions
17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
17 mmboe
− Divestitures
0
− Production
−25 mmboe
Combined used
−25 mmboe
± Conv. to developed
0
Net change
42 mmboe
Closing
288 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
90.17 mmboe
+ Ext. & disc.
4.33 mmboe
+ Revisions
3.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
7.83 mmboe
− Divestitures
−4.67 mmboe
− Production
−5.5 mmboe
Combined used
−10.17 mmboe
± Conv. to developed
0
Net change
18 mmboe
Closing
87.83 mmboe
Balance check
✓
2023
Canada/Other Americas Upstream (Play)
Oil
1P
Net
Sec
945 mmboe
105 mmboe
32 mmboe
0
0
137 mmboe
0
−88 mmboe
−88 mmboe
0
225 mmboe
994 mmboe
✓
Canada/Other Americas Upstream (Play)
Bitumen
1P
Net
Sec
2 420 mmboe
0
123 mmboe
0
0
123 mmboe
0
−129 mmboe
−129 mmboe
0
252 mmboe
2 414 mmboe
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
1P
Net
Sec
353 mmboe
0
26 mmboe
0
0
26 mmboe
0
−25 mmboe
−25 mmboe
0
51 mmboe
354 mmboe
✓
Canada/Other Americas Upstream (Play)
Natural gas
1P
Net
Sec
118 mmboe
11.17 mmboe
−33.5 mmboe
0
0
−22.33 mmboe
−0.17 mmboe
−8.83 mmboe
−9 mmboe
0
−13.33 mmboe
86.67 mmboe
✓
2024
Canada/Other Americas Upstream (Play)
Oil
1P
Net
Sec
994 mmboe
138 mmboe
116 mmboe
0
0
254 mmboe
−4 mmboe
−126 mmboe
−130 mmboe
0
384 mmboe
1 118 mmboe
✓
Canada/Other Americas Upstream (Play)
Bitumen
1P
Net
Sec
2 414 mmboe
0
152 mmboe
0
0
152 mmboe
0
−137 mmboe
−137 mmboe
0
289 mmboe
2 429 mmboe
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
1P
Net
Sec
354 mmboe
0
−35 mmboe
0
0
−35 mmboe
0
−23 mmboe
−23 mmboe
0
−12 mmboe
296 mmboe
✓
Canada/Other Americas Upstream (Play)
Natural gas
1P
Net
Sec
86.67 mmboe
11.33 mmboe
3.67 mmboe
0
0
15 mmboe
−1.67 mmboe
−9.83 mmboe
−11.5 mmboe
0
26.5 mmboe
90.17 mmboe
✓
2025
Canada/Other Americas Upstream (Play)
Oil
1P
Net
Sec
1 118 mmboe
92 mmboe
124 mmboe
0
0
216 mmboe
0
−139 mmboe
−139 mmboe
0
355 mmboe
1 195 mmboe
✓
Canada/Other Americas Upstream (Play)
Bitumen
1P
Net
Sec
2 429 mmboe
0
42 mmboe
0
0
42 mmboe
0
−141 mmboe
−141 mmboe
0
183 mmboe
2 330 mmboe
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
1P
Net
Sec
296 mmboe
0
17 mmboe
0
0
17 mmboe
0
−25 mmboe
−25 mmboe
0
42 mmboe
288 mmboe
✓
Canada/Other Americas Upstream (Play)
Natural gas
1P
Net
Sec
90.17 mmboe
4.33 mmboe
3.5 mmboe
0
0
7.83 mmboe
−4.67 mmboe
−5.5 mmboe
−10.17 mmboe
0
18 mmboe
87.83 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | ||||
|---|---|---|---|---|
| Oil · 1P · Net change (Δ %) | Bitumen · 1P · Net change (Δ %) | Synthetic crude · 1P · Net change (Δ %) | Natural gas · 1P · Net change (Δ %) | |
|
2023
|
225 mmboe (+24%)
|
252 mmboe (+10%)
|
51 mmboe (+14%)
|
−13.33 mmboe (-11%)
|
|
2024
|
384 mmboe (+39%)
|
289 mmboe (+12%)
|
−12 mmboe (-3%)
|
26.5 mmboe (+31%)
|
|
2025
|
355 mmboe (+32%)
|
183 mmboe (+8%)
|
42 mmboe (+14%)
|
18 mmboe (+20%)
|
2023
Oil · 1P · Net change (Δ %)
225 mmboe (+24%)
Bitumen · 1P · Net change (Δ %)
252 mmboe (+10%)
Synthetic crude · 1P · Net change (Δ %)
51 mmboe (+14%)
Natural gas · 1P · Net change (Δ %)
−13.33 mmboe (-11%)
2024
Oil · 1P · Net change (Δ %)
384 mmboe (+39%)
Bitumen · 1P · Net change (Δ %)
289 mmboe (+12%)
Synthetic crude · 1P · Net change (Δ %)
−12 mmboe (-3%)
Natural gas · 1P · Net change (Δ %)
26.5 mmboe (+31%)
2025
Oil · 1P · Net change (Δ %)
355 mmboe (+32%)
Bitumen · 1P · Net change (Δ %)
183 mmboe (+8%)
Synthetic crude · 1P · Net change (Δ %)
42 mmboe (+14%)
Natural gas · 1P · Net change (Δ %)
18 mmboe (+20%)
2023
225 mmboe (+24%)
252 mmboe (+10%)
51 mmboe (+14%)
−13.33 mmboe (-11%)
2024
384 mmboe (+39%)
289 mmboe (+12%)
−12 mmboe (-3%)
26.5 mmboe (+31%)
2025
355 mmboe (+32%)
183 mmboe (+8%)
42 mmboe (+14%)
18 mmboe (+20%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
Europe Upstream
Play
United Kingdom, Europe (UK, Norway, Germany, Netherlands, Cyprus)
Natural gas
2/5
Oil
1/5
Oil Gas
Type
Operating
Status
🇬🇧 United Kingdom, Europe (UK, Norway, Germany, Netherlands, Cyprus)
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Conventional Oil Gas
Extraction:
Conventional Oil Gas
Producing wells (net):
298
Producing wells (net):
298
Description
As at 31 December 2025
Consolidated European upstream operations — UK, Norway, Germany and Netherlands, with exploration offshore Cyprus (Pegasus-1 gas discovery in 2025, commercialization options under evaluation). Equity companies (incl. GasTerra, NAM, BEB) hold additional reserves (YE2025 proved developed 207 bcf gas).
Oil & Gas metrics
Multiple effective dates · 1P
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Natural gas
|
13.87 mmboe/yr
4/5
|
56.33 mmboe 1P
2/5
|
reserves 4.1 yrs
|
|
Oil
|
0.73 mmboe/yr
2/5
|
3 mmboe 1P
1/5
|
reserves 4.1 yrs
|
|
NGL
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
13.87 mmboe/yr
4/5
56.33 mmboe 1P
2/5
reserves 4.1 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
0.73 mmboe/yr
2/5
3 mmboe 1P
1/5
reserves 4.1 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
-
-
-
Natural gas
13.87 mmboe/yr
4/5
56.33 mmboe 1P
2/5
reserves 4.1 yrs
Oil
0.73 mmboe/yr
2/5
3 mmboe 1P
1/5
reserves 4.1 yrs
NGL
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
Multiple effective dates
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
8.30M net acres · 7% developed
546k developed · 7.75M undeveloped
|
298 net producing
|
-
|
-
|
1 drilled
FY 2025
|
1 WIP
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
8.30M net acres · 7% developed
546k developed · 7.75M undeveloped
298 net producing
-
-
1 drilled
FY 2025
1 WIP
8.30M net acres · 7% developed
546k developed · 7.75M undeveloped
298 net producing
-
-
1 drilled
FY 2025
1 WIP
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Reserves & resources — detail
As at 31 December 2025
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Europe Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
68.83 mmboe
|
0
|
−0.5 mmboe
|
0
|
0
|
−0.5 mmboe
|
0
|
−17.17 mmboe
|
−17.17 mmboe
|
0
|
16.67 mmboe
|
51.17 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
5 mmboe
|
0
|
0
|
0
|
0
|
0
|
0
|
−1 mmboe
|
−1 mmboe
|
0
|
1 mmboe
|
4 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Europe Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
51.17 mmboe
|
0
|
33 mmboe
|
0
|
0
|
33 mmboe
|
0
|
−16.5 mmboe
|
−16.5 mmboe
|
0
|
49.5 mmboe
|
67.67 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
4 mmboe
|
0
|
0
|
0
|
0
|
0
|
0
|
−1 mmboe
|
−1 mmboe
|
0
|
1 mmboe
|
3 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Europe Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
67.67 mmboe
|
0
|
3.5 mmboe
|
0
|
0
|
3.5 mmboe
|
0
|
−14.83 mmboe
|
−14.83 mmboe
|
0
|
18.33 mmboe
|
56.33 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
3 mmboe
|
0
|
1 mmboe
|
0
|
0
|
1 mmboe
|
0
|
−1 mmboe
|
−1 mmboe
|
0
|
2 mmboe
|
3 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Europe Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
68.83 mmboe
+ Ext. & disc.
0
+ Revisions
−0.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−0.5 mmboe
− Divestitures
0
− Production
−17.17 mmboe
Combined used
−17.17 mmboe
± Conv. to developed
0
Net change
16.67 mmboe
Closing
51.17 mmboe
Balance check
✓
Europe Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
5 mmboe
+ Ext. & disc.
0
+ Revisions
0
+ Improved rec.
0
+ Purchases
0
Combined added
0
− Divestitures
0
− Production
−1 mmboe
Combined used
−1 mmboe
± Conv. to developed
0
Net change
1 mmboe
Closing
4 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Europe Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
51.17 mmboe
+ Ext. & disc.
0
+ Revisions
33 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
33 mmboe
− Divestitures
0
− Production
−16.5 mmboe
Combined used
−16.5 mmboe
± Conv. to developed
0
Net change
49.5 mmboe
Closing
67.67 mmboe
Balance check
✓
Europe Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
4 mmboe
+ Ext. & disc.
0
+ Revisions
0
+ Improved rec.
0
+ Purchases
0
Combined added
0
− Divestitures
0
− Production
−1 mmboe
Combined used
−1 mmboe
± Conv. to developed
0
Net change
1 mmboe
Closing
3 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Europe Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
67.67 mmboe
+ Ext. & disc.
0
+ Revisions
3.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
3.5 mmboe
− Divestitures
0
− Production
−14.83 mmboe
Combined used
−14.83 mmboe
± Conv. to developed
0
Net change
18.33 mmboe
Closing
56.33 mmboe
Balance check
✓
Europe Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 mmboe
+ Ext. & disc.
0
+ Revisions
1 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
1 mmboe
− Divestitures
0
− Production
−1 mmboe
Combined used
−1 mmboe
± Conv. to developed
0
Net change
2 mmboe
Closing
3 mmboe
Balance check
✓
2023
Europe Upstream (Play)
Natural gas
1P
Net
Sec
68.83 mmboe
0
−0.5 mmboe
0
0
−0.5 mmboe
0
−17.17 mmboe
−17.17 mmboe
0
16.67 mmboe
51.17 mmboe
✓
Europe Upstream (Play)
Oil
1P
Net
Sec
5 mmboe
0
0
0
0
0
0
−1 mmboe
−1 mmboe
0
1 mmboe
4 mmboe
✓
2024
Europe Upstream (Play)
Natural gas
1P
Net
Sec
51.17 mmboe
0
33 mmboe
0
0
33 mmboe
0
−16.5 mmboe
−16.5 mmboe
0
49.5 mmboe
67.67 mmboe
✓
Europe Upstream (Play)
Oil
1P
Net
Sec
4 mmboe
0
0
0
0
0
0
−1 mmboe
−1 mmboe
0
1 mmboe
3 mmboe
✓
2025
Europe Upstream (Play)
Natural gas
1P
Net
Sec
67.67 mmboe
0
3.5 mmboe
0
0
3.5 mmboe
0
−14.83 mmboe
−14.83 mmboe
0
18.33 mmboe
56.33 mmboe
✓
Europe Upstream (Play)
Oil
1P
Net
Sec
3 mmboe
0
1 mmboe
0
0
1 mmboe
0
−1 mmboe
−1 mmboe
0
2 mmboe
3 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | ||
|---|---|---|
| Natural gas · 1P · Net change (Δ %) | Oil · 1P · Net change (Δ %) | |
|
2023
|
16.67 mmboe (+24%)
|
1 mmboe (+20%)
|
|
2024
|
49.5 mmboe (+97%)
|
1 mmboe (+25%)
|
|
2025
|
18.33 mmboe (+27%)
|
2 mmboe (+67%)
|
2023
Natural gas · 1P · Net change (Δ %)
16.67 mmboe (+24%)
Oil · 1P · Net change (Δ %)
1 mmboe (+20%)
2024
Natural gas · 1P · Net change (Δ %)
49.5 mmboe (+97%)
Oil · 1P · Net change (Δ %)
1 mmboe (+25%)
2025
Natural gas · 1P · Net change (Δ %)
18.33 mmboe (+27%)
Oil · 1P · Net change (Δ %)
2 mmboe (+67%)
2023
16.67 mmboe (+24%)
1 mmboe (+20%)
2024
49.5 mmboe (+97%)
1 mmboe (+25%)
2025
18.33 mmboe (+27%)
2 mmboe (+67%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
Africa Upstream
Play
Angola, Africa (Angola, Nigeria, Mozambique)
Oil
4/5
Natural gas
2/5
Oil Gas
Type
Operating
Status
🇦🇴 Angola, Africa (Angola, Nigeria, Mozambique)
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Offshore
Extraction:
Offshore
Producing wells (net):
94
Producing wells (net):
94
Description
As at 31 December 2025
Consolidated African upstream operations — three producing deepwater blocks in Angola and three in Nigeria, plus the Coral South Floating LNG offshore Mozambique. In 2025, Angola Block 15 amended its PSA to extend the production license to 2037 and 1.6 net acres were relinquished. Equity companies hold an additional 775 bcf of proved developed gas at YE2025.
Oil & Gas metrics
Multiple effective dates · 1P
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Oil
|
51.47 mmboe/yr
4/5
|
217 mmboe 1P
4/5
|
reserves 4.2 yrs
|
|
Natural gas
|
0.12 mmboe/yr
1/5
|
18.83 mmboe 1P
2/5
|
reserves 25+ yrs
|
|
NGL
|
0.73 mmboe/yr
3/5
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
51.47 mmboe/yr
4/5
217 mmboe 1P
4/5
reserves 4.2 yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
0.12 mmboe/yr
1/5
18.83 mmboe 1P
2/5
reserves 25+ yrs
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
0.73 mmboe/yr
3/5
-
-
Oil
51.47 mmboe/yr
4/5
217 mmboe 1P
4/5
reserves 4.2 yrs
Natural gas
0.12 mmboe/yr
1/5
18.83 mmboe 1P
2/5
reserves 25+ yrs
NGL
0.73 mmboe/yr
3/5
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint
Multiple effective dates
| Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) |
|---|---|---|---|---|---|
|
8.49M net acres · 5% developed
428k developed · 8.06M undeveloped
|
94 net producing
|
-
|
-
|
1 drilled
FY 2025
|
2 WIP
|
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
8.49M net acres · 5% developed
428k developed · 8.06M undeveloped
94 net producing
-
-
1 drilled
FY 2025
2 WIP
8.49M net acres · 5% developed
428k developed · 8.06M undeveloped
94 net producing
-
-
1 drilled
FY 2025
2 WIP
Oil & Gas inventory & footprint — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Reserves & resources — detail
As at 31 December 2025
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Africa Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
271 mmboe
|
0
|
31 mmboe
|
0
|
0
|
31 mmboe
|
0
|
−78 mmboe
|
−78 mmboe
|
0
|
109 mmboe
|
224 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
52 mmboe
|
0
|
−8.17 mmboe
|
0
|
0
|
−8.17 mmboe
|
0
|
−7.17 mmboe
|
−7.17 mmboe
|
0
|
−1 mmboe
|
36.67 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Africa Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
224 mmboe
|
25 mmboe
|
62 mmboe
|
0
|
0
|
87 mmboe
|
−45 mmboe
|
−75 mmboe
|
−120 mmboe
|
0
|
207 mmboe
|
191 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
36.67 mmboe
|
0.33 mmboe
|
4 mmboe
|
0
|
0
|
4.33 mmboe
|
−17.5 mmboe
|
−7.67 mmboe
|
−25.17 mmboe
|
0
|
29.5 mmboe
|
15.83 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Africa Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
191 mmboe
|
0
|
78 mmboe
|
0
|
0
|
78 mmboe
|
0
|
−52 mmboe
|
−52 mmboe
|
0
|
130 mmboe
|
217 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
15.83 mmboe
|
0
|
5.67 mmboe
|
0
|
0
|
5.67 mmboe
|
0
|
−2.67 mmboe
|
−2.67 mmboe
|
0
|
8.33 mmboe
|
18.83 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Africa Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
271 mmboe
+ Ext. & disc.
0
+ Revisions
31 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
31 mmboe
− Divestitures
0
− Production
−78 mmboe
Combined used
−78 mmboe
± Conv. to developed
0
Net change
109 mmboe
Closing
224 mmboe
Balance check
✓
Africa Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
52 mmboe
+ Ext. & disc.
0
+ Revisions
−8.17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−8.17 mmboe
− Divestitures
0
− Production
−7.17 mmboe
Combined used
−7.17 mmboe
± Conv. to developed
0
Net change
−1 mmboe
Closing
36.67 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Africa Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
224 mmboe
+ Ext. & disc.
25 mmboe
+ Revisions
62 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
87 mmboe
− Divestitures
−45 mmboe
− Production
−75 mmboe
Combined used
−120 mmboe
± Conv. to developed
0
Net change
207 mmboe
Closing
191 mmboe
Balance check
✓
Africa Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
36.67 mmboe
+ Ext. & disc.
0.33 mmboe
+ Revisions
4 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
4.33 mmboe
− Divestitures
−17.5 mmboe
− Production
−7.67 mmboe
Combined used
−25.17 mmboe
± Conv. to developed
0
Net change
29.5 mmboe
Closing
15.83 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Africa Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
191 mmboe
+ Ext. & disc.
0
+ Revisions
78 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
78 mmboe
− Divestitures
0
− Production
−52 mmboe
Combined used
−52 mmboe
± Conv. to developed
0
Net change
130 mmboe
Closing
217 mmboe
Balance check
✓
Africa Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
15.83 mmboe
+ Ext. & disc.
