What changed in this filing

/stocks — the workspaceLOADING

Item 2. Properties

2024-02-28 compared with 2023-02-22 · 121 added, 163 removed, 524 unchanged (35% of the section changed)

74 unchanged sentences

In addition, the group provides training to personnel involved in the reserves estimation and reporting process within ExxonMobil and its affiliates.

The Global Reserves and Resources Manager has more than 30 years of experience in reservoir engineering and reserves assessment, has a degree in Engineering, and served on the Oil and Gas Reserves Committee of the Society of Petroleum Engineers (SPE).

The current Global Reserves and Resources Manager has more than 30 years of experience in reservoir engineering and reserves assessment, has a degree in Engineering, and served on the Oil and Gas Reserves Committee of the Society of Petroleum Engineers.

The group is staffed with individuals that have an average of more than 15 years of technical experience in the petroleum industry, including expertise in the classification and categorization of reserves under SEC guidelines.

13 unchanged sentences

During the year, ExxonMobil conducted development activities that resulted in the transfer of approximately 0.8 GOEB from proved undeveloped to proved developed reserves by year-end.

The largest transfers were related to development activities in the United States, Mozambique, Guyana, and the United Arab Emirates.

During 2022, extensions and discoveries, primarily in the United States and Guyana, resulted in the addition of approximately 1.4 GOEB of proved undeveloped reserves, along with an increase of approximately 0.7 GOEB due to purchases in Asia.

Also, the Corporation reclassified approximately 0.8 GOEB of proved undeveloped reserves which no longer met the SEC definition of proved reserves, primarily in the United States and Canada.

The largest transfers were related to development activities in the United States, Guyana, Australia, and the United Arab Emirates.

In 2023, extensions and discoveries, primarily in the United States and Guyana, resulted in the addition of approximately 1.1 GOEB of proved undeveloped reserves.

Also, the Corporation reclassified approximately 0.6 GOEB of proved undeveloped reserves which no longer met the SEC definition of proved reserves, primarily in the United States.

Overall, investments of $14.6 billion were made by the Corporation during 2023 to progress the development of reported proved undeveloped reserves, including $14.3 billion for oil and gas producing activities, along with additional investments for other non-oil and gas producing activities such as the construction of support infrastructure and other related facilities.

3 unchanged sentences

Development projects typically take several years from the time of recording proved undeveloped reserves to the start of production and can exceed five years for large and complex projects.

Proved undeveloped reserves in Australia, Kazakhstan, the United States, and the United Arab Emirates have remained undeveloped for five years or more primarily due to constraints on the capacity of infrastructure, as well as the time required to complete development for very large projects.

Proved undeveloped reserves in Australia, Kazakhstan, the United Arab Emirates, and the United States have remained undeveloped for five years or more primarily due to constraints on the capacity of infrastructure, as well as the time required to complete development for very large projects.

The Corporation is reasonably certain that these proved reserves will be produced;

47 unchanged sentences

Europe 148 361 431

Africa 90 7 —

Asia 2,575 2,639 2,658

174 unchanged sentences

Africa — — — —

Asia 61 4 8 3

Total Equity Companies 70 4 21 5

2 unchanged sentences

United States

ExxonMobil’s year-end 2022 acreage holdings totaled 9.5 million net acres, of which 0.2 million net acres were offshore.

In 2022, ExxonMobil relinquished 1 million net acres, of which 0.2 million were offshore.

Net acreage totaled 9.3 million acres at year-end 2023, of which 0.2 million acres were offshore.

ExxonMobil was active in areas onshore and offshore in the lower 48 states and in Alaska.

Development activities continued on the Golden Pass liquefied natural gas export project.

Development activities continued on the Golden Pass LNG export project.

During the year, a total of 446.9 net exploratory and development wells were completed in the inland lower 48 states.

Development activities focused on liquids-rich opportunities in the onshore U.S., primarily in the Permian Basin of West Texas and New Mexico.

ExxonMobil’s net acreage in the Gulf of Mexico at year-end 2022 was 0.1 million acres.

A total of 0.9 net development wells were completed during the year.

In addition, ExxonMobil closed on the sale of its interest in the Aera Energy joint venture and acquired Denbury Inc.

(Denbury), which includes Gulf Coast and Rocky Mountain oil and natural gas operations.

Net acreage in the Gulf of Mexico totaled 0.1 million acres at year-end 2023.