0
+ Revisions
5.67 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
5.67 mmboe
− Divestitures
0
− Production
−2.67 mmboe
Combined used
−2.67 mmboe
± Conv. to developed
0
Net change
8.33 mmboe
Closing
18.83 mmboe
Balance check
✓
2023
Africa Upstream (Play)
Oil
1P
Net
Sec
271 mmboe
0
31 mmboe
0
0
31 mmboe
0
−78 mmboe
−78 mmboe
0
109 mmboe
224 mmboe
✓
Africa Upstream (Play)
Natural gas
1P
Net
Sec
52 mmboe
0
−8.17 mmboe
0
0
−8.17 mmboe
0
−7.17 mmboe
−7.17 mmboe
0
−1 mmboe
36.67 mmboe
✓
2024
Africa Upstream (Play)
Oil
1P
Net
Sec
224 mmboe
25 mmboe
62 mmboe
0
0
87 mmboe
−45 mmboe
−75 mmboe
−120 mmboe
0
207 mmboe
191 mmboe
✓
Africa Upstream (Play)
Natural gas
1P
Net
Sec
36.67 mmboe
0.33 mmboe
4 mmboe
0
0
4.33 mmboe
−17.5 mmboe
−7.67 mmboe
−25.17 mmboe
0
29.5 mmboe
15.83 mmboe
✓
2025
Africa Upstream (Play)
Oil
1P
Net
Sec
191 mmboe
0
78 mmboe
0
0
78 mmboe
0
−52 mmboe
−52 mmboe
0
130 mmboe
217 mmboe
✓
Africa Upstream (Play)
Natural gas
1P
Net
Sec
15.83 mmboe
0
5.67 mmboe
0
0
5.67 mmboe
0
−2.67 mmboe
−2.67 mmboe
0
8.33 mmboe
18.83 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | ||
|---|---|---|
| Oil · 1P · Net change (Δ %) | Natural gas · 1P · Net change (Δ %) | |
|
2023
|
109 mmboe (+40%)
|
−1 mmboe (-2%)
|
|
2024
|
207 mmboe (+92%)
|
29.5 mmboe (+80%)
|
|
2025
|
130 mmboe (+68%)
|
8.33 mmboe (+53%)
|
2023
Oil · 1P · Net change (Δ %)
109 mmboe (+40%)
Natural gas · 1P · Net change (Δ %)
−1 mmboe (-2%)
2024
Oil · 1P · Net change (Δ %)
207 mmboe (+92%)
Natural gas · 1P · Net change (Δ %)
29.5 mmboe (+80%)
2025
Oil · 1P · Net change (Δ %)
130 mmboe (+68%)
Natural gas · 1P · Net change (Δ %)
8.33 mmboe (+53%)
2023
109 mmboe (+40%)
−1 mmboe (-2%)
2024
207 mmboe (+92%)
29.5 mmboe (+80%)
2025
130 mmboe (+68%)
8.33 mmboe (+53%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
Angola Deepwater Blocks (incl. Block 15)
Play
Angola, Offshore Angola
Oil Gas
Type
Operating
Status
🇦🇴 Angola, Offshore Angola
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Offshore
Extraction:
Offshore
Description
As at 31 December 2025
Three producing deepwater blocks offshore Angola. In 2025, Block 15 amended its Production Sharing Agreement to extend the production license to 2037, and a total of 1.6 net acres were relinquished in Angola.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Nigeria Deepwater Blocks
Play
Nigeria, Offshore Nigeria
Oil Gas
Type
Operating
Status
🇳🇬 Nigeria, Offshore Nigeria
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Offshore
Extraction:
Offshore
Description
As at 31 December 2025
Three producing deepwater blocks offshore Nigeria in which operations continued during 2025.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Permian Basin
Play · Operating
United States, Texas and New Mexico, Permian Basin
Oil equivalent (BOE)
Oil Gas
Type
Operating
Status
🇺🇸 United States, Texas and New Mexico (Permian Basin)
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Unconventional Shale
Extraction:
Unconventional Shale
Description
As at 31 December 2025
Liquids-rich unconventional development across the Delaware and Midland sub-basins of West Texas and New Mexico — ExxonMobil's primary onshore U.S. growth asset, expanded by the May 2024 Pioneer Natural Resources acquisition. Record total production of 1.6 Moebd in 2025, ~0.4 Moebd above 2024. Development applies ExxonMobil cube design, proprietary lightweight proppant, and leading drilling/completion technology for industry-leading capital efficiency. Production expected to reach ~2.5 Moebd by 2030. On track for net-zero Scope 1+2 GHG emissions in integrated Permian operated assets by 2035.
Oil & Gas metrics
As at 31 December 2025
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Oil equivalent (BOE)
|
584 mmboe/yr
5/5
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil equivalent (BOE)
584 mmboe/yr
5/5
-
-
Oil equivalent (BOE)
584 mmboe/yr
5/5
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Stabroek Block
Play · Operating
Guyana, Offshore Guyana
Oil
Oil Gas
Type
Operating
Status
🇬🇾 Guyana, Offshore Guyana
Country
Project information
As at 31 December 2025
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Offshore
Extraction:
Offshore
Description
As at 31 December 2025
Deepwater development offshore Guyana. Four FPSOs in operation at YE2025 — Liza Destiny, Liza Unity, Prosperity, and ONE GUYANA (Yellowtail), which entered service in August 2025; combined gross production exceeded 870 kbd in Q4 2025 and Guyana achieved record annual production of 715 kbd. Uaru and Whiptail (fifth and sixth developments, ~250 kbd investment-basis capacity each) progressing on schedule; Hammerhead reached FID in September 2025 with start-up anticipated 2029. Eight FPSOs anticipated by year-end 2030. Guyana petroleum agreements provide 20-year production periods for oil fields (renewable up to 10 years).
Oil & Gas metrics
As at 31 December 2025
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
Oil
|
260.98 mmboe/yr
5/5
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
260.98 mmboe/yr
5/5
-
-
Oil
260.98 mmboe/yr
5/5
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Development · 1 project
Rovuma LNG
Asset · Feasibility · Ownership 36%
Mozambique, Offshore Mozambique (Area 4)
Oil Gas
Type
Development
Status
🇲🇿 Mozambique, Offshore Mozambique (Area 4)
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
36
Ownership %:
36
Operator:
Yes
Operator:
Yes
Extraction:
Lng
Extraction:
Lng
Description
As at 31 December 2025
Proposed onshore LNG development of the Area 4 offshore gas resources in Mozambique (ExxonMobil 36% interest in Mozambique Rovuma Venture S.p.A.). Force majeure was lifted in 2025 and the project continues front-end engineering and design in support of a final investment decision in 2026.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Exploration · 1 project
Offshore Cyprus Exploration (Pegasus-1)
Asset · Exploration
Cyprus, Offshore Cyprus
Oil Gas
Type
Exploration
Status
Cyprus, Offshore Cyprus
Country
Project information
As at 31 December 2025
Aggregation level:
Asset
Aggregation level:
Asset
Report standard:
Sec S K 1200
Report standard:
Sec S K 1200
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Offshore
Extraction:
Offshore
Description
As at 31 December 2025
The Pegasus-1 exploratory well was drilled offshore Cyprus in 2025 and encountered a gas-bearing reservoir. Evaluations are ongoing to develop potential commercialization options.
Oil & Gas metrics
| Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime |
|---|---|---|---|
|
-
|
-
|
-
|
-
|
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
-
-
-
-
-
-
-
-
Oil & Gas metrics — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Processing facilities · 16 projects
Qatar LNG (North Field)
Play · Lng Export · Operating
Qatar, Qatar
Natural gas
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Play or complex
Aggregation level:
Play or complex
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
No
Operator:
No
Operator name:
QatarEnergy LNG ventures
Operator name:
QatarEnergy LNG ventures
Extraction:
Lng
Extraction:
Lng
Country:
Qatar
Country:
Qatar
Region:
Qatar
Region:
Qatar
Facility kind:
Lng Export
Facility kind:
Lng Export
Licensed capacity:
45.7
Licensed capacity:
45.7
Capacity unit:
mt
Capacity unit:
mt
Capacity period:
Per Year
Capacity period:
Per Year
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
ExxonMobil participation in Qatar LNG — 45.7 million tonnes per year of gross liquefied natural gas capacity and 3.4 bcf/d of flowing gas capacity in 2025. Development activities continued on the North Field East and North Field Production Sustainment projects. Held through QatarEnergy LNG equity ventures (ownership interests of 24-31% across QatarEnergy LNG N and S trains).
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Natural gas
|
3.4 bcf/Per Day
Nameplate
|
Feedstock
Capacity
Natural gas
3.4 bcf/Per Day
Nameplate
Natural gas
3.4 bcf/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Beaumont Refining & Chemical Complex
Asset · Operating
United States, Texas
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
United States
Country:
United States
Region:
Texas
Region:
Texas
Facility kind:
-
Facility kind:
-
Licensed capacity:
612
Licensed capacity:
612
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Beaumont Refining & Chemical Complex — ExxonMobil's share of refining capacity 612 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network. Ethylene 0.9 Mt/yr, polyethylene 1.7 Mt/yr.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
612 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
612 mbbl/Per Day
Nameplate
Oil
612 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Singapore Refining & Chemical Complex
Asset · Operating
Singapore, Jurong/Singapore
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Singapore
Country:
Singapore
Region:
Jurong/Singapore
Region:
Jurong/Singapore
Facility kind:
-
Facility kind:
-
Licensed capacity:
592
Licensed capacity:
592
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Singapore Refining & Chemical Complex — ExxonMobil's share of refining capacity 592 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network. Ethylene 1.9 Mt/yr, polyethylene 1.9 Mt/yr, polypropylene 1.0 Mt/yr.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
592 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
592 mbbl/Per Day
Nameplate
Oil
592 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Baytown Refining & Chemical Complex
Asset · Operating
United States, Texas
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
United States
Country:
United States
Region:
Texas
Region:
Texas
Facility kind:
-
Facility kind:
-
Licensed capacity:
565
Licensed capacity:
565
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Baytown Refining & Chemical Complex — ExxonMobil's share of refining capacity 565 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network. Ethylene 4.0 Mt/yr, polypropylene 0.8 Mt/yr.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
565 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
565 mbbl/Per Day
Nameplate
Oil
565 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Baton Rouge Refining & Chemical Complex
Asset · Operating
United States, Louisiana
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
United States
Country:
United States
Region:
Louisiana
Region:
Louisiana
Facility kind:
-
Facility kind:
-
Licensed capacity:
523
Licensed capacity:
523
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Baton Rouge Refining & Chemical Complex — ExxonMobil's share of refining capacity 523 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network. Ethylene 1.1 Mt/yr, polyethylene 1.3 Mt/yr, polypropylene 1.0 Mt/yr.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
523 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
523 mbbl/Per Day
Nameplate
Oil
523 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Antwerp Refinery
Asset · Operating
Belgium, Antwerp
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Belgium
Country:
Belgium
Region:
Antwerp
Region:
Antwerp
Facility kind:
-
Facility kind:
-
Licensed capacity:
318
Licensed capacity:
318
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Antwerp Refinery — ExxonMobil's share of refining capacity 318 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network. Polyethylene 0.4 Mt/yr.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
318 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
318 mbbl/Per Day
Nameplate
Oil
318 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Joliet Refinery
Asset · Operating
United States, Illinois
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
United States
Country:
United States
Region:
Illinois
Region:
Illinois
Facility kind:
-
Facility kind:
-
Licensed capacity:
267
Licensed capacity:
267
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Joliet Refinery — ExxonMobil's share of refining capacity 267 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
267 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
267 mbbl/Per Day
Nameplate
Oil
267 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Fawley Refining & Chemical Complex
Asset · Operating
United Kingdom, Hampshire
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
United Kingdom
Country:
United Kingdom
Region:
Hampshire
Region:
Hampshire
Facility kind:
-
Facility kind:
-
Licensed capacity:
265
Licensed capacity:
265
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Fawley Refining & Chemical Complex — ExxonMobil's share of refining capacity 265 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
265 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
265 mbbl/Per Day
Nameplate
Oil
265 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Yanbu Refinery (SAMREF)
Asset · Operating · Ownership 50%
Saudi Arabia, Yanbu
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
50
Ownership %:
50
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Saudi Arabia
Country:
Saudi Arabia
Region:
Yanbu
Region:
Yanbu
Facility kind:
-
Facility kind:
-
Licensed capacity:
200
Licensed capacity:
200
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Yanbu Refinery (SAMREF) — ExxonMobil's share of refining capacity 200 thousand barrels per day at year-end 2025 (ExxonMobil interest 50%). Part of the integrated global refining and chemical manufacturing network. Saudi Aramco Mobil Refinery Company JV (50%).
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
200 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
200 mbbl/Per Day
Nameplate
Oil
200 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Strathcona Refinery
Asset · Operating · Ownership 69.6%
Canada, Alberta
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
69.6
Ownership %:
69.6
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Canada
Country:
Canada
Region:
Alberta
Region:
Alberta
Facility kind:
-
Facility kind:
-
Licensed capacity:
197
Licensed capacity:
197
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Strathcona Refinery — ExxonMobil's share of refining capacity 197 thousand barrels per day at year-end 2025 (ExxonMobil interest 69.6%). Part of the integrated global refining and chemical manufacturing network. Held via Imperial Oil (69.6%).
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
197 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
197 mbbl/Per Day
Nameplate
Oil
197 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Rotterdam Refinery
Asset · Operating
Netherlands, Rotterdam
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
100
Ownership %:
100
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Netherlands
Country:
Netherlands
Region:
Rotterdam
Region:
Rotterdam
Facility kind:
-
Facility kind:
-
Licensed capacity:
192
Licensed capacity:
192
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Rotterdam Refinery — ExxonMobil's share of refining capacity 192 thousand barrels per day at year-end 2025 (ExxonMobil interest 100%). Part of the integrated global refining and chemical manufacturing network.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
192 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
192 mbbl/Per Day
Nameplate
Oil
192 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Sarnia Refining & Chemical Complex
Asset · Operating · Ownership 69.6%
Canada, Ontario
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
69.6
Ownership %:
69.6
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Canada
Country:
Canada
Region:
Ontario
Region:
Ontario
Facility kind:
-
Facility kind:
-
Licensed capacity:
124
Licensed capacity:
124
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Sarnia Refining & Chemical Complex — ExxonMobil's share of refining capacity 124 thousand barrels per day at year-end 2025 (ExxonMobil interest 69.6%). Part of the integrated global refining and chemical manufacturing network. Ethylene 0.3 Mt/yr, polyethylene 0.5 Mt/yr. Held via Imperial Oil (69.6%).
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
124 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
124 mbbl/Per Day
Nameplate
Oil
124 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Nanticoke Refinery
Asset · Operating · Ownership 69.6%
Canada, Ontario
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
69.6
Ownership %:
69.6
Operator:
Yes
Operator:
Yes
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Canada
Country:
Canada
Region:
Ontario
Region:
Ontario
Facility kind:
-
Facility kind:
-
Licensed capacity:
113
Licensed capacity:
113
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Nanticoke Refinery — ExxonMobil's share of refining capacity 113 thousand barrels per day at year-end 2025 (ExxonMobil interest 69.6%). Part of the integrated global refining and chemical manufacturing network. Held via Imperial Oil (69.6%).
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
113 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
113 mbbl/Per Day
Nameplate
Oil
113 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Karlsruhe Refinery
Asset · Operating · Ownership 25%
Germany, Baden-Wuerttemberg
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
25
Ownership %:
25
Operator:
No
Operator:
No
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
Germany
Country:
Germany
Region:
Baden-Wuerttemberg
Region:
Baden-Wuerttemberg
Facility kind:
-
Facility kind:
-
Licensed capacity:
78
Licensed capacity:
78
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Karlsruhe Refinery — ExxonMobil's share of refining capacity 78 thousand barrels per day at year-end 2025 (ExxonMobil interest 25%). Part of the integrated global refining and chemical manufacturing network. ExxonMobil share of capacity at 25% interest.
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
78 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
78 mbbl/Per Day
Nameplate
Oil
78 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Fujian Refining & Petrochemical
Asset · Operating · Ownership 25%
China, Fujian
Oil
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Operating
Status:
Operating
Report standard:
-
Report standard:
-
Ownership %:
25
Ownership %:
25
Operator:
No
Operator:
No
Extraction:
Processing Facility
Extraction:
Processing Facility
Country:
China
Country:
China
Region:
Fujian
Region:
Fujian
Facility kind:
-
Facility kind:
-
Licensed capacity:
67
Licensed capacity:
67
Capacity unit:
mbbl
Capacity unit:
mbbl
Capacity period:
Per Day
Capacity period:
Per Day
Capacity kind:
Nameplate
Capacity kind:
Nameplate
Description
As at 31 December 2025
Fujian Refining & Petrochemical — ExxonMobil's share of refining capacity 67 thousand barrels per day at year-end 2025 (ExxonMobil interest 25%). Part of the integrated global refining and chemical manufacturing network. Ethylene 0.3 Mt/yr, polyethylene 0.2 Mt/yr, polypropylene 0.2 Mt/yr (ExxonMobil share, 25% JV).
Processing facilities
As at 31 December 2025
| Feedstock | Capacity |
|---|---|
|
Oil
|
67 mbbl/Per Day
Nameplate
|
Feedstock
Capacity
Oil
67 mbbl/Per Day
Nameplate
Oil
67 mbbl/Per Day
Nameplate
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Golden Pass LNG
Asset · Lng Export · Construction · Ownership 30%
United States, Texas (Sabine Pass)
Project information
As at 31 December 2025
Type:
Processing Facility
Type:
Processing Facility
Aggregation level:
Asset
Aggregation level:
Asset
Status:
Construction
Status:
Construction
Report standard:
-
Report standard:
-
Ownership %:
30
Ownership %:
30
Operator:
No
Operator:
No
Operator name:
Golden Pass LNG Terminal LLC
Operator name:
Golden Pass LNG Terminal LLC
Extraction:
Lng
Extraction:
Lng
Country:
United States
Country:
United States
Region:
Texas (Sabine Pass)
Region:
Texas (Sabine Pass)
Facility kind:
Lng Export
Facility kind:
Lng Export
Licensed capacity:
-
Licensed capacity:
-
Capacity unit:
-
Capacity unit:
-
Capacity period:
-
Capacity period:
-
Capacity kind:
-
Capacity kind:
-
Description
As at 31 December 2025
LNG export terminal under construction at Sabine Pass, Texas (Golden Pass LNG Terminal LLC — ExxonMobil 30% equity interest). Mechanical completion of Train 1 achieved in late 2025, with first LNG production expected in the first quarter of 2026. One of ExxonMobil's key U.S. LNG expansion opportunities alongside Qatar, Mozambique and Papua New Guinea.