Participation in Alaska production and development continued with a total of 2.3 net development wells completed.

1 unchanged sentence

Oil and Gas Operations:

ExxonMobil’s year-end 2022 acreage holdings totaled 4.3 million net acres, of which 2.5 million net acres were offshore.

In 2022, ExxonMobil relinquished 2.5 million net acres, of which 1.5 million were offshore.

Net acreage totaled 3.9 million acres at year-end 2023, of which 2.1 million acres were offshore.

A total of 0.9 net exploratory and development wells were completed during the year.

In Situ Bitumen Operations:

ExxonMobil’s year-end 2022 in situ bitumen acreage holdings totaled 0.5 million net onshore acres.

A total of 24 net development wells at Cold Lake were completed during the year.

ExxonMobil’s net acreage totaled 2.9 million acres at year-end 2022, of which 2.6 million net acres were offshore.

Net acreage totaled 0.5 million onshore acres at year-end 2023.

During the year, a total of 32 net development wells at Cold Lake were completed.

Net acreage totaled 2.9 million acres at year-end 2023, of which 2.6 million acres were offshore.

During the year, a total of 4.4 net development wells were completed.

ExxonMobil’s net acreage totaled 2.6 million offshore acres at year-end 2022.

During the year, a total of 1.5 net exploratory wells were completed.

Development activities continued on the Bacalhau Phase 1 project.

ExxonMobil’s net acreage totaled 4.6 million offshore acres at year-end 2022.

During the year, a total of 6 net exploratory and development wells were completed.

The Liza Phase 2 Unity floating production, storage and offloading vessel commenced operations, and development activities continued on the Payara project.

The Yellowtail project was funded in 2022.

ExxonMobil’s net acreage totaled 1.4 million onshore acres at year-end 2022.

ExxonMobil’s net interest in licenses totaled 1.4 million acres at year-end 2022, of which 0.4 million acres were offshore.

Net acreage totaled 2.6 million offshore acres at year-end 2023.

During the year, a total of 0.4 net development well was completed.

In 2022, the Dutch Government further reduced Groningen gas extraction and continues to evaluate the timing for cessation of production.

United Kingdom

ExxonMobil’s net interest in licenses totaled 0.1 million offshore acres at year-end 2022.

ExxonMobil’s net acreage totaled 3 million acres at year-end 2022, of which 2.9 million net acres were offshore.

Development activities continued on the Bacalhau Phase 1 project.

Net acreage totaled 4.6 million offshore acres at year-end 2023.

During the year, a total of 12.6 net exploratory and development wells were completed.

Equatorial Guinea

ExxonMobil’s net acreage totaled 0.1 million offshore acres at year-end 2022.

ExxonMobil’s net acreage totaled 0.7 million offshore acres at year-end 2022.

In 2022, ExxonMobil relinquished 1 million net offshore acres outside of the core Area 4 development.

The Coral South Floating LNG development began production in October 2022.

ExxonMobil’s net acreage totaled 0.9 million offshore acres at year-end 2022.

The Payara development commenced operations with the Prosperity floating production, storage and offloading vessel, and development activities continued on the Yellowtail project.

The Uaru project was funded in 2023.

Net acreage totaled 1.4 million onshore acres at year-end 2023.

During the year, a total of 1.4 net exploratory and development wells were completed.

ExxonMobil's net acreage totaled 7 thousand offshore acres at year-end 2022.

Net interest in licenses totaled 1.3 million acres at year-end 2023, of which 0.3 million acres were offshore.

Groningen gas production ceased on October 1, 2023, at the Dutch government’s instruction.

In case of severe cold weather conditions, the Dutch government could mandate the re-start of gas production.

United Kingdom

Net interest in licenses totaled 0.1 million offshore acres at year-end 2023.

Net acreage totaled 3 million acres at year-end 2023, of which 2.9 million acres were offshore.

During the year, a total of 3.7 net development wells were completed.

ExxonMobil’s net acreage totaled 0.1 million onshore acres at year-end 2022.

ExxonMobil’s net acreage totaled 36 thousand onshore acres at year-end 2022.

Equatorial Guinea

Net acreage totaled 0.1 million offshore acres at year-end 2023.

ExxonMobil is actively taking steps to exit its operations in the country.

Net acreage totaled 0.1 million offshore acres at year-end 2023.