Processing facilities
| Feedstock | Capacity |
|---|---|
|
Natural gas
implied
|
-
|
Feedstock
Capacity
Natural gas
implied
-
Natural gas
implied
-
Processing facilities — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
- The projects listed here reflect the information captured in this workspace and are not necessarily a complete picture of the company's portfolio. For authoritative figures, refer to the company's official filings.
36
Operating projects
1
Construction project
1
Development project
1
Exploration project
Portfolio Summary
Totals from Portfolio Aggregate · Multiple effective dates · 1P
| Commodity | Production (rating) | Reserves & Resources (rating) | Production value (est.) |
|---|---|---|---|
|
Oil
|
825.63 mmboe/yr
5/5
|
8 187 mmboe 1P
5/5
|
$66.9B (71%)
USD 81.08 / bbl
|
|
Natural gas
|
3 081.33 bcf/yr
513.55 mmboe/yr
5/5
|
36 408 bcf 1P
6 068 mmboe 1P
5/5
|
$9.7B (10%)
USD 3.16 / mcf
|
|
NGL
|
223.38 mmboe/yr
5/5
|
2 437 mmboe 1P
5/5
|
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
|
|
Bitumen
|
140.53 mmboe/yr
5/5
|
2 330 mmboe 1P
5/5
|
$7.0B (7%)
≈ $50 / bbl pre-upgrade
|
|
Synthetic crude
|
24.82 mmboe/yr
4/5
|
288 mmboe 1P
4/5
|
$2.0B (2%)
≈ $80 / bbl
|
Oil
Production (rating)
Reserves & Resources (rating)
Production value (est.)
825.63 mmboe/yr
5/5
8 187 mmboe 1P
5/5
$66.9B (71%)
USD 81.08 / bbl
Natural gas
Production (rating)
Reserves & Resources (rating)
Production value (est.)
3 081.33 bcf/yr
513.55 mmboe/yr
5/5
36 408 bcf 1P
6 068 mmboe 1P
5/5
$9.7B (10%)
USD 3.16 / mcf
NGL
Production (rating)
Reserves & Resources (rating)
Production value (est.)
223.38 mmboe/yr
5/5
2 437 mmboe 1P
5/5
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
Bitumen
Production (rating)
Reserves & Resources (rating)
Production value (est.)
140.53 mmboe/yr
5/5
2 330 mmboe 1P
5/5
$7.0B (7%)
≈ $50 / bbl pre-upgrade
Synthetic crude
Production (rating)
Reserves & Resources (rating)
Production value (est.)
24.82 mmboe/yr
4/5
288 mmboe 1P
4/5
$2.0B (2%)
≈ $80 / bbl
Oil
825.63 mmboe/yr
5/5
8 187 mmboe 1P
5/5
$66.9B (71%)
USD 81.08 / bbl
Natural gas
3 081.33 bcf/yr
513.55 mmboe/yr
5/5
36 408 bcf 1P
6 068 mmboe 1P
5/5
$9.7B (10%)
USD 3.16 / mcf
NGL
223.38 mmboe/yr
5/5
2 437 mmboe 1P
5/5
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
Bitumen
140.53 mmboe/yr
5/5
2 330 mmboe 1P
5/5
$7.0B (7%)
≈ $50 / bbl pre-upgrade
Synthetic crude
24.82 mmboe/yr
4/5
288 mmboe 1P
4/5
$2.0B (2%)
≈ $80 / bbl
Portfolio Aggregate
Multiple effective dates · 1P
| Portfolio Aggregate | |||||
|---|---|---|---|---|---|
| Commodity | Production | Reserves & Resources | Production value (est.) | ||
|
|
Σ Portfolio · ExxonMobil Worldwide Upstream
|
Oil
|
825.63 mmboe/yr
|
8 187 mmboe 1P
|
$66.9B (71%)
USD 81.08 / bbl
|
|
|
|
Natural gas
|
513.55 mmboe/yr
|
6 068 mmboe 1P
|
$9.7B (10%)
USD 3.16 / mcf
|
|
|
|
NGL
|
223.38 mmboe/yr
|
2 437 mmboe 1P
|
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
|
|
|
|
Bitumen
|
140.53 mmboe/yr
|
2 330 mmboe 1P
|
$7.0B (7%)
≈ $50 / bbl pre-upgrade
|
|
|
|
Synthetic crude
|
24.82 mmboe/yr
|
288 mmboe 1P
|
$2.0B (2%)
≈ $80 / bbl
|
Σ Portfolio · ExxonMobil Worldwide Upstream
Commodity
Production
Reserves & Resources
Production value (est.)
Oil
825.63 mmboe/yr
8 187 mmboe 1P
$66.9B (71%)
USD 81.08 / bbl
Commodity
Production
Reserves & Resources
Production value (est.)
Natural gas
513.55 mmboe/yr
6 068 mmboe 1P
$9.7B (10%)
USD 3.16 / mcf
Commodity
Production
Reserves & Resources
Production value (est.)
NGL
223.38 mmboe/yr
2 437 mmboe 1P
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
Commodity
Production
Reserves & Resources
Production value (est.)
Bitumen
140.53 mmboe/yr
2 330 mmboe 1P
$7.0B (7%)
≈ $50 / bbl pre-upgrade
Commodity
Production
Reserves & Resources
Production value (est.)
Synthetic crude
24.82 mmboe/yr
288 mmboe 1P
$2.0B (2%)
≈ $80 / bbl
Σ Portfolio · ExxonMobil Worldwide Upstream
Oil
825.63 mmboe/yr
8 187 mmboe 1P
$66.9B (71%)
USD 81.08 / bbl
Natural gas
513.55 mmboe/yr
6 068 mmboe 1P
$9.7B (10%)
USD 3.16 / mcf
NGL
223.38 mmboe/yr
2 437 mmboe 1P
$8.9B (9%)
≈ $40 / bbl mixed-NGL netback
Bitumen
140.53 mmboe/yr
2 330 mmboe 1P
$7.0B (7%)
≈ $50 / bbl pre-upgrade
Synthetic crude
24.82 mmboe/yr
288 mmboe 1P
$2.0B (2%)
≈ $80 / bbl
Portfolio Aggregate — Assumptions & Disclaimers
- When a Portfolio Aggregate row exists, individual asset rows are not summed into it — that would double-count.
- The aggregate typically comes from the annual reserves statement and may use a different effective date than individual asset rows.
- Production value (est.) is attributable annual production × the resolved commodity price (compact USD with an optional mix share in parentheses when multiple commodities contribute; short price label on the second line). Estimated lifetime is not shown on this table — use per-asset Oil & Gas sections for reserve life.
- Portfolio-level rollups are convenient for company-vs-company comparisons but can mask asset-level concentration risk: a single producing field or mine may account for the majority of the rollup figure.
Portfolio Aggregate · Processing facilities
As at 31 December 2025
| Portfolio Aggregate | |||
|---|---|---|---|
| Commodity | Capacity | ||
|
|
Σ Portfolio · ExxonMobil Refining & Chemical Portfolio
|
Oil
|
4 113 mbbl/Per Day
Nameplate
|
Σ Portfolio · ExxonMobil Refining & Chemical Portfolio
Commodity
Capacity
Oil
4 113 mbbl/Per Day
Nameplate
Σ Portfolio · ExxonMobil Refining & Chemical Portfolio
Oil
4 113 mbbl/Per Day
Nameplate
Portfolio Aggregate · Processing facilities — Assumptions & Disclaimers
- Scope: company-wide processing / midstream rollups (refining, pipelines, fractionation, storage, LNG). They are split from the upstream Portfolio Aggregate so each table only shows columns it can populate.
- Capacity is the consolidated nameplate / contracted / licensed capacity from the project record, not period throughput. Production, reserves and production value are intentionally omitted — processing rollups carry no contained-volume × price economics in this model.
- When a Portfolio Aggregate row exists, individual facility rows are not summed into it — that would double-count.
- Nameplate / licensed capacity is an engineering maximum; sustained utilisation may be lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, fractionation spreads) are commodity-specific and may not be visible on this page.
Oil & Gas metrics · 21 projects
Multiple effective dates · 1P
| Project | |||||||
|---|---|---|---|---|---|---|---|
| Location | Status | Commodity | Production (rating) | Reserves & Resources (rating) | Estimated Lifetime | ||
|
★
|
Asia Upstream
|
🇦🇪 United Arab Emirates
Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
|
Operating
|
Oil
|
162.43 mmboe/yr
5/5
|
2 960 mmboe 1P
5/5
|
reserves 18.2 yrs
|
|
|
|
|
|
Natural gas
|
58.89 mmboe/yr
5/5
|
366.5 mmboe 1P
4/5
|
reserves 6.2 yrs
|
|
|
|
|
|
NGL
|
10.22 mmboe/yr
5/5
|
67 mmboe 1P
4/5
|
reserves 6.6 yrs
|
|
★
|
Australia/Oceania Upstream
|
🇦🇺 Australia
Australia and Oceania
|
Operating
|
Natural gas
|
78.05 mmboe/yr
5/5
|
951.67 mmboe 1P
4/5
|
reserves 12.2 yrs
|
|
|
|
|
|
Oil
|
6.57 mmboe/yr
3/5
|
60 mmboe 1P
3/5
|
reserves 9.1 yrs
|
|
|
|
|
|
NGL
|
2.56 mmboe/yr
4/5
|
8 mmboe 1P
2/5
|
reserves 3.1 yrs
|
|
★
|
Canada/Other Americas Upstream
|
🇨🇦 Canada
Canada and Other Americas
|
Operating
|
Oil
|
139.06 mmboe/yr
5/5
|
1 195 mmboe 1P
5/5
|
reserves 8.6 yrs
|
|
|
|
|
|
Bitumen
|
140.53 mmboe/yr
5/5
|
2 330 mmboe 1P
5/5
|
reserves 16.6 yrs
|
|
|
|
|
|
Synthetic crude
|
24.82 mmboe/yr
4/5
|
288 mmboe 1P
4/5
|
reserves 11.6 yrs
|
|
|
|
|
|
Natural gas
|
1.64 mmboe/yr
2/5
|
87.83 mmboe 1P
3/5
|
reserves 25+ yrs
|
|
|
|
|
|
NGL
|
0.36 mmboe/yr
2/5
|
1 mmboe 1P
1/5
|
reserves 2.7 yrs
|
|
★
|
United States Upstream
|
🇺🇸 United States
United States
|
Operating
|
Oil
|
366.82 mmboe/yr
5/5
|
3 110 mmboe 1P
5/5
|
reserves 8.5 yrs
|
|
|
|
|
|
Natural gas
|
203.55 mmboe/yr
5/5
|
2 797.83 mmboe 1P
5/5
|
reserves 13.7 yrs
|
|
|
|
|
|
NGL
|
187.61 mmboe/yr
5/5
|
2 063 mmboe 1P
5/5
|
reserves 11 yrs
|
|
|
Africa Upstream
|
🇦🇴 Angola
Africa (Angola, Nigeria, Mozambique)
|
Operating
|
Oil
|
51.47 mmboe/yr
4/5
|
217 mmboe 1P
4/5
|
reserves 4.2 yrs
|
|
|
|
|
|
Natural gas
|
0.12 mmboe/yr
1/5
|
18.83 mmboe 1P
2/5
|
reserves 25+ yrs
|
|
|
|
|
|
NGL
|
0.73 mmboe/yr
3/5
|
-
|
-
|
|
|
Angola Deepwater Blocks (incl. Block 15)
|
🇦🇴 Angola
Offshore Angola
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Bacalhau
|
🇧🇷 Brazil
Offshore Brazil
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Coral South FLNG
Ownership 25.0% WI
|
🇲🇿 Mozambique
Offshore Mozambique (Area 4)
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Europe Upstream
|
🇬🇧 United Kingdom
Europe (UK, Norway, Germany, Netherlands, Cyprus)
|
Operating
|
Natural gas
|
13.87 mmboe/yr
4/5
|
56.33 mmboe 1P
2/5
|
reserves 4.1 yrs
|
|
|
|
|
|
Oil
|
0.73 mmboe/yr
2/5
|
3 mmboe 1P
1/5
|
reserves 4.1 yrs
|
|
|
|
|
|
NGL
|
-
|
-
|
-
|
|
|
Gorgon-Jansz LNG
|
🇦🇺 Australia
Western Australia
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Kashagan
Ownership 16.8% WI
|
🇰🇿 Kazakhstan
Caspian Sea (Atyrau)
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Kearl
Ownership 71.0% WI
|
🇨🇦 Canada
Alberta
|
Operating
|
Bitumen
|
96.36 mmboe/yr
5/5
|
-
|
-
|
|
|
Nigeria Deepwater Blocks
|
🇳🇬 Nigeria
Offshore Nigeria
|
Operating
|
-
|
-
|
-
|
-
|
|
|
PNG LNG
Ownership 33.0% WI
|
🇵🇬 Papua New Guinea
Papua New Guinea
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Permian Basin
|
🇺🇸 United States
Texas and New Mexico
|
Operating
|
Oil equivalent (BOE)
|
584 mmboe/yr
5/5
|
-
|
-
|
|
|
Stabroek Block
|
🇬🇾 Guyana
Offshore Guyana
|
Operating
|
Oil
|
260.98 mmboe/yr
5/5
|
-
|
-
|
|
|
Syncrude
Ownership 25.0% WI
|
🇨🇦 Canada
Alberta
|
Operating
|
Synthetic crude
|
24.82 mmboe/yr
4/5
|
-
|
-
|
|
|
Tengiz / Korolev (Tengizchevroil)
Ownership 25.0% WI
|
🇰🇿 Kazakhstan
Atyrau
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Upper Zakum
|
🇦🇪 United Arab Emirates
Abu Dhabi
|
Operating
|
-
|
-
|
-
|
-
|
|
|
Rovuma LNG
Ownership 36.0% WI
|
🇲🇿 Mozambique
Offshore Mozambique (Area 4)
|
Development
Feasibility
|
-
|
-
|
-
|
-
|
|
|
Offshore Cyprus Exploration (Pegasus-1)
|
Cyprus
Offshore Cyprus
|
Exploration
|
-
|
-
|
-
|
-
|
|
|
|
|
|
Σ Oil
|
988.06 mmboe/yr
Est. revenue 51%
|
7 545 mmboe
|
-
|
|
|
|
|
|
Σ Natural gas
|
356.12 mmboe/yr
Est. revenue 4%
|
4 279 mmboe
|
-
|
|
|
|
|
|
Σ NGL
|
201.48 mmboe/yr
Est. revenue 5%
|
2 139 mmboe
|
-
|
|
|
|
|
|
Σ Oil equivalent (BOE)
|
584 mmboe/yr
Est. revenue 30%
|
-
|
-
|
|
|
|
|
|
Σ Bitumen
|
236.88 mmboe/yr
Est. revenue 7%
|
2 330 mmboe
|
-
|
|
|
|
|
|
Σ Synthetic crude
|
49.64 mmboe/yr
Est. revenue 3%
|
288 mmboe
|
-
|
★
Asia Upstream
🇦🇪 United Arab Emirates
Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Oil
162.43 mmboe/yr
5/5
2 960 mmboe 1P
5/5
reserves 18.2 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
58.89 mmboe/yr
5/5
366.5 mmboe 1P
4/5
reserves 6.2 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
10.22 mmboe/yr
5/5
67 mmboe 1P
4/5
reserves 6.6 yrs
★
Australia/Oceania Upstream
🇦🇺 Australia
Australia and Oceania
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Natural gas
78.05 mmboe/yr
5/5
951.67 mmboe 1P
4/5
reserves 12.2 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
6.57 mmboe/yr
3/5
60 mmboe 1P
3/5
reserves 9.1 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
2.56 mmboe/yr
4/5
8 mmboe 1P
2/5
reserves 3.1 yrs
★
Canada/Other Americas Upstream
🇨🇦 Canada
Canada and Other Americas
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Oil
139.06 mmboe/yr
5/5
1 195 mmboe 1P
5/5
reserves 8.6 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Bitumen
140.53 mmboe/yr
5/5
2 330 mmboe 1P
5/5
reserves 16.6 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Synthetic crude
24.82 mmboe/yr
4/5
288 mmboe 1P
4/5
reserves 11.6 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
1.64 mmboe/yr
2/5
87.83 mmboe 1P
3/5
reserves 25+ yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
0.36 mmboe/yr
2/5
1 mmboe 1P
1/5
reserves 2.7 yrs
★
United States Upstream
🇺🇸 United States
United States
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Oil
366.82 mmboe/yr
5/5
3 110 mmboe 1P
5/5
reserves 8.5 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
203.55 mmboe/yr
5/5
2 797.83 mmboe 1P
5/5
reserves 13.7 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
187.61 mmboe/yr
5/5
2 063 mmboe 1P
5/5
reserves 11 yrs
Africa Upstream
🇦🇴 Angola
Africa (Angola, Nigeria, Mozambique)
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Oil
51.47 mmboe/yr
4/5
217 mmboe 1P
4/5
reserves 4.2 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Natural gas
0.12 mmboe/yr
1/5
18.83 mmboe 1P
2/5
reserves 25+ yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
0.73 mmboe/yr
3/5
-
-
Angola Deepwater Blocks (incl. Block 15)
🇦🇴 Angola
Offshore Angola
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Bacalhau
🇧🇷 Brazil
Offshore Brazil
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Coral South FLNG
Ownership 25.0% WI
🇲🇿 Mozambique
Offshore Mozambique (Area 4)
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Europe Upstream
🇬🇧 United Kingdom
Europe (UK, Norway, Germany, Netherlands, Cyprus)
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Natural gas
13.87 mmboe/yr
4/5
56.33 mmboe 1P
2/5
reserves 4.1 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Oil
0.73 mmboe/yr
2/5
3 mmboe 1P
1/5
reserves 4.1 yrs
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
NGL
-
-
-
Gorgon-Jansz LNG
🇦🇺 Australia
Western Australia
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Kashagan
Ownership 16.8% WI
🇰🇿 Kazakhstan
Caspian Sea (Atyrau)
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Kearl
Ownership 71.0% WI
🇨🇦 Canada
Alberta
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Bitumen
96.36 mmboe/yr
5/5
-
-
Nigeria Deepwater Blocks
🇳🇬 Nigeria
Offshore Nigeria
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
PNG LNG
Ownership 33.0% WI
🇵🇬 Papua New Guinea
Papua New Guinea
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Permian Basin
🇺🇸 United States
Texas and New Mexico
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Oil equivalent (BOE)
584 mmboe/yr
5/5
-
-
Stabroek Block
🇬🇾 Guyana
Offshore Guyana
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Oil
260.98 mmboe/yr
5/5
-
-
Syncrude
Ownership 25.0% WI
🇨🇦 Canada
Alberta
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
Synthetic crude
24.82 mmboe/yr
4/5
-
-
Tengiz / Korolev (Tengizchevroil)
Ownership 25.0% WI
🇰🇿 Kazakhstan
Atyrau
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Upper Zakum
🇦🇪 United Arab Emirates
Abu Dhabi
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Operating
-
-
-
-
Rovuma LNG
Ownership 36.0% WI
🇲🇿 Mozambique
Offshore Mozambique (Area 4)
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Development
Feasibility
-
-
-
-
Offshore Cyprus Exploration (Pegasus-1)
Cyprus
Offshore Cyprus
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Exploration
-
-
-
-
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Σ Oil
988.06 mmboe/yr
Est. revenue 51%
7 545 mmboe
-
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Σ Natural gas
356.12 mmboe/yr
Est. revenue 4%
4 279 mmboe
-
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Σ NGL
201.48 mmboe/yr
Est. revenue 5%
2 139 mmboe
-
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Σ Oil equivalent (BOE)
584 mmboe/yr
Est. revenue 30%
-
-
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Σ Bitumen
236.88 mmboe/yr
Est. revenue 7%
2 330 mmboe
-
Status
Commodity
Production (rating)
Reserves & Resources (rating)
Estimated Lifetime
Σ Synthetic crude
49.64 mmboe/yr
Est. revenue 3%
288 mmboe
-
★
Asia Upstream
🇦🇪 United Arab Emirates
Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
Operating
Oil
162.43 mmboe/yr
5/5
2 960 mmboe 1P
5/5
reserves 18.2 yrs
Natural gas
58.89 mmboe/yr
5/5
366.5 mmboe 1P
4/5
reserves 6.2 yrs
NGL
10.22 mmboe/yr
5/5
67 mmboe 1P
4/5
reserves 6.6 yrs
★
Australia/Oceania Upstream
🇦🇺 Australia
Australia and Oceania
Operating
Natural gas
78.05 mmboe/yr
5/5
951.67 mmboe 1P
4/5
reserves 12.2 yrs
Oil
6.57 mmboe/yr
3/5
60 mmboe 1P
3/5
reserves 9.1 yrs
NGL
2.56 mmboe/yr
4/5
8 mmboe 1P
2/5
reserves 3.1 yrs
★
Canada/Other Americas Upstream
🇨🇦 Canada
Canada and Other Americas
Operating
Oil
139.06 mmboe/yr
5/5
1 195 mmboe 1P
5/5
reserves 8.6 yrs
Bitumen
140.53 mmboe/yr
5/5
2 330 mmboe 1P
5/5
reserves 16.6 yrs
Synthetic crude
24.82 mmboe/yr
4/5
288 mmboe 1P
4/5
reserves 11.6 yrs
Natural gas
1.64 mmboe/yr
2/5
87.83 mmboe 1P
3/5
reserves 25+ yrs
NGL
0.36 mmboe/yr
2/5
1 mmboe 1P
1/5
reserves 2.7 yrs
★
United States Upstream
🇺🇸 United States
United States
Operating
Oil
366.82 mmboe/yr
5/5
3 110 mmboe 1P
5/5
reserves 8.5 yrs
Natural gas
203.55 mmboe/yr
5/5
2 797.83 mmboe 1P
5/5
reserves 13.7 yrs
NGL
187.61 mmboe/yr
5/5
2 063 mmboe 1P
5/5
reserves 11 yrs
Africa Upstream
🇦🇴 Angola
Africa (Angola, Nigeria, Mozambique)
Operating
Oil
51.47 mmboe/yr
4/5
217 mmboe 1P
4/5
reserves 4.2 yrs
Natural gas
0.12 mmboe/yr
1/5
18.83 mmboe 1P
2/5
reserves 25+ yrs
NGL
0.73 mmboe/yr
3/5
-
-
Angola Deepwater Blocks (incl. Block 15)
🇦🇴 Angola
Offshore Angola
Operating
-
-
-
-
Bacalhau
🇧🇷 Brazil
Offshore Brazil
Operating
-
-
-
-
Coral South FLNG
Ownership 25.0% WI
🇲🇿 Mozambique
Offshore Mozambique (Area 4)
Operating
-
-
-
-
Europe Upstream
🇬🇧 United Kingdom
Europe (UK, Norway, Germany, Netherlands, Cyprus)
Operating
Natural gas
13.87 mmboe/yr
4/5
56.33 mmboe 1P
2/5
reserves 4.1 yrs
Oil
0.73 mmboe/yr
2/5
3 mmboe 1P
1/5
reserves 4.1 yrs
NGL
-
-
-
Gorgon-Jansz LNG
🇦🇺 Australia
Western Australia
Operating
-
-
-
-
Kashagan
Ownership 16.8% WI
🇰🇿 Kazakhstan
Caspian Sea (Atyrau)
Operating
-
-
-
-
Kearl
Ownership 71.0% WI
🇨🇦 Canada
Alberta
Operating
Bitumen
96.36 mmboe/yr
5/5
-
-
Nigeria Deepwater Blocks
🇳🇬 Nigeria
Offshore Nigeria
Operating
-
-
-
-
PNG LNG
Ownership 33.0% WI
🇵🇬 Papua New Guinea
Papua New Guinea
Operating
-
-
-
-
Permian Basin
🇺🇸 United States
Texas and New Mexico
Operating
Oil equivalent (BOE)
584 mmboe/yr
5/5
-
-
Stabroek Block
🇬🇾 Guyana
Offshore Guyana
Operating
Oil
260.98 mmboe/yr
5/5
-
-
Syncrude
Ownership 25.0% WI
🇨🇦 Canada
Alberta
Operating
Synthetic crude
24.82 mmboe/yr
4/5
-
-
Tengiz / Korolev (Tengizchevroil)
Ownership 25.0% WI
🇰🇿 Kazakhstan
Atyrau
Operating
-
-
-
-
Upper Zakum
🇦🇪 United Arab Emirates
Abu Dhabi
Operating
-
-
-
-
Rovuma LNG
Ownership 36.0% WI
🇲🇿 Mozambique
Offshore Mozambique (Area 4)
Development
Feasibility
-
-
-
-
Offshore Cyprus Exploration (Pegasus-1)
Cyprus
Offshore Cyprus
Exploration
-
-
-
-
Σ Oil
988.06 mmboe/yr
Est. revenue 51%
7 545 mmboe
-
Σ Natural gas
356.12 mmboe/yr
Est. revenue 4%
4 279 mmboe
-
Σ NGL
201.48 mmboe/yr
Est. revenue 5%
2 139 mmboe
-
Σ Oil equivalent (BOE)
584 mmboe/yr
Est. revenue 30%
-
-
Σ Bitumen
236.88 mmboe/yr
Est. revenue 7%
2 330 mmboe
-
Σ Synthetic crude
49.64 mmboe/yr
Est. revenue 3%
288 mmboe
-
Oil & Gas metrics · 21 projects — Assumptions & Disclaimers
- Petroleum reserves are reported under SPE-PRMS, NI 51-101, COGEH or SEC S-K 1200. The headline figure is 2P (Proved + Probable) when disclosed, falling back to 1P (Proved) for SEC-only filers; 3P is shown for transparency only.
- Pricing case. PRMS / NI 51-101 reserves are typically dual-reported under 'Forecast Prices & Costs' and 'Constant / SEC Prices & Costs'. Both cases are shown when disclosed; do not add them together.
- Development status. Petroleum reserves carry an orthogonal developed / undeveloped axis (PDP, PDNP, PUD). Where the source splits the reserve into these buckets we preserve the split.
- Reserves walk tables (if present) disaggregate the change in reserves into Opening balance, Extensions & discoveries, Revisions, Improved recovery, Purchases, Divestitures, Production, Conversion to developed and Closing balance, following NI 51-101 / SEC S-K 1200 reconciliation requirements.
- Contingent (1C/2C/3C) and Prospective (1U/2U/3U) resources are shown for transparency but do not feed the headline 2P metric and do not contribute to the USD value mix.
- BOE / Mcfe conversion uses a 6:1 thermal ratio unless the source declares otherwise. Thermal convenience only — not economic equivalence.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
Oil & Gas inventory & footprint · 9 projects
Multiple effective dates
| Asset | |||||||||
|---|---|---|---|---|---|---|---|---|---|
| Location | Status | Land (net acres) | Wellbore stock (net wells) | Drilling runway (net locations) | Breakeven & type curve | Drilling activity (latest FY) | Active stock (latest) | ||
|
★
|
Asia Upstream
|
🇦🇪 United Arab Emirates
Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
|
Operating
|
637k net acres · 66% developed
422k developed · 215k undeveloped
|
327 net producing
|
-
|
-
|
5 drilled
FY 2025
|
2 WIP
|
|
★
|
Australia/Oceania Upstream
|
🇦🇺 Australia
Australia and Oceania
|
Operating
|
2.70M net acres · 39% developed
1.04M developed · 1.66M undeveloped
|
46 net producing
|
-
|
-
|
1 drilled
FY 2025
|
1 WIP
|
|
★
|
Canada/Other Americas Upstream
|
🇨🇦 Canada
Canada and Other Americas
|
Operating
|
12.06M net acres · 11% developed
1.30M developed · 10.76M undeveloped
|
5 050 net producing
|
-
|
-
|
14 drilled
FY 2025
|
20 WIP
|
|
★
|
United States Upstream
|
🇺🇸 United States
United States
|
Operating
|
7.17M net acres · 71% developed
5.08M developed · 2.09M undeveloped
|
17.6k net producing
|
-
|
-
|
698 drilled
FY 2025
|
492 WIP
|
|
|
Africa Upstream
|
🇦🇴 Angola
Africa (Angola, Nigeria, Mozambique)
|
Operating
|
8.49M net acres · 5% developed
428k developed · 8.06M undeveloped
|
94 net producing
|
-
|
-
|
1 drilled
FY 2025
|
2 WIP
|
|
|
Europe Upstream
|
🇬🇧 United Kingdom
Europe (UK, Norway, Germany, Netherlands, Cyprus)
|
Operating
|
8.30M net acres · 7% developed
546k developed · 7.75M undeveloped
|
298 net producing
|
-
|
-
|
1 drilled
FY 2025
|
1 WIP
|
|
|
ExxonMobil Worldwide Upstream
|
🇺🇸 United States
|
Operating
|
-
|
-
|
-
|
-
|
733 drilled
FY 2025
|
518 WIP
|
|
|
Kearl
Ownership 71.0% WI
|
🇨🇦 Canada
Alberta
|
Operating
|
49k net acres
49k developed
|
-
|
-
|
-
|
-
|
-
|
|
|
Syncrude
Ownership 25.0% WI
|
🇨🇦 Canada
Alberta
|
Operating
|
55k net acres
55k developed
|
-
|
-
|
-
|
-
|
-
|
★
Asia Upstream
🇦🇪 United Arab Emirates
Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
637k net acres · 66% developed
422k developed · 215k undeveloped
327 net producing
-
-
5 drilled
FY 2025
2 WIP
★
Australia/Oceania Upstream
🇦🇺 Australia
Australia and Oceania
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
2.70M net acres · 39% developed
1.04M developed · 1.66M undeveloped
46 net producing
-
-
1 drilled
FY 2025
1 WIP
★
Canada/Other Americas Upstream
🇨🇦 Canada
Canada and Other Americas
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
12.06M net acres · 11% developed
1.30M developed · 10.76M undeveloped
5 050 net producing
-
-
14 drilled
FY 2025
20 WIP
★
United States Upstream
🇺🇸 United States
United States
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
7.17M net acres · 71% developed
5.08M developed · 2.09M undeveloped
17.6k net producing
-
-
698 drilled
FY 2025
492 WIP
Africa Upstream
🇦🇴 Angola
Africa (Angola, Nigeria, Mozambique)
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
8.49M net acres · 5% developed
428k developed · 8.06M undeveloped
94 net producing
-
-
1 drilled
FY 2025
2 WIP
Europe Upstream
🇬🇧 United Kingdom
Europe (UK, Norway, Germany, Netherlands, Cyprus)
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
8.30M net acres · 7% developed
546k developed · 7.75M undeveloped
298 net producing
-
-
1 drilled
FY 2025
1 WIP
ExxonMobil Worldwide Upstream
🇺🇸 United States
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
-
-
-
-
733 drilled
FY 2025
518 WIP
Kearl
Ownership 71.0% WI
🇨🇦 Canada
Alberta
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
49k net acres
49k developed
-
-
-
-
-
Syncrude
Ownership 25.0% WI
🇨🇦 Canada
Alberta
Status
Land (net acres)
Wellbore stock (net wells)
Drilling runway (net locations)
Breakeven & type curve
Drilling activity (latest FY)
Active stock (latest)
Operating
55k net acres
55k developed
-
-
-
-
-
★
Asia Upstream
🇦🇪 United Arab Emirates
Asia (UAE, Qatar, Kazakhstan, Iraq, Malaysia, Indonesia)
Operating
637k net acres · 66% developed
422k developed · 215k undeveloped
327 net producing
-
-
5 drilled
FY 2025
2 WIP
★
Australia/Oceania Upstream
🇦🇺 Australia
Australia and Oceania
Operating
2.70M net acres · 39% developed
1.04M developed · 1.66M undeveloped
46 net producing
-
-
1 drilled
FY 2025
1 WIP
★
Canada/Other Americas Upstream
🇨🇦 Canada
Canada and Other Americas
Operating
12.06M net acres · 11% developed
1.30M developed · 10.76M undeveloped
5 050 net producing
-
-
14 drilled
FY 2025
20 WIP
★
United States Upstream
🇺🇸 United States
United States
Operating
7.17M net acres · 71% developed
5.08M developed · 2.09M undeveloped
17.6k net producing
-
-
698 drilled
FY 2025
492 WIP
Africa Upstream
🇦🇴 Angola
Africa (Angola, Nigeria, Mozambique)
Operating
8.49M net acres · 5% developed
428k developed · 8.06M undeveloped
94 net producing
-
-
1 drilled
FY 2025
2 WIP
Europe Upstream
🇬🇧 United Kingdom
Europe (UK, Norway, Germany, Netherlands, Cyprus)
Operating
8.30M net acres · 7% developed
546k developed · 7.75M undeveloped
298 net producing
-
-
1 drilled
FY 2025
1 WIP
ExxonMobil Worldwide Upstream
🇺🇸 United States
Operating
-
-
-
-
733 drilled
FY 2025
518 WIP
Kearl
Ownership 71.0% WI
🇨🇦 Canada
Alberta
Operating
49k net acres
49k developed
-
-
-
-
-
Syncrude
Ownership 25.0% WI
🇨🇦 Canada
Alberta
Operating
55k net acres
55k developed
-
-
-
-
-
Oil & Gas inventory & footprint · 9 projects — Assumptions & Disclaimers
- Grain. One row per asset (not per commodity). Per-commodity reserves and production stay on the Oil & Gas table immediately above; this section answers the orthogonal question of land, wellbore stock, drilling runway and recent activity.
- Rail. All counts and acreages are NET (working-interest share) — the investor's actual exposure, not the operator's gross filing. Where a source only publishes gross figures, the cell falls back to '–'.
- Acres. Developed + undeveloped net acres at the latest effective_date; total net acres and the developed share (% of total) are on the first line, with developed and undeveloped magnitudes on the second line.
- Wellbore stock. Latest producing_wells_net is the headline; non_producing_wells_net (shut-in, suspended, behind-pipe) is added as '+ N non-producing' when the filer separates them.
- Drilling runway. 'Net locations' is management's headline identified-inventory count at the disclosed breakeven. 'Booked PUD' is the subset already booked as Proved Undeveloped reserves on the Oil & Gas table above; the remainder is the 'shadow inventory' — economic at the stated breakeven but excluded from booked reserves by the SEC five-year PUD rule, trailing-12-month pricing or the reasonable-certainty standard.
- Breakeven & type curve. Breakeven price defaults to USD per bbl WTI; non-WTI / non-USD benchmarks are echoed inline. EUR per well is taken as published; do not sum across assets with different unit families (mboe / mmboe / mbbl / mmbbl / bcf / tcf).
- Activity. Flow rows (wells drilled, wells completed) use the latest period_year on the latest period_type. Stock rows (DUC count, rigs running, completion crews, wells in progress) use the latest effective_date. A blank cell means the company did not disclose that activity_kind.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
Processing facilities · 16 projects
As at 31 December 2025
| Facility | |||||
|---|---|---|---|---|---|
| Location | Status | Feedstock | Capacity | ||
|
|
Terminals & LNG
|
|
|
|
|
|
|
Qatar LNG (North Field)
|
🇶🇦 Qatar
Qatar
|
Operating
|
Natural gas
|
3.4 bcf/Per Day
Nameplate
|
|
|
Golden Pass LNG
Ownership 30.0% WI
|
🇺🇸 United States
Texas (Sabine Pass)
|
Construction
|
Natural gas
implied
|
-
|
|
|
Other
|
|
|
|
|
|
|
Beaumont Refining & Chemical Complex
|
🇺🇸 United States
Texas
|
Operating
|
Oil
|
612 mbbl/Per Day
Nameplate
|
|
|
Singapore Refining & Chemical Complex
|
🇸🇬 Singapore
Jurong/Singapore
|
Operating
|
Oil
|
592 mbbl/Per Day
Nameplate
|
|
|
Baytown Refining & Chemical Complex
|
🇺🇸 United States
Texas
|
Operating
|
Oil
|
565 mbbl/Per Day
Nameplate
|
|
|
Baton Rouge Refining & Chemical Complex
|
🇺🇸 United States
Louisiana
|
Operating
|
Oil
|
523 mbbl/Per Day
Nameplate
|
|
|
Antwerp Refinery
|
🇧🇪 Belgium
Antwerp
|
Operating
|
Oil
|
318 mbbl/Per Day
Nameplate
|
|
|
Joliet Refinery
|
🇺🇸 United States
Illinois
|
Operating
|
Oil
|
267 mbbl/Per Day
Nameplate
|
|
|
Fawley Refining & Chemical Complex
|
🇬🇧 United Kingdom
Hampshire
|
Operating
|
Oil
|
265 mbbl/Per Day
Nameplate
|
|
|
Yanbu Refinery (SAMREF)
Ownership 50.0% WI
|
🇸🇦 Saudi Arabia
Yanbu
|
Operating
|
Oil
|
200 mbbl/Per Day
Nameplate
|
|
|
Strathcona Refinery
Ownership 69.6% WI
|
🇨🇦 Canada
Alberta
|
Operating
|
Oil
|
197 mbbl/Per Day
Nameplate
|
|
|
Rotterdam Refinery
|
🇳🇱 Netherlands
Rotterdam
|
Operating
|
Oil
|
192 mbbl/Per Day
Nameplate
|
|
|
Sarnia Refining & Chemical Complex
Ownership 69.6% WI
|
🇨🇦 Canada
Ontario
|
Operating
|
Oil
|
124 mbbl/Per Day
Nameplate
|
|
|
Nanticoke Refinery
Ownership 69.6% WI
|
🇨🇦 Canada
Ontario
|
Operating
|
Oil
|
113 mbbl/Per Day
Nameplate
|
|
|
Karlsruhe Refinery
Ownership 25.0% WI
|
🇩🇪 Germany
Baden-Wuerttemberg
|
Operating
|
Oil
|
78 mbbl/Per Day
Nameplate
|
|
|
Fujian Refining & Petrochemical
Ownership 25.0% WI
|
🇨🇳 China
Fujian
|
Operating
|
Oil
|
67 mbbl/Per Day
Nameplate
|
Terminals & LNG
Status
Feedstock
Capacity
Qatar LNG (North Field)
🇶🇦 Qatar
Qatar
Status
Feedstock
Capacity
Operating
Natural gas
3.4 bcf/Per Day
Nameplate
Golden Pass LNG
Ownership 30.0% WI
🇺🇸 United States
Texas (Sabine Pass)
Status
Feedstock
Capacity
Construction
Natural gas
implied
-
Other
Status
Feedstock
Capacity
Beaumont Refining & Chemical Complex
🇺🇸 United States
Texas
Status
Feedstock
Capacity
Operating
Oil
612 mbbl/Per Day
Nameplate
Singapore Refining & Chemical Complex
🇸🇬 Singapore
Jurong/Singapore
Status
Feedstock
Capacity
Operating
Oil
592 mbbl/Per Day
Nameplate
Baytown Refining & Chemical Complex
🇺🇸 United States
Texas
Status
Feedstock
Capacity
Operating
Oil
565 mbbl/Per Day
Nameplate
Baton Rouge Refining & Chemical Complex
🇺🇸 United States
Louisiana
Status
Feedstock
Capacity
Operating
Oil
523 mbbl/Per Day
Nameplate
Antwerp Refinery
🇧🇪 Belgium
Antwerp
Status
Feedstock
Capacity
Operating
Oil
318 mbbl/Per Day
Nameplate
Joliet Refinery
🇺🇸 United States
Illinois
Status
Feedstock
Capacity
Operating
Oil
267 mbbl/Per Day
Nameplate
Fawley Refining & Chemical Complex
🇬🇧 United Kingdom
Hampshire
Status
Feedstock
Capacity
Operating
Oil
265 mbbl/Per Day
Nameplate
Yanbu Refinery (SAMREF)
Ownership 50.0% WI
🇸🇦 Saudi Arabia
Yanbu
Status
Feedstock
Capacity
Operating
Oil
200 mbbl/Per Day
Nameplate
Strathcona Refinery
Ownership 69.6% WI
🇨🇦 Canada
Alberta
Status
Feedstock
Capacity
Operating
Oil
197 mbbl/Per Day
Nameplate
Rotterdam Refinery
🇳🇱 Netherlands
Rotterdam
Status
Feedstock
Capacity
Operating
Oil
192 mbbl/Per Day
Nameplate
Sarnia Refining & Chemical Complex
Ownership 69.6% WI
🇨🇦 Canada
Ontario
Status
Feedstock
Capacity
Operating
Oil
124 mbbl/Per Day
Nameplate
Nanticoke Refinery
Ownership 69.6% WI
🇨🇦 Canada
Ontario
Status
Feedstock
Capacity
Operating
Oil
113 mbbl/Per Day
Nameplate
Karlsruhe Refinery
Ownership 25.0% WI
🇩🇪 Germany
Baden-Wuerttemberg
Status
Feedstock
Capacity
Operating
Oil
78 mbbl/Per Day
Nameplate
Fujian Refining & Petrochemical
Ownership 25.0% WI
🇨🇳 China
Fujian
Status
Feedstock
Capacity
Operating
Oil
67 mbbl/Per Day
Nameplate
Terminals & LNG
Qatar LNG (North Field)
🇶🇦 Qatar
Qatar
Operating
Natural gas
3.4 bcf/Per Day
Nameplate
Golden Pass LNG
Ownership 30.0% WI
🇺🇸 United States
Texas (Sabine Pass)
Construction
Natural gas
implied
-
Other
Beaumont Refining & Chemical Complex
🇺🇸 United States
Texas
Operating
Oil
612 mbbl/Per Day
Nameplate
Singapore Refining & Chemical Complex
🇸🇬 Singapore
Jurong/Singapore
Operating
Oil
592 mbbl/Per Day
Nameplate
Baytown Refining & Chemical Complex
🇺🇸 United States
Texas
Operating
Oil
565 mbbl/Per Day
Nameplate
Baton Rouge Refining & Chemical Complex
🇺🇸 United States
Louisiana
Operating
Oil
523 mbbl/Per Day
Nameplate
Antwerp Refinery
🇧🇪 Belgium
Antwerp
Operating
Oil
318 mbbl/Per Day
Nameplate
Joliet Refinery
🇺🇸 United States
Illinois
Operating
Oil
267 mbbl/Per Day
Nameplate
Fawley Refining & Chemical Complex
🇬🇧 United Kingdom
Hampshire
Operating
Oil
265 mbbl/Per Day
Nameplate
Yanbu Refinery (SAMREF)
Ownership 50.0% WI
🇸🇦 Saudi Arabia
Yanbu
Operating
Oil
200 mbbl/Per Day
Nameplate
Strathcona Refinery
Ownership 69.6% WI
🇨🇦 Canada
Alberta
Operating
Oil
197 mbbl/Per Day
Nameplate
Rotterdam Refinery
🇳🇱 Netherlands
Rotterdam
Operating
Oil
192 mbbl/Per Day
Nameplate
Sarnia Refining & Chemical Complex
Ownership 69.6% WI
🇨🇦 Canada
Ontario
Operating
Oil
124 mbbl/Per Day
Nameplate
Nanticoke Refinery
Ownership 69.6% WI
🇨🇦 Canada
Ontario
Operating
Oil
113 mbbl/Per Day
Nameplate
Karlsruhe Refinery
Ownership 25.0% WI
🇩🇪 Germany
Baden-Wuerttemberg
Operating
Oil
78 mbbl/Per Day
Nameplate
Fujian Refining & Petrochemical
Ownership 25.0% WI
🇨🇳 China
Fujian
Operating
Oil
67 mbbl/Per Day
Nameplate
Processing facilities · 16 projects — Assumptions & Disclaimers
- Capacity is the nameplate or licensed capacity from the project record, not period throughput.
- Throughput volumes (annual barrels processed, tonnes milled, Mcf moved) are modelled as production on the same facility and are surfaced under the Production / lifetime columns where present.
- Feedstock is sourced from resource rows tagged for the facility.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
Reserves & resources — detail
As at 31 December 2025
| Project | |||
|---|---|---|---|
| Commodity | 1P (share %) | Total (share %) | |
|
Asia Upstream (Play)
|
Oil
|
2 960 mmbbl (39%)
|
2 960 mmboe (39%)
|
|
Asia Upstream (Play)
|
Natural gas
|
2 199 bcf (9%)
|
366.5 mmboe (9%)
|
|
Asia Upstream (Play)
|
NGL
|
67 mmbbl (3%)
|
67 mmboe (3%)
|
|
Canada/Other Americas Upstream (Play)
|
Oil
|
1 195 mmbbl (16%)
|
1 195 mmboe (16%)
|
|
Canada/Other Americas Upstream (Play)
|
Natural gas
|
527 bcf (2%)
|
87.83 mmboe (2%)
|
|
Canada/Other Americas Upstream (Play)
|
NGL
|
1 mmbbl (<1%)
|
1 mmboe (<1%)
|
|
Canada/Other Americas Upstream (Play)
|
Bitumen
|
2 330 mmbbl
|
2 330 mmboe
|
|
Canada/Other Americas Upstream (Play)
|
Synthetic crude
|
288 mmbbl
|
288 mmboe
|
|
United States Upstream (Play)
|
Oil
|
3 110 mmbbl (41%)
|
3 110 mmboe (41%)
|
|
United States Upstream (Play)
|
Natural gas
|
16 787 bcf (65%)
|
2 797.83 mmboe (65%)
|
|
United States Upstream (Play)
|
NGL
|
2 063 mmbbl (96%)
|
2 063 mmboe (96%)
|
|
Australia/Oceania Upstream (Play)
|
Oil
|
60 mmbbl (<1%)
|
60 mmboe (<1%)
|
|
Australia/Oceania Upstream (Play)
|
Natural gas
|
5 710 bcf (22%)
|
951.67 mmboe (22%)
|
|
Australia/Oceania Upstream (Play)
|
NGL
|
8 mmbbl (<1%)
|
8 mmboe (<1%)
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Oil
|
8 187 mmbbl
|
8 187 mmboe
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Natural gas
|
36 408 bcf
|
6 068 mmboe
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
NGL
|
2 437 mmbbl
|
2 437 mmboe
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Bitumen
|
2 330 mmbbl
|
2 330 mmboe
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Synthetic crude
|
288 mmbbl
|
288 mmboe
|
|
Africa Upstream (Play)
|
Oil
|
217 mmbbl (3%)
|
217 mmboe (3%)
|
|
Africa Upstream (Play)
|
Natural gas
|
113 bcf (<1%)
|
18.83 mmboe (<1%)
|
|
Europe Upstream (Play)
|
Oil
|
3 mmbbl (<1%)
|
3 mmboe (<1%)
|
|
Europe Upstream (Play)
|
Natural gas
|
338 bcf (1%)
|
56.33 mmboe (1%)
|
Asia Upstream (Play)
Commodity
Oil
1P (share %)
2 960 mmbbl (39%)
Total (share %)
2 960 mmboe (39%)
Asia Upstream (Play)
Commodity
Natural gas
1P (share %)
2 199 bcf (9%)
Total (share %)
366.5 mmboe (9%)
Asia Upstream (Play)
Commodity
NGL
1P (share %)
67 mmbbl (3%)
Total (share %)
67 mmboe (3%)
Canada/Other Americas Upstream (Play)
Commodity
Oil
1P (share %)
1 195 mmbbl (16%)
Total (share %)
1 195 mmboe (16%)
Canada/Other Americas Upstream (Play)
Commodity
Natural gas
1P (share %)
527 bcf (2%)
Total (share %)
87.83 mmboe (2%)
Canada/Other Americas Upstream (Play)
Commodity
NGL
1P (share %)
1 mmbbl (<1%)
Total (share %)
1 mmboe (<1%)
Canada/Other Americas Upstream (Play)
Commodity
Bitumen
1P (share %)
2 330 mmbbl
Total (share %)
2 330 mmboe
Canada/Other Americas Upstream (Play)
Commodity
Synthetic crude
1P (share %)
288 mmbbl
Total (share %)
288 mmboe
United States Upstream (Play)
Commodity
Oil
1P (share %)
3 110 mmbbl (41%)
Total (share %)
3 110 mmboe (41%)
United States Upstream (Play)
Commodity
Natural gas
1P (share %)
16 787 bcf (65%)
Total (share %)
2 797.83 mmboe (65%)
United States Upstream (Play)
Commodity
NGL
1P (share %)
2 063 mmbbl (96%)
Total (share %)
2 063 mmboe (96%)
Australia/Oceania Upstream (Play)
Commodity
Oil
1P (share %)
60 mmbbl (<1%)
Total (share %)
60 mmboe (<1%)
Australia/Oceania Upstream (Play)
Commodity
Natural gas
1P (share %)
5 710 bcf (22%)
Total (share %)
951.67 mmboe (22%)
Australia/Oceania Upstream (Play)
Commodity
NGL
1P (share %)
8 mmbbl (<1%)
Total (share %)
8 mmboe (<1%)
ExxonMobil Worldwide Upstream (Portfolio)
Commodity
Oil
1P (share %)
8 187 mmbbl
Total (share %)
8 187 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
Commodity
Natural gas
1P (share %)
36 408 bcf
Total (share %)
6 068 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
Commodity
NGL
1P (share %)
2 437 mmbbl
Total (share %)
2 437 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
Commodity
Bitumen
1P (share %)
2 330 mmbbl
Total (share %)
2 330 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
Commodity
Synthetic crude
1P (share %)
288 mmbbl
Total (share %)
288 mmboe
Africa Upstream (Play)
Commodity
Oil
1P (share %)
217 mmbbl (3%)
Total (share %)
217 mmboe (3%)
Africa Upstream (Play)
Commodity
Natural gas
1P (share %)
113 bcf (<1%)
Total (share %)
18.83 mmboe (<1%)
Europe Upstream (Play)
Commodity
Oil
1P (share %)
3 mmbbl (<1%)
Total (share %)
3 mmboe (<1%)
Europe Upstream (Play)
Commodity
Natural gas
1P (share %)
338 bcf (1%)
Total (share %)
56.33 mmboe (1%)
Asia Upstream (Play)
Oil
2 960 mmbbl (39%)
2 960 mmboe (39%)
Asia Upstream (Play)
Natural gas
2 199 bcf (9%)
366.5 mmboe (9%)
Asia Upstream (Play)
NGL
67 mmbbl (3%)
67 mmboe (3%)
Canada/Other Americas Upstream (Play)
Oil
1 195 mmbbl (16%)
1 195 mmboe (16%)
Canada/Other Americas Upstream (Play)
Natural gas
527 bcf (2%)
87.83 mmboe (2%)
Canada/Other Americas Upstream (Play)
NGL
1 mmbbl (<1%)
1 mmboe (<1%)
Canada/Other Americas Upstream (Play)
Bitumen
2 330 mmbbl
2 330 mmboe
Canada/Other Americas Upstream (Play)
Synthetic crude
288 mmbbl
288 mmboe
United States Upstream (Play)
Oil
3 110 mmbbl (41%)
3 110 mmboe (41%)
United States Upstream (Play)
Natural gas
16 787 bcf (65%)
2 797.83 mmboe (65%)
United States Upstream (Play)
NGL
2 063 mmbbl (96%)
2 063 mmboe (96%)
Australia/Oceania Upstream (Play)
Oil
60 mmbbl (<1%)
60 mmboe (<1%)
Australia/Oceania Upstream (Play)
Natural gas
5 710 bcf (22%)
951.67 mmboe (22%)
Australia/Oceania Upstream (Play)
NGL
8 mmbbl (<1%)
8 mmboe (<1%)
ExxonMobil Worldwide Upstream (Portfolio)
Oil
8 187 mmbbl
8 187 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
36 408 bcf
6 068 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
NGL
2 437 mmbbl
2 437 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
Bitumen
2 330 mmbbl
2 330 mmboe
ExxonMobil Worldwide Upstream (Portfolio)
Synthetic crude
288 mmbbl
288 mmboe
Africa Upstream (Play)
Oil
217 mmbbl (3%)
217 mmboe (3%)
Africa Upstream (Play)
Natural gas
113 bcf (<1%)
18.83 mmboe (<1%)
Europe Upstream (Play)
Oil
3 mmbbl (<1%)
3 mmboe (<1%)
Europe Upstream (Play)
Natural gas
338 bcf (1%)
56.33 mmboe (1%)
Reserves & resources — detail — Assumptions & Disclaimers
- Attributable. Per-category cells follow METALPILOT §6 (latest per project × commodity × category). Headline reserve base appears in Asset quality / mix.
- Inferred is shown for context and excluded from headline totals. Petroleum rows may be deduped on development_status.
Reserves walk · Gross (disclosed)
| Project | Commodity | ||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Category / dev_status | Reporting basis | Pricing case | Opening | + Ext. & disc. | + Revisions | + Improved rec. | + Purchases | Combined added | − Divestitures | − Production | Combined used | ± Conv. to developed | Net change | Closing | Balance check | ||
|
2023
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asia Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 794 mmboe
|
0
|
30 mmboe
|
0
|
0
|
30 mmboe
|
−4 mmboe
|
−153 mmboe
|
−157 mmboe
|
0
|
187 mmboe
|
2 667 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
66 mmboe
|
0
|
3 mmboe
|
0
|
0
|
3 mmboe
|
0
|
−8 mmboe
|
−8 mmboe
|
0
|
11 mmboe
|
61 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
945 mmboe
|
105 mmboe
|
32 mmboe
|
0
|
0
|
137 mmboe
|
0
|
−88 mmboe
|
−88 mmboe
|
0
|
225 mmboe
|
994 mmboe
|
✓
|
|
United States Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 204 mmboe
|
355 mmboe
|
−398 mmboe
|
0
|
156 mmboe
|
113 mmboe
|
−12 mmboe
|
−203 mmboe
|
−215 mmboe
|
0
|
328 mmboe
|
2 102 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
271 mmboe
|
0
|
31 mmboe
|
0
|
0
|
31 mmboe
|
0
|
−78 mmboe
|
−78 mmboe
|
0
|
109 mmboe
|
224 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
5 mmboe
|
0
|
0
|
0
|
0
|
0
|
0
|
−1 mmboe
|
−1 mmboe
|
0
|
1 mmboe
|
4 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Oil
|
1P
|
Net
|
Sec
|
6 285 mmboe
|
460 mmboe
|
−302 mmboe
|
0
|
156 mmboe
|
314 mmboe
|
−16 mmboe
|
−531 mmboe
|
−547 mmboe
|
0
|
861 mmboe
|
6 052 mmboe
|
✓
|
|
Asia Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
510.17 mmboe
|
0
|
20.17 mmboe
|
0
|
0
|
20.17 mmboe
|
−1.5 mmboe
|
−63.17 mmboe
|
−64.67 mmboe
|
0
|
84.83 mmboe
|
465.67 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
1 001.33 mmboe
|
0
|
56.5 mmboe
|
0
|
0
|
56.5 mmboe
|
0
|
−81.5 mmboe
|
−81.5 mmboe
|
0
|
138 mmboe
|
976.33 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
118 mmboe
|
11.17 mmboe
|
−33.5 mmboe
|
0
|
0
|
−22.33 mmboe
|
−0.17 mmboe
|
−8.83 mmboe
|
−9 mmboe
|
0
|
−13.33 mmboe
|
86.67 mmboe
|
✓
|
|
United States Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
2 274.17 mmboe
|
321.67 mmboe
|
−324.17 mmboe
|
0
|
1.17 mmboe
|
−1.33 mmboe
|
−69.5 mmboe
|
−159.5 mmboe
|
−229 mmboe
|
0
|
227.67 mmboe
|
2 043.83 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
52 mmboe
|
0
|
−8.17 mmboe
|
0
|
0
|
−8.17 mmboe
|
0
|
−7.17 mmboe
|
−7.17 mmboe
|
0
|
−1 mmboe
|
36.67 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
68.83 mmboe
|
0
|
−0.5 mmboe
|
0
|
0
|
−0.5 mmboe
|
0
|
−17.17 mmboe
|
−17.17 mmboe
|
0
|
16.67 mmboe
|
51.17 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Natural gas
|
1P
|
Net
|
Sec
|
4 024.5 mmboe
|
332.83 mmboe
|
−289.67 mmboe
|
0
|
1.17 mmboe
|
44.33 mmboe
|
−71.17 mmboe
|
−337.33 mmboe
|
−408.5 mmboe
|
0
|
452.83 mmboe
|
3 660.33 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
NGL
|
1P
|
Net
|
Sec
|
1 176 mmboe
|
272 mmboe
|
−110 mmboe
|
0
|
2 mmboe
|
164 mmboe
|
−5 mmboe
|
−99 mmboe
|
−104 mmboe
|
0
|
268 mmboe
|
1 236 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Bitumen
|
1P
|
Net
|
Sec
|
2 420 mmboe
|
0
|
123 mmboe
|
0
|
0
|
123 mmboe
|
0
|
−129 mmboe
|
−129 mmboe
|
0
|
252 mmboe
|
2 414 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Synthetic crude
|
1P
|
Net
|
Sec
|
353 mmboe
|
0
|
26 mmboe
|
0
|
0
|
26 mmboe
|
0
|
−25 mmboe
|
−25 mmboe
|
0
|
51 mmboe
|
354 mmboe
|
✓
|
|
2024
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asia Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 667 mmboe
|
0
|
603 mmboe
|
0
|
0
|
603 mmboe
|
−7 mmboe
|
−154 mmboe
|
−161 mmboe
|
0
|
764 mmboe
|
3 109 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
61 mmboe
|
0
|
1 mmboe
|
0
|
0
|
1 mmboe
|
0
|
−7 mmboe
|
−7 mmboe
|
0
|
8 mmboe
|
55 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
994 mmboe
|
138 mmboe
|
116 mmboe
|
0
|
0
|
254 mmboe
|
−4 mmboe
|
−126 mmboe
|
−130 mmboe
|
0
|
384 mmboe
|
1 118 mmboe
|
✓
|
|
United States Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
2 102 mmboe
|
804 mmboe
|
−176 mmboe
|
0
|
877 mmboe
|
1 505 mmboe
|
−18 mmboe
|
−316 mmboe
|
−334 mmboe
|
0
|
1 839 mmboe
|
3 273 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
224 mmboe
|
25 mmboe
|
62 mmboe
|
0
|
0
|
87 mmboe
|
−45 mmboe
|
−75 mmboe
|
−120 mmboe
|
0
|
207 mmboe
|
191 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
4 mmboe
|
0
|
0
|
0
|
0
|
0
|
0
|
−1 mmboe
|
−1 mmboe
|
0
|
1 mmboe
|
3 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Oil
|
1P
|
Net
|
Sec
|
6 052 mmboe
|
967 mmboe
|
606 mmboe
|
0
|
877 mmboe
|
2 450 mmboe
|
−74 mmboe
|
−679 mmboe
|
−753 mmboe
|
0
|
3 203 mmboe
|
7 749 mmboe
|
✓
|
|
Asia Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
465.67 mmboe
|
0
|
20.67 mmboe
|
0
|
0
|
20.67 mmboe
|
−0.83 mmboe
|
−62.17 mmboe
|
−63 mmboe
|
0
|
83.67 mmboe
|
423.33 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
976.33 mmboe
|
0.17 mmboe
|
16.17 mmboe
|
0
|
0
|
16.33 mmboe
|
0
|
−79.5 mmboe
|
−79.5 mmboe
|
0
|
95.83 mmboe
|
913.17 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
86.67 mmboe
|
11.33 mmboe
|
3.67 mmboe
|
0
|
0
|
15 mmboe
|
−1.67 mmboe
|
−9.83 mmboe
|
−11.5 mmboe
|
0
|
26.5 mmboe
|
90.17 mmboe
|
✓
|
|
United States Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
2 043.83 mmboe
|
447.17 mmboe
|
−151.83 mmboe
|
0
|
674 mmboe
|
969.33 mmboe
|
−13.83 mmboe
|
−192.17 mmboe
|
−206 mmboe
|
0
|
1 175.33 mmboe
|
2 807.17 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
36.67 mmboe
|
0.33 mmboe
|
4 mmboe
|
0
|
0
|
4.33 mmboe
|
−17.5 mmboe
|
−7.67 mmboe
|
−25.17 mmboe
|
0
|
29.5 mmboe
|
15.83 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
51.17 mmboe
|
0
|
33 mmboe
|
0
|
0
|
33 mmboe
|
0
|
−16.5 mmboe
|
−16.5 mmboe
|
0
|
49.5 mmboe
|
67.67 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Natural gas
|
1P
|
Net
|
Sec
|
3 660.33 mmboe
|
459 mmboe
|
−74.33 mmboe
|
0
|
674 mmboe
|
1 058.67 mmboe
|
−33.83 mmboe
|
−367.83 mmboe
|
−401.67 mmboe
|
0
|
1 460.33 mmboe
|
4 317.33 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
NGL
|
1P
|
Net
|
Sec
|
1 236 mmboe
|
489 mmboe
|
−128 mmboe
|
0
|
730 mmboe
|
1 091 mmboe
|
−15 mmboe
|
−148 mmboe
|
−163 mmboe
|
0
|
1 254 mmboe
|
2 164 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Bitumen
|
1P
|
Net
|
Sec
|
2 414 mmboe
|
0
|
152 mmboe
|
0
|
0
|
152 mmboe
|
0
|
−137 mmboe
|
−137 mmboe
|
0
|
289 mmboe
|
2 429 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Synthetic crude
|
1P
|
Net
|
Sec
|
354 mmboe
|
0
|
−35 mmboe
|
0
|
0
|
−35 mmboe
|
0
|
−23 mmboe
|
−23 mmboe
|
0
|
−12 mmboe
|
296 mmboe
|
✓
|
|
2025
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asia Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
3 109 mmboe
|
0
|
13 mmboe
|
0
|
0
|
13 mmboe
|
0
|
−162 mmboe
|
−162 mmboe
|
0
|
175 mmboe
|
2 960 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
55 mmboe
|
6 mmboe
|
6 mmboe
|
0
|
0
|
12 mmboe
|
0
|
−7 mmboe
|
−7 mmboe
|
0
|
19 mmboe
|
60 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
1 118 mmboe
|
92 mmboe
|
124 mmboe
|
0
|
0
|
216 mmboe
|
0
|
−139 mmboe
|
−139 mmboe
|
0
|
355 mmboe
|
1 195 mmboe
|
✓
|
|
United States Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
3 273 mmboe
|
890 mmboe
|
−652 mmboe
|
0
|
38 mmboe
|
276 mmboe
|
−72 mmboe
|
−367 mmboe
|
−439 mmboe
|
0
|
715 mmboe
|
3 110 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
191 mmboe
|
0
|
78 mmboe
|
0
|
0
|
78 mmboe
|
0
|
−52 mmboe
|
−52 mmboe
|
0
|
130 mmboe
|
217 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Oil
|
1P
|
Net
|
Sec
|
3 mmboe
|
0
|
1 mmboe
|
0
|
0
|
1 mmboe
|
0
|
−1 mmboe
|
−1 mmboe
|
0
|
2 mmboe
|
3 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Oil
|
1P
|
Net
|
Sec
|
7 749 mmboe
|
988 mmboe
|
−430 mmboe
|
0
|
38 mmboe
|
596 mmboe
|
−72 mmboe
|
−728 mmboe
|
−800 mmboe
|
0
|
1 396 mmboe
|
7 545 mmboe
|
✓
|
|
Asia Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
423.33 mmboe
|
0
|
11.33 mmboe
|
0
|
0
|
11.33 mmboe
|
−2.33 mmboe
|
−65.83 mmboe
|
−68.17 mmboe
|
0
|
79.5 mmboe
|
366.5 mmboe
|
✓
|
|
Australia/Oceania Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
913.17 mmboe
|
80.83 mmboe
|
38 mmboe
|
0
|
0
|
118.83 mmboe
|
0
|
−80.33 mmboe
|
−80.33 mmboe
|
0
|
199.17 mmboe
|
951.67 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
90.17 mmboe
|
4.33 mmboe
|
3.5 mmboe
|
0
|
0
|
7.83 mmboe
|
−4.67 mmboe
|
−5.5 mmboe
|
−10.17 mmboe
|
0
|
18 mmboe
|
87.83 mmboe
|
✓
|
|
United States Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
2 807.17 mmboe
|
461.5 mmboe
|
−247 mmboe
|
0
|
39 mmboe
|
253.5 mmboe
|
−41.33 mmboe
|
−221.5 mmboe
|
−262.83 mmboe
|
0
|
516.33 mmboe
|
2 797.83 mmboe
|
✓
|
|
Africa Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
15.83 mmboe
|
0
|
5.67 mmboe
|
0
|
0
|
5.67 mmboe
|
0
|
−2.67 mmboe
|
−2.67 mmboe
|
0
|
8.33 mmboe
|
18.83 mmboe
|
✓
|
|
Europe Upstream (Play)
|
Natural gas
|
1P
|
Net
|
Sec
|
67.67 mmboe
|
0
|
3.5 mmboe
|
0
|
0
|
3.5 mmboe
|
0
|
−14.83 mmboe
|
−14.83 mmboe
|
0
|
18.33 mmboe
|
56.33 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
Natural gas
|
1P
|
Net
|
Sec
|
4 317.33 mmboe
|
546.67 mmboe
|
−185 mmboe
|
0
|
39 mmboe
|
400.67 mmboe
|
−48.33 mmboe
|
−390.67 mmboe
|
−439 mmboe
|
0
|
839.67 mmboe
|
4 279 mmboe
|
✓
|
|
ExxonMobil Worldwide Upstream (Portfolio)
|
NGL
|
1P
|
Net
|
Sec
|
2 164 mmboe
|
513 mmboe
|
−373 mmboe
|
0
|
41 mmboe
|
181 mmboe
|
−12 mmboe
|
−194 mmboe
|
−206 mmboe
|
0
|
387 mmboe
|
2 139 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Bitumen
|
1P
|
Net
|
Sec
|
2 429 mmboe
|
0
|
42 mmboe
|
0
|
0
|
42 mmboe
|
0
|
−141 mmboe
|
−141 mmboe
|
0
|
183 mmboe
|
2 330 mmboe
|
✓
|
|
Canada/Other Americas Upstream (Play)
|
Synthetic crude
|
1P
|
Net
|
Sec
|
296 mmboe
|
0
|
17 mmboe
|
0
|
0
|
17 mmboe
|
0
|
−25 mmboe
|
−25 mmboe
|
0
|
42 mmboe
|
288 mmboe
|
✓
|
2023
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Asia Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 794 mmboe
+ Ext. & disc.
0
+ Revisions
30 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
30 mmboe
− Divestitures
−4 mmboe
− Production
−153 mmboe
Combined used
−157 mmboe
± Conv. to developed
0
Net change
187 mmboe
Closing
2 667 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
66 mmboe
+ Ext. & disc.
0
+ Revisions
3 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
3 mmboe
− Divestitures
0
− Production
−8 mmboe
Combined used
−8 mmboe
± Conv. to developed
0
Net change
11 mmboe
Closing
61 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
945 mmboe
+ Ext. & disc.
105 mmboe
+ Revisions
32 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
137 mmboe
− Divestitures
0
− Production
−88 mmboe
Combined used
−88 mmboe
± Conv. to developed
0
Net change
225 mmboe
Closing
994 mmboe
Balance check
✓
United States Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 204 mmboe
+ Ext. & disc.
355 mmboe
+ Revisions
−398 mmboe
+ Improved rec.
0
+ Purchases
156 mmboe
Combined added
113 mmboe
− Divestitures
−12 mmboe
− Production
−203 mmboe
Combined used
−215 mmboe
± Conv. to developed
0
Net change
328 mmboe
Closing
2 102 mmboe
Balance check
✓
Africa Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
271 mmboe
+ Ext. & disc.
0
+ Revisions
31 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
31 mmboe
− Divestitures
0
− Production
−78 mmboe
Combined used
−78 mmboe
± Conv. to developed
0
Net change
109 mmboe
Closing
224 mmboe
Balance check
✓
Europe Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
5 mmboe
+ Ext. & disc.
0
+ Revisions
0
+ Improved rec.
0
+ Purchases
0
Combined added
0
− Divestitures
0
− Production
−1 mmboe
Combined used
−1 mmboe
± Conv. to developed
0
Net change
1 mmboe
Closing
4 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
6 285 mmboe
+ Ext. & disc.
460 mmboe
+ Revisions
−302 mmboe
+ Improved rec.
0
+ Purchases
156 mmboe
Combined added
314 mmboe
− Divestitures
−16 mmboe
− Production
−531 mmboe
Combined used
−547 mmboe
± Conv. to developed
0
Net change
861 mmboe
Closing
6 052 mmboe
Balance check
✓
Asia Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
510.17 mmboe
+ Ext. & disc.
0
+ Revisions
20.17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
20.17 mmboe
− Divestitures
−1.5 mmboe
− Production
−63.17 mmboe
Combined used
−64.67 mmboe
± Conv. to developed
0
Net change
84.83 mmboe
Closing
465.67 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 001.33 mmboe
+ Ext. & disc.
0
+ Revisions
56.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
56.5 mmboe
− Divestitures
0
− Production
−81.5 mmboe
Combined used
−81.5 mmboe
± Conv. to developed
0
Net change
138 mmboe
Closing
976.33 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
118 mmboe
+ Ext. & disc.
11.17 mmboe
+ Revisions
−33.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−22.33 mmboe
− Divestitures
−0.17 mmboe
− Production
−8.83 mmboe
Combined used
−9 mmboe
± Conv. to developed
0
Net change
−13.33 mmboe
Closing
86.67 mmboe
Balance check
✓
United States Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 274.17 mmboe
+ Ext. & disc.
321.67 mmboe
+ Revisions
−324.17 mmboe
+ Improved rec.
0
+ Purchases
1.17 mmboe
Combined added
−1.33 mmboe
− Divestitures
−69.5 mmboe
− Production
−159.5 mmboe
Combined used
−229 mmboe
± Conv. to developed
0
Net change
227.67 mmboe
Closing
2 043.83 mmboe
Balance check
✓
Africa Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
52 mmboe
+ Ext. & disc.
0
+ Revisions
−8.17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−8.17 mmboe
− Divestitures
0
− Production
−7.17 mmboe
Combined used
−7.17 mmboe
± Conv. to developed
0
Net change
−1 mmboe
Closing
36.67 mmboe
Balance check
✓
Europe Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
68.83 mmboe
+ Ext. & disc.
0
+ Revisions
−0.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−0.5 mmboe
− Divestitures
0
− Production
−17.17 mmboe
Combined used
−17.17 mmboe
± Conv. to developed
0
Net change
16.67 mmboe
Closing
51.17 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
4 024.5 mmboe
+ Ext. & disc.
332.83 mmboe
+ Revisions
−289.67 mmboe
+ Improved rec.
0
+ Purchases
1.17 mmboe
Combined added
44.33 mmboe
− Divestitures
−71.17 mmboe
− Production
−337.33 mmboe
Combined used
−408.5 mmboe
± Conv. to developed
0
Net change
452.83 mmboe
Closing
3 660.33 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 176 mmboe
+ Ext. & disc.
272 mmboe
+ Revisions
−110 mmboe
+ Improved rec.
0
+ Purchases
2 mmboe
Combined added
164 mmboe
− Divestitures
−5 mmboe
− Production
−99 mmboe
Combined used
−104 mmboe
± Conv. to developed
0
Net change
268 mmboe
Closing
1 236 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Bitumen
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 420 mmboe
+ Ext. & disc.
0
+ Revisions
123 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
123 mmboe
− Divestitures
0
− Production
−129 mmboe
Combined used
−129 mmboe
± Conv. to developed
0
Net change
252 mmboe
Closing
2 414 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
353 mmboe
+ Ext. & disc.
0
+ Revisions
26 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
26 mmboe
− Divestitures
0
− Production
−25 mmboe
Combined used
−25 mmboe
± Conv. to developed
0
Net change
51 mmboe
Closing
354 mmboe
Balance check
✓
2024
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Asia Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 667 mmboe
+ Ext. & disc.
0
+ Revisions
603 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
603 mmboe
− Divestitures
−7 mmboe
− Production
−154 mmboe
Combined used
−161 mmboe
± Conv. to developed
0
Net change
764 mmboe
Closing
3 109 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
61 mmboe
+ Ext. & disc.
0
+ Revisions
1 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
1 mmboe
− Divestitures
0
− Production
−7 mmboe
Combined used
−7 mmboe
± Conv. to developed
0
Net change
8 mmboe
Closing
55 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
994 mmboe
+ Ext. & disc.
138 mmboe
+ Revisions
116 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
254 mmboe
− Divestitures
−4 mmboe
− Production
−126 mmboe
Combined used
−130 mmboe
± Conv. to developed
0
Net change
384 mmboe
Closing
1 118 mmboe
Balance check
✓
United States Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 102 mmboe
+ Ext. & disc.
804 mmboe
+ Revisions
−176 mmboe
+ Improved rec.
0
+ Purchases
877 mmboe
Combined added
1 505 mmboe
− Divestitures
−18 mmboe
− Production
−316 mmboe
Combined used
−334 mmboe
± Conv. to developed
0
Net change
1 839 mmboe
Closing
3 273 mmboe
Balance check
✓
Africa Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
224 mmboe
+ Ext. & disc.
25 mmboe
+ Revisions
62 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
87 mmboe
− Divestitures
−45 mmboe
− Production
−75 mmboe
Combined used
−120 mmboe
± Conv. to developed
0
Net change
207 mmboe
Closing
191 mmboe
Balance check
✓
Europe Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
4 mmboe
+ Ext. & disc.
0
+ Revisions
0
+ Improved rec.
0
+ Purchases
0
Combined added
0
− Divestitures
0
− Production
−1 mmboe
Combined used
−1 mmboe
± Conv. to developed
0
Net change
1 mmboe
Closing
3 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
6 052 mmboe
+ Ext. & disc.
967 mmboe
+ Revisions
606 mmboe
+ Improved rec.
0
+ Purchases
877 mmboe
Combined added
2 450 mmboe
− Divestitures
−74 mmboe
− Production
−679 mmboe
Combined used
−753 mmboe
± Conv. to developed
0
Net change
3 203 mmboe
Closing
7 749 mmboe
Balance check
✓
Asia Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
465.67 mmboe
+ Ext. & disc.
0
+ Revisions
20.67 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
20.67 mmboe
− Divestitures
−0.83 mmboe
− Production
−62.17 mmboe
Combined used
−63 mmboe
± Conv. to developed
0
Net change
83.67 mmboe
Closing
423.33 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
976.33 mmboe
+ Ext. & disc.
0.17 mmboe
+ Revisions
16.17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
16.33 mmboe
− Divestitures
0
− Production
−79.5 mmboe
Combined used
−79.5 mmboe
± Conv. to developed
0
Net change
95.83 mmboe
Closing
913.17 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
86.67 mmboe
+ Ext. & disc.
11.33 mmboe
+ Revisions
3.67 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
15 mmboe
− Divestitures
−1.67 mmboe
− Production
−9.83 mmboe
Combined used
−11.5 mmboe
± Conv. to developed
0
Net change
26.5 mmboe
Closing
90.17 mmboe
Balance check
✓
United States Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 043.83 mmboe
+ Ext. & disc.
447.17 mmboe
+ Revisions
−151.83 mmboe
+ Improved rec.
0
+ Purchases
674 mmboe
Combined added
969.33 mmboe
− Divestitures
−13.83 mmboe
− Production
−192.17 mmboe
Combined used
−206 mmboe
± Conv. to developed
0
Net change
1 175.33 mmboe
Closing
2 807.17 mmboe
Balance check
✓
Africa Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
36.67 mmboe
+ Ext. & disc.
0.33 mmboe
+ Revisions
4 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
4.33 mmboe
− Divestitures
−17.5 mmboe
− Production
−7.67 mmboe
Combined used
−25.17 mmboe
± Conv. to developed
0
Net change
29.5 mmboe
Closing
15.83 mmboe
Balance check
✓
Europe Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
51.17 mmboe
+ Ext. & disc.
0
+ Revisions
33 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
33 mmboe
− Divestitures
0
− Production
−16.5 mmboe
Combined used
−16.5 mmboe
± Conv. to developed
0
Net change
49.5 mmboe
Closing
67.67 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 660.33 mmboe
+ Ext. & disc.
459 mmboe
+ Revisions
−74.33 mmboe
+ Improved rec.
0
+ Purchases
674 mmboe
Combined added
1 058.67 mmboe
− Divestitures
−33.83 mmboe
− Production
−367.83 mmboe
Combined used
−401.67 mmboe
± Conv. to developed
0
Net change
1 460.33 mmboe
Closing
4 317.33 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 236 mmboe
+ Ext. & disc.
489 mmboe
+ Revisions
−128 mmboe
+ Improved rec.
0
+ Purchases
730 mmboe
Combined added
1 091 mmboe
− Divestitures
−15 mmboe
− Production
−148 mmboe
Combined used
−163 mmboe
± Conv. to developed
0
Net change
1 254 mmboe
Closing
2 164 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Bitumen
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 414 mmboe
+ Ext. & disc.
0
+ Revisions
152 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
152 mmboe
− Divestitures
0
− Production
−137 mmboe
Combined used
−137 mmboe
± Conv. to developed
0
Net change
289 mmboe
Closing
2 429 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
354 mmboe
+ Ext. & disc.
0
+ Revisions
−35 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
−35 mmboe
− Divestitures
0
− Production
−23 mmboe
Combined used
−23 mmboe
± Conv. to developed
0
Net change
−12 mmboe
Closing
296 mmboe
Balance check
✓
2025
Category / dev_status
Reporting basis
Pricing case
Opening
+ Ext. & disc.
+ Revisions
+ Improved rec.
+ Purchases
Combined added
− Divestitures
− Production
Combined used
± Conv. to developed
Net change
Closing
Balance check
Asia Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 109 mmboe
+ Ext. & disc.
0
+ Revisions
13 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
13 mmboe
− Divestitures
0
− Production
−162 mmboe
Combined used
−162 mmboe
± Conv. to developed
0
Net change
175 mmboe
Closing
2 960 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
55 mmboe
+ Ext. & disc.
6 mmboe
+ Revisions
6 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
12 mmboe
− Divestitures
0
− Production
−7 mmboe
Combined used
−7 mmboe
± Conv. to developed
0
Net change
19 mmboe
Closing
60 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
1 118 mmboe
+ Ext. & disc.
92 mmboe
+ Revisions
124 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
216 mmboe
− Divestitures
0
− Production
−139 mmboe
Combined used
−139 mmboe
± Conv. to developed
0
Net change
355 mmboe
Closing
1 195 mmboe
Balance check
✓
United States Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 273 mmboe
+ Ext. & disc.
890 mmboe
+ Revisions
−652 mmboe
+ Improved rec.
0
+ Purchases
38 mmboe
Combined added
276 mmboe
− Divestitures
−72 mmboe
− Production
−367 mmboe
Combined used
−439 mmboe
± Conv. to developed
0
Net change
715 mmboe
Closing
3 110 mmboe
Balance check
✓
Africa Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
191 mmboe
+ Ext. & disc.
0
+ Revisions
78 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
78 mmboe
− Divestitures
0
− Production
−52 mmboe
Combined used
−52 mmboe
± Conv. to developed
0
Net change
130 mmboe
Closing
217 mmboe
Balance check
✓
Europe Upstream (Play)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
3 mmboe
+ Ext. & disc.
0
+ Revisions
1 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
1 mmboe
− Divestitures
0
− Production
−1 mmboe
Combined used
−1 mmboe
± Conv. to developed
0
Net change
2 mmboe
Closing
3 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Oil
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
7 749 mmboe
+ Ext. & disc.
988 mmboe
+ Revisions
−430 mmboe
+ Improved rec.
0
+ Purchases
38 mmboe
Combined added
596 mmboe
− Divestitures
−72 mmboe
− Production
−728 mmboe
Combined used
−800 mmboe
± Conv. to developed
0
Net change
1 396 mmboe
Closing
7 545 mmboe
Balance check
✓
Asia Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
423.33 mmboe
+ Ext. & disc.
0
+ Revisions
11.33 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
11.33 mmboe
− Divestitures
−2.33 mmboe
− Production
−65.83 mmboe
Combined used
−68.17 mmboe
± Conv. to developed
0
Net change
79.5 mmboe
Closing
366.5 mmboe
Balance check
✓
Australia/Oceania Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
913.17 mmboe
+ Ext. & disc.
80.83 mmboe
+ Revisions
38 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
118.83 mmboe
− Divestitures
0
− Production
−80.33 mmboe
Combined used
−80.33 mmboe
± Conv. to developed
0
Net change
199.17 mmboe
Closing
951.67 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
90.17 mmboe
+ Ext. & disc.
4.33 mmboe
+ Revisions
3.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
7.83 mmboe
− Divestitures
−4.67 mmboe
− Production
−5.5 mmboe
Combined used
−10.17 mmboe
± Conv. to developed
0
Net change
18 mmboe
Closing
87.83 mmboe
Balance check
✓
United States Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 807.17 mmboe
+ Ext. & disc.
461.5 mmboe
+ Revisions
−247 mmboe
+ Improved rec.
0
+ Purchases
39 mmboe
Combined added
253.5 mmboe
− Divestitures
−41.33 mmboe
− Production
−221.5 mmboe
Combined used
−262.83 mmboe
± Conv. to developed
0
Net change
516.33 mmboe
Closing
2 797.83 mmboe
Balance check
✓
Africa Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
15.83 mmboe
+ Ext. & disc.
0
+ Revisions
5.67 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
5.67 mmboe
− Divestitures
0
− Production
−2.67 mmboe
Combined used
−2.67 mmboe
± Conv. to developed
0
Net change
8.33 mmboe
Closing
18.83 mmboe
Balance check
✓
Europe Upstream (Play)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
67.67 mmboe
+ Ext. & disc.
0
+ Revisions
3.5 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
3.5 mmboe
− Divestitures
0
− Production
−14.83 mmboe
Combined used
−14.83 mmboe
± Conv. to developed
0
Net change
18.33 mmboe
Closing
56.33 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
4 317.33 mmboe
+ Ext. & disc.
546.67 mmboe
+ Revisions
−185 mmboe
+ Improved rec.
0
+ Purchases
39 mmboe
Combined added
400.67 mmboe
− Divestitures
−48.33 mmboe
− Production
−390.67 mmboe
Combined used
−439 mmboe
± Conv. to developed
0
Net change
839.67 mmboe
Closing
4 279 mmboe
Balance check
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 164 mmboe
+ Ext. & disc.
513 mmboe
+ Revisions
−373 mmboe
+ Improved rec.
0
+ Purchases
41 mmboe
Combined added
181 mmboe
− Divestitures
−12 mmboe
− Production
−194 mmboe
Combined used
−206 mmboe
± Conv. to developed
0
Net change
387 mmboe
Closing
2 139 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Bitumen
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
2 429 mmboe
+ Ext. & disc.
0
+ Revisions
42 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
42 mmboe
− Divestitures
0
− Production
−141 mmboe
Combined used
−141 mmboe
± Conv. to developed
0
Net change
183 mmboe
Closing
2 330 mmboe
Balance check
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
Category / dev_status
1P
Reporting basis
Net
Pricing case
Sec
Opening
296 mmboe
+ Ext. & disc.
0
+ Revisions
17 mmboe
+ Improved rec.
0
+ Purchases
0
Combined added
17 mmboe
− Divestitures
0
− Production
−25 mmboe
Combined used
−25 mmboe
± Conv. to developed
0
Net change
42 mmboe
Closing
288 mmboe
Balance check
✓
2023
Asia Upstream (Play)
Oil
1P
Net
Sec
2 794 mmboe
0
30 mmboe
0
0
30 mmboe
−4 mmboe
−153 mmboe
−157 mmboe
0
187 mmboe
2 667 mmboe
✓
Australia/Oceania Upstream (Play)
Oil
1P
Net
Sec
66 mmboe
0
3 mmboe
0
0
3 mmboe
0
−8 mmboe
−8 mmboe
0
11 mmboe
61 mmboe
✓
Canada/Other Americas Upstream (Play)
Oil
1P
Net
Sec
945 mmboe
105 mmboe
32 mmboe
0
0
137 mmboe
0
−88 mmboe
−88 mmboe
0
225 mmboe
994 mmboe
✓
United States Upstream (Play)
Oil
1P
Net
Sec
2 204 mmboe
355 mmboe
−398 mmboe
0
156 mmboe
113 mmboe
−12 mmboe
−203 mmboe
−215 mmboe
0
328 mmboe
2 102 mmboe
✓
Africa Upstream (Play)
Oil
1P
Net
Sec
271 mmboe
0
31 mmboe
0
0
31 mmboe
0
−78 mmboe
−78 mmboe
0
109 mmboe
224 mmboe
✓
Europe Upstream (Play)
Oil
1P
Net
Sec
5 mmboe
0
0
0
0
0
0
−1 mmboe
−1 mmboe
0
1 mmboe
4 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Oil
1P
Net
Sec
6 285 mmboe
460 mmboe
−302 mmboe
0
156 mmboe
314 mmboe
−16 mmboe
−531 mmboe
−547 mmboe
0
861 mmboe
6 052 mmboe
✓
Asia Upstream (Play)
Natural gas
1P
Net
Sec
510.17 mmboe
0
20.17 mmboe
0
0
20.17 mmboe
−1.5 mmboe
−63.17 mmboe
−64.67 mmboe
0
84.83 mmboe
465.67 mmboe
✓
Australia/Oceania Upstream (Play)
Natural gas
1P
Net
Sec
1 001.33 mmboe
0
56.5 mmboe
0
0
56.5 mmboe
0
−81.5 mmboe
−81.5 mmboe
0
138 mmboe
976.33 mmboe
✓
Canada/Other Americas Upstream (Play)
Natural gas
1P
Net
Sec
118 mmboe
11.17 mmboe
−33.5 mmboe
0
0
−22.33 mmboe
−0.17 mmboe
−8.83 mmboe
−9 mmboe
0
−13.33 mmboe
86.67 mmboe
✓
United States Upstream (Play)
Natural gas
1P
Net
Sec
2 274.17 mmboe
321.67 mmboe
−324.17 mmboe
0
1.17 mmboe
−1.33 mmboe
−69.5 mmboe
−159.5 mmboe
−229 mmboe
0
227.67 mmboe
2 043.83 mmboe
✓
Africa Upstream (Play)
Natural gas
1P
Net
Sec
52 mmboe
0
−8.17 mmboe
0
0
−8.17 mmboe
0
−7.17 mmboe
−7.17 mmboe
0
−1 mmboe
36.67 mmboe
✓
Europe Upstream (Play)
Natural gas
1P
Net
Sec
68.83 mmboe
0
−0.5 mmboe
0
0
−0.5 mmboe
0
−17.17 mmboe
−17.17 mmboe
0
16.67 mmboe
51.17 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
1P
Net
Sec
4 024.5 mmboe
332.83 mmboe
−289.67 mmboe
0
1.17 mmboe
44.33 mmboe
−71.17 mmboe
−337.33 mmboe
−408.5 mmboe
0
452.83 mmboe
3 660.33 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
1P
Net
Sec
1 176 mmboe
272 mmboe
−110 mmboe
0
2 mmboe
164 mmboe
−5 mmboe
−99 mmboe
−104 mmboe
0
268 mmboe
1 236 mmboe
✓
Canada/Other Americas Upstream (Play)
Bitumen
1P
Net
Sec
2 420 mmboe
0
123 mmboe
0
0
123 mmboe
0
−129 mmboe
−129 mmboe
0
252 mmboe
2 414 mmboe
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
1P
Net
Sec
353 mmboe
0
26 mmboe
0
0
26 mmboe
0
−25 mmboe
−25 mmboe
0
51 mmboe
354 mmboe
✓
2024
Asia Upstream (Play)
Oil
1P
Net
Sec
2 667 mmboe
0
603 mmboe
0
0
603 mmboe
−7 mmboe
−154 mmboe
−161 mmboe
0
764 mmboe
3 109 mmboe
✓
Australia/Oceania Upstream (Play)
Oil
1P
Net
Sec
61 mmboe
0
1 mmboe
0
0
1 mmboe
0
−7 mmboe
−7 mmboe
0
8 mmboe
55 mmboe
✓
Canada/Other Americas Upstream (Play)
Oil
1P
Net
Sec
994 mmboe
138 mmboe
116 mmboe
0
0
254 mmboe
−4 mmboe
−126 mmboe
−130 mmboe
0
384 mmboe
1 118 mmboe
✓
United States Upstream (Play)
Oil
1P
Net
Sec
2 102 mmboe
804 mmboe
−176 mmboe
0
877 mmboe
1 505 mmboe
−18 mmboe
−316 mmboe
−334 mmboe
0
1 839 mmboe
3 273 mmboe
✓
Africa Upstream (Play)
Oil
1P
Net
Sec
224 mmboe
25 mmboe
62 mmboe
0
0
87 mmboe
−45 mmboe
−75 mmboe
−120 mmboe
0
207 mmboe
191 mmboe
✓
Europe Upstream (Play)
Oil
1P
Net
Sec
4 mmboe
0
0
0
0
0
0
−1 mmboe
−1 mmboe
0
1 mmboe
3 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Oil
1P
Net
Sec
6 052 mmboe
967 mmboe
606 mmboe
0
877 mmboe
2 450 mmboe
−74 mmboe
−679 mmboe
−753 mmboe
0
3 203 mmboe
7 749 mmboe
✓
Asia Upstream (Play)
Natural gas
1P
Net
Sec
465.67 mmboe
0
20.67 mmboe
0
0
20.67 mmboe
−0.83 mmboe
−62.17 mmboe
−63 mmboe
0
83.67 mmboe
423.33 mmboe
✓
Australia/Oceania Upstream (Play)
Natural gas
1P
Net
Sec
976.33 mmboe
0.17 mmboe
16.17 mmboe
0
0
16.33 mmboe
0
−79.5 mmboe
−79.5 mmboe
0
95.83 mmboe
913.17 mmboe
✓
Canada/Other Americas Upstream (Play)
Natural gas
1P
Net
Sec
86.67 mmboe
11.33 mmboe
3.67 mmboe
0
0
15 mmboe
−1.67 mmboe
−9.83 mmboe
−11.5 mmboe
0
26.5 mmboe
90.17 mmboe
✓
United States Upstream (Play)
Natural gas
1P
Net
Sec
2 043.83 mmboe
447.17 mmboe
−151.83 mmboe
0
674 mmboe
969.33 mmboe
−13.83 mmboe
−192.17 mmboe
−206 mmboe
0
1 175.33 mmboe
2 807.17 mmboe
✓
Africa Upstream (Play)
Natural gas
1P
Net
Sec
36.67 mmboe
0.33 mmboe
4 mmboe
0
0
4.33 mmboe
−17.5 mmboe
−7.67 mmboe
−25.17 mmboe
0
29.5 mmboe
15.83 mmboe
✓
Europe Upstream (Play)
Natural gas
1P
Net
Sec
51.17 mmboe
0
33 mmboe
0
0
33 mmboe
0
−16.5 mmboe
−16.5 mmboe
0
49.5 mmboe
67.67 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
1P
Net
Sec
3 660.33 mmboe
459 mmboe
−74.33 mmboe
0
674 mmboe
1 058.67 mmboe
−33.83 mmboe
−367.83 mmboe
−401.67 mmboe
0
1 460.33 mmboe
4 317.33 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
1P
Net
Sec
1 236 mmboe
489 mmboe
−128 mmboe
0
730 mmboe
1 091 mmboe
−15 mmboe
−148 mmboe
−163 mmboe
0
1 254 mmboe
2 164 mmboe
✓
Canada/Other Americas Upstream (Play)
Bitumen
1P
Net
Sec
2 414 mmboe
0
152 mmboe
0
0
152 mmboe
0
−137 mmboe
−137 mmboe
0
289 mmboe
2 429 mmboe
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
1P
Net
Sec
354 mmboe
0
−35 mmboe
0
0
−35 mmboe
0
−23 mmboe
−23 mmboe
0
−12 mmboe
296 mmboe
✓
2025
Asia Upstream (Play)
Oil
1P
Net
Sec
3 109 mmboe
0
13 mmboe
0
0
13 mmboe
0
−162 mmboe
−162 mmboe
0
175 mmboe
2 960 mmboe
✓
Australia/Oceania Upstream (Play)
Oil
1P
Net
Sec
55 mmboe
6 mmboe
6 mmboe
0
0
12 mmboe
0
−7 mmboe
−7 mmboe
0
19 mmboe
60 mmboe
✓
Canada/Other Americas Upstream (Play)
Oil
1P
Net
Sec
1 118 mmboe
92 mmboe
124 mmboe
0
0
216 mmboe
0
−139 mmboe
−139 mmboe
0
355 mmboe
1 195 mmboe
✓
United States Upstream (Play)
Oil
1P
Net
Sec
3 273 mmboe
890 mmboe
−652 mmboe
0
38 mmboe
276 mmboe
−72 mmboe
−367 mmboe
−439 mmboe
0
715 mmboe
3 110 mmboe
✓
Africa Upstream (Play)
Oil
1P
Net
Sec
191 mmboe
0
78 mmboe
0
0
78 mmboe
0
−52 mmboe
−52 mmboe
0
130 mmboe
217 mmboe
✓
Europe Upstream (Play)
Oil
1P
Net
Sec
3 mmboe
0
1 mmboe
0
0
1 mmboe
0
−1 mmboe
−1 mmboe
0
2 mmboe
3 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Oil
1P
Net
Sec
7 749 mmboe
988 mmboe
−430 mmboe
0
38 mmboe
596 mmboe
−72 mmboe
−728 mmboe
−800 mmboe
0
1 396 mmboe
7 545 mmboe
✓
Asia Upstream (Play)
Natural gas
1P
Net
Sec
423.33 mmboe
0
11.33 mmboe
0
0
11.33 mmboe
−2.33 mmboe
−65.83 mmboe
−68.17 mmboe
0
79.5 mmboe
366.5 mmboe
✓
Australia/Oceania Upstream (Play)
Natural gas
1P
Net
Sec
913.17 mmboe
80.83 mmboe
38 mmboe
0
0
118.83 mmboe
0
−80.33 mmboe
−80.33 mmboe
0
199.17 mmboe
951.67 mmboe
✓
Canada/Other Americas Upstream (Play)
Natural gas
1P
Net
Sec
90.17 mmboe
4.33 mmboe
3.5 mmboe
0
0
7.83 mmboe
−4.67 mmboe
−5.5 mmboe
−10.17 mmboe
0
18 mmboe
87.83 mmboe
✓
United States Upstream (Play)
Natural gas
1P
Net
Sec
2 807.17 mmboe
461.5 mmboe
−247 mmboe
0
39 mmboe
253.5 mmboe
−41.33 mmboe
−221.5 mmboe
−262.83 mmboe
0
516.33 mmboe
2 797.83 mmboe
✓
Africa Upstream (Play)
Natural gas
1P
Net
Sec
15.83 mmboe
0
5.67 mmboe
0
0
5.67 mmboe
0
−2.67 mmboe
−2.67 mmboe
0
8.33 mmboe
18.83 mmboe
✓
Europe Upstream (Play)
Natural gas
1P
Net
Sec
67.67 mmboe
0
3.5 mmboe
0
0
3.5 mmboe
0
−14.83 mmboe
−14.83 mmboe
0
18.33 mmboe
56.33 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
Natural gas
1P
Net
Sec
4 317.33 mmboe
546.67 mmboe
−185 mmboe
0
39 mmboe
400.67 mmboe
−48.33 mmboe
−390.67 mmboe
−439 mmboe
0
839.67 mmboe
4 279 mmboe
✓
ExxonMobil Worldwide Upstream (Portfolio)
NGL
1P
Net
Sec
2 164 mmboe
513 mmboe
−373 mmboe
0
41 mmboe
181 mmboe
−12 mmboe
−194 mmboe
−206 mmboe
0
387 mmboe
2 139 mmboe
✓
Canada/Other Americas Upstream (Play)
Bitumen
1P
Net
Sec
2 429 mmboe
0
42 mmboe
0
0
42 mmboe
0
−141 mmboe
−141 mmboe
0
183 mmboe
2 330 mmboe
✓
Canada/Other Americas Upstream (Play)
Synthetic crude
1P
Net
Sec
296 mmboe
0
17 mmboe
0
0
17 mmboe
0
−25 mmboe
−25 mmboe
0
42 mmboe
288 mmboe
✓
Reserves walk · Gross (disclosed) — Assumptions & Disclaimers
- Per METALPILOT model invariants: closing = opening + Σ deltas. Rows are rendered as disclosed (gross reporting basis), grouped by period year. Signs follow the source. Combined added rolls up the four additive lines; Combined used rolls up divestitures and production. Net change is combined added minus combined used.
- Mining / R&R walks are not modelled here. Royalty / stream walks reflect the operator's underlying movement on the gross asset, not cash to the holder. Balance check: ✓ when closing balances within 1% of opening + Σ deltas; otherwise the variance is shown as 'Δ <value> <unit>'.
Reserves walk · Net change by year
| Year | |||||
|---|---|---|---|---|---|
| Oil · 1P · Net change (Δ %) | Natural gas · 1P · Net change (Δ %) | NGL · 1P · Net change (Δ %) | Bitumen · 1P · Net change (Δ %) | Synthetic crude · 1P · Net change (Δ %) | |
|
2023
|
109 mmboe (+40%)
|
−13.33 mmboe (-11%)
|
268 mmboe (+23%)
|
252 mmboe (+10%)
|
51 mmboe (+14%)
|
|
2024
|
764 mmboe (+29%)
|
49.5 mmboe (+97%)
|
1 254 mmboe (+101%)
|
289 mmboe (+12%)
|
−12 mmboe (-3%)
|
|
2025
|
175 mmboe (+6%)
|
18.33 mmboe (+27%)
|
387 mmboe (+18%)
|
183 mmboe (+8%)
|
42 mmboe (+14%)
|
2023
Oil · 1P · Net change (Δ %)
109 mmboe (+40%)
Natural gas · 1P · Net change (Δ %)
−13.33 mmboe (-11%)
NGL · 1P · Net change (Δ %)
268 mmboe (+23%)
Bitumen · 1P · Net change (Δ %)
252 mmboe (+10%)
Synthetic crude · 1P · Net change (Δ %)
51 mmboe (+14%)
2024
Oil · 1P · Net change (Δ %)
764 mmboe (+29%)
Natural gas · 1P · Net change (Δ %)
49.5 mmboe (+97%)
NGL · 1P · Net change (Δ %)
1 254 mmboe (+101%)
Bitumen · 1P · Net change (Δ %)
289 mmboe (+12%)
Synthetic crude · 1P · Net change (Δ %)
−12 mmboe (-3%)
2025
Oil · 1P · Net change (Δ %)
175 mmboe (+6%)
Natural gas · 1P · Net change (Δ %)
18.33 mmboe (+27%)
NGL · 1P · Net change (Δ %)
387 mmboe (+18%)
Bitumen · 1P · Net change (Δ %)
183 mmboe (+8%)
Synthetic crude · 1P · Net change (Δ %)
42 mmboe (+14%)
2023
109 mmboe (+40%)
−13.33 mmboe (-11%)
268 mmboe (+23%)
252 mmboe (+10%)
51 mmboe (+14%)
2024
764 mmboe (+29%)
49.5 mmboe (+97%)
1 254 mmboe (+101%)
289 mmboe (+12%)
−12 mmboe (-3%)
2025
175 mmboe (+6%)
18.33 mmboe (+27%)
387 mmboe (+18%)
183 mmboe (+8%)
42 mmboe (+14%)
Reserves walk · Net change by year — Assumptions & Disclaimers
- One row per period year. Columns are attributable net change (combined added − combined used) per commodity × category slice, with Δ% vs opening balance in brackets.
- Closing balances appear in the gross walk table above. Percentages use opening balance as the denominator.
Generic assumptions
- Generic assumptions (this panel) covers modelling choices for the KPI strip and each table section. Generic disclaimers (the panel below) covers investment risk, section-specific notices and data limitations. For definitions, units, reporting standards, cost benchmarks and attribution methods, see the Terminology tab.
- Project counts exclude play-level rollups so the same asset is not double-counted with its parent play.
- When a Portfolio Aggregate row exists, company-level totals (attributable production / reserve base USD) use only that rollup; underlying assets appear only in the per-project sections below.
- Attributable production / reserve base apply the attribution method documented on the Terminology tab (working interest, royalty / stream rate, net of royalty, or gross WI).
- Hydrocarbon production shows source units with an MMboe equivalent for gas (6 Mcf ≈ 1 BOE); estimated production revenue and the mix bar value MMboe-normalised gas at the same $/Bcf × 6 implied $/MMboe.
- USD value lines use the most recent commodity price snapshot. They are not a market valuation of the company.
- 'Operating' reflects each asset's operating status. 'Strategic' reflects the strategic flag on the asset.
Generic disclaimers
- The information on this page is provided for informational and educational purposes only. It is not investment advice, not a recommendation to buy, sell or hold any security, commodity, derivative or other financial instrument, and not an offer or solicitation in any jurisdiction.
- Metal Pilot compiles, normalises and presents data drawn from publicly available sources. We make no representation or warranty, express or implied, as to the accuracy, completeness, timeliness, fitness for a particular purpose, or non-infringement of any data on this page. Figures may be incomplete, out of date, misclassified, mis-attributed or incorrect.
- Always verify every figure with the original public disclosure (the company's annual report, NI 43-101 / NI 51-101 / SEC / JORC / SAMREC / PERC / PRMS / COGEH technical report, MD&A, investor presentation, press release, regulator filing or equivalent primary source) before making any investment, trading, lending, commercial, legal or operational decision. The primary source always prevails over Metal Pilot's normalised view.
- To the maximum extent permitted by applicable law, Metal Pilot, its affiliates, contributors and licensors disclaim all liability for any loss, damage, claim, cost or expense of any kind (including direct, indirect, incidental, consequential, special, punitive or exemplary losses, loss of profits, loss of opportunity, trading losses, investment losses or reputational losses) arising out of or in connection with reliance on, or use of, any information on this page.
- Metal Pilot is not a registered investment adviser, broker-dealer, mineral / petroleum qualified person or competent person, technical evaluator, accountant or lawyer. The presentation of data on this page does not constitute a qualified person's report, a competent person's statement, an audit, a fairness opinion or a valuation.
- By using this page you acknowledge that all investment and commercial decisions are made at your own risk and that any reliance on the information shown here is your own responsibility.
- KPI tiles are convenience aggregations only. They are not guidance, not a forecast, not a valuation, and may exclude assets that the company itself reports as material. Always verify with the most recent 10-K / 20-F / 40-F / annual report and the underlying technical reports.
- Counts and country flags are derived from the company's own classification. Some assets may be reported under joint ventures, holding companies or special-purpose vehicles, which may change the apparent country or operator profile relative to a strict beneficial-ownership view.
- Oil and gas estimates are inherently uncertain. Even Proved (1P) reserves carry an SEC-defined 'reasonable certainty' standard, which is not the same as a guarantee of recovery. Booked reserves are highly sensitive to assumed prices; price-deck changes can move 2P balances by material amounts year-on-year. Contingent and Prospective volumes carry substantial discovery, appraisal, commercial and development risk.
- Footprint and runway are stocks at a point in time and may straddle the reserves effective date by up to a quarter. Net economic locations are a management estimate at a stated breakeven price — re-pricing the deck or changing the benchmark can move the number materially without any underlying reserves change. Shadow inventory should be read as 'optionality the operator believes economic', not 'reserves'. DUC and rigs-running counts at one effective_date are leading indicators of near-term production but are not commitments. Carried interests, area-of-mutual-interest agreements and joint-venture mechanics can cause the disclosed net figure to drift from a naive net = gross × working-interest calculation. EUR per well is blended across formations unless the source split it; cross-operator comparison is indicative only.
- Nameplate capacity is an engineering maximum; sustained utilisation may be substantially lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, smelter TC/RCs, fractionation spreads) are commodity-specific and may not be visible on this page.
- Portfolio-level rollups are convenient for company-vs-company comparisons but can mask asset-level concentration risk: a single producing field or mine may account for the majority of the rollup figure.
- Nameplate / licensed capacity is an engineering maximum; sustained utilisation may be lower because of maintenance, environmental limits, commercial contracts, weather or feedstock availability. Processing margins (refining crack spreads, fractionation spreads) are commodity-specific and may not be visible on this page.
- Adding categories across uncertainty levels (e.g. adding Inferred to M+I, or adding 3P to 2P) is statistically incorrect because the underlying probability distributions are different. Do not infer a single 'total resource' by summing rows of different categories.
- Reserve reconciliations are sensitive to the year's price deck (positive or negative revisions can dominate other lines), to changes in accounting standards (e.g. SEC pricing transition years) and to property acquisitions / divestitures (which can swing closing balances independently of any drilling). Do not interpret a single year's walk in isolation.
- Year-on-year net additions are a poor proxy for organic exploration success: a single acquisition can dwarf years of drilling, and a single price-driven revision can dwarf both.
- Snapshot in time. Reserves, resources, production, costs, NPV and grade figures are dated to the effective date of the source document; operating results may have changed materially since publication.
- Estimates, not certainties. Reserves and resources are estimates prepared under defined codes; even classified reserves carry stated probability ranges, and resources carry significantly higher uncertainty.
- Heterogeneous standards. Mining categories (Proven, Probable, Measured, Indicated, Inferred) and petroleum categories (1P, 2P, 3P, 1C, 2C, 3C, 1U, 2U, 3U) are not directly comparable across codes or even across companies. Definitions live on the Terminology tab.
- Attribution mathematics. Volumes may be on a gross (100 %), company gross working-interest, or company net (after royalty / entitlement) basis. See the Terminology tab → Attribution methods.
- Currency and units. Costs and NPV are shown in the currency the company reports them in; no FX adjustment is applied to historical figures. Volumes are normalised to the commodity display unit when a conversion is defined.
- Aggregation choices. When a Portfolio Aggregate row exists, snapshot KPIs use only that rollup so the same barrel / tonne is not counted twice; play-level rollups never feed company-level totals.
- Coverage gaps. A blank cell (–) means the company did not disclose the figure under the reporting standard we tracked, or the figure was not machine-extractable. It does not mean the figure is zero.
- Possible data errors. Despite our QC pipeline, individual figures may be misread, mis-categorised, attached to the wrong commodity or the wrong effective date. Always verify against the original filing before relying on any number for a decision.
- 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.
Each table lists the numeric band for scores 1–5 (production and resource base; grade where applicable for mining commodities) using the same thresholds as project rating stat cards. Only commodities that appear on featured projects for this document are listed.
Oil equivalent (BOE)
1 / 5
0–0.5 MMboe/yr
0–5 MMboe
2 / 5
0.5–5 MMboe/yr
5–25 MMboe
3 / 5
5–20 MMboe/yr
25–100 MMboe
4 / 5
20–75 MMboe/yr
100–500 MMboe
5 / 5
≥ 75 MMboe/yr
≥ 500 MMboe
Oil
1 / 5
0–0.5 MMbbl/yr
0–5 MMbbl
2 / 5
0.5–5 MMbbl/yr
5–25 MMbbl
3 / 5
5–20 MMbbl/yr
25–100 MMbbl
4 / 5
20–75 MMbbl/yr
100–500 MMbbl
5 / 5
≥ 75 MMbbl/yr
≥ 500 MMbbl
Natural gas
1 / 5
0–4 Bcf/yr
0–50 Bcf
2 / 5
4–20 Bcf/yr
50–500 Bcf
3 / 5
20–75 Bcf/yr
500–2000 Bcf
4 / 5
75–180 Bcf/yr
2000–10000 Bcf
5 / 5
≥ 180 Bcf/yr
≥ 10000 Bcf
NGL
1 / 5
0–0.1 MMbbl/yr
0–2 MMbbl
2 / 5
0.1–0.5 MMbbl/yr
2–10 MMbbl
3 / 5
0.5–2 MMbbl/yr
10–25 MMbbl
4 / 5
2–5 MMbbl/yr
25–100 MMbbl
5 / 5
≥ 5 MMbbl/yr
≥ 100 MMbbl
Bitumen
1 / 5
0–0.5 MMbbl/yr
0–5 MMbbl
2 / 5
0.5–5 MMbbl/yr
5–25 MMbbl
3 / 5
5–20 MMbbl/yr
25–100 MMbbl
4 / 5
20–75 MMbbl/yr
100–500 MMbbl
5 / 5
≥ 75 MMbbl/yr
≥ 500 MMbbl
Synthetic crude
1 / 5
0–0.5 MMbbl/yr
0–5 MMbbl
2 / 5
0.5–5 MMbbl/yr
5–25 MMbbl
3 / 5
5–20 MMbbl/yr
25–100 MMbbl
4 / 5
20–75 MMbbl/yr
100–500 MMbbl
5 / 5
≥ 75 MMbbl/yr
≥ 500 MMbbl
Copper uses kt Cu bands (Mlb Cu when lb-scale copper resources appear on featured projects). Lithium grade uses hard-rock % Li₂O bands unless brine-style extraction or brine units appear on featured projects.
- 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.