In 2023, 0.6 million net offshore acres were relinquished outside of the core Area 4 development.

Within Area 4, ExxonMobil participated in the co-venturer-operated Coral South Floating LNG, a gross 3.4 million metric tons per year LNG facility.

Net acreage totaled 0.9 million offshore acres at year-end 2023.

During the year, a total of 0.2 net development well was completed.

Oil field rehabilitation activities continued during 2022 and across the life of this project will include drilling of new wells;

working over of existing wells;

and optimization, debottlenecking and expansion of facilities.

ExxonMobil’s net acreage totaled 0.3 million acres at year-end 2022, of which 0.2 million net acres were offshore.

Net acreage totaled 7 thousand offshore acres at year-end 2023.

During the year, a total of 0.5 net development wells were completed.

Development activities continued on the Tengiz Expansion project.

ExxonMobil’s interests in production sharing contracts covered 0.2 million net offshore acres at year-end 2022.

Through our joint ventures with QatarEnergy, ExxonMobil’s net acreage totaled 80 thousand offshore acres at year-end 2022.

ExxonMobil participated in 52.3 million tonnes per year gross liquefied natural gas capacity and 3.4 billion cubic feet per day of flowing gas capacity at year end.

Net acreage totaled 0.1 million onshore acres at year-end 2023.

Net acreage totaled 25 thousand onshore acres at year-end 2023.

During the year, a total of 1.1 net development wells were completed.

The North Field Production Sustainment Compression project was funded in 2022.

ExxonMobil also announced participation in Qatar's North Field East project via the Qatar Liquefied Gas Company Limited (QG7) venture, representing 18.5 thousand net acres and 8 million tonnes per year gross liquefied natural gas capacity expected to begin in 2026.

Effective October 14, 2022, the Russian government unilaterally terminated the Corporation's interests in Sakhalin, transferring operations to a Russian operator.

Refer to "Note 2:

Russia" of the Financial Section of this report for additional information.

ExxonMobil’s net onshore acreage in Thailand concessions totaled 16 thousand acres at year-end 2022.

In 2023, ExxonMobil completed a partial sale of 10 percent participating interest and in early 2024 closed on the sale of its remaining interest resulting in a full exit from the country.

Net acreage totaled 0.3 million acres at year-end 2023, of which 0.2 million acres were offshore.

During the year, a total of 1 net development wells were completed.

Development activities continued on the Tengiz Expansion project.

Net interests in production sharing contracts covered 0.2 million offshore acres at year-end 2023.

During the year, a total of 0.5 net development well was completed.

Through joint ventures with QatarEnergy, net acreage totaled 80 thousand offshore acres at year-end 2023.

During the year, a total of 4.7 net development wells were completed.

ExxonMobil participated in 52.3 million metric tons per year gross liquefied natural gas capacity and 3.4 billion cubic feet per day of flowing gas capacity at year-end.

Development activities continued on the North Field East project and North Field Production Sustainment projects.

Net acreage in concessions totaled 16 thousand onshore acres at year-end 2023.

During the year, a total of 0.2 net development wells were completed.

United Arab Emirates

ExxonMobil’s net acreage in the Abu Dhabi offshore Upper Zakum oil concession was 81 thousand acres at year-end 2022.

Net acreage in the Abu Dhabi offshore Upper Zakum oil concession was 81 thousand acres at year-end 2023.

During the year, a total of 3.1 net development wells were completed.

1 unchanged sentence

Australia / Oceania

ExxonMobil’s net acreage totaled 1.2 million offshore acres and 10 thousand onshore acres at year-end 2022.

In 2022, 0.6 million net offshore acres were relinquished.

The co-venturer-operated Gorgon Jansz liquefied natural gas (LNG) development consists of a subsea infrastructure for offshore production and transportation of the gas, a 15.6 million tonnes per year LNG facility and a 280 million cubic feet per day domestic gas plant located on Barrow Island, Western Australia.

Development activities continued on the Gorgon Stage 2 project and Jansz Io Compression project during the year.

Net acreage totaled 1.2 million offshore acres and nine thousand onshore acres at year-end 2023.

The co-venturer-operated Gorgon Jansz liquefied natural gas (LNG) development consists of a subsea infrastructure for offshore production and transportation of the gas, a 15.6 million metric tons per year LNG facility, and a 280 million cubic feet per day domestic gas plant located on Barrow Island, Western Australia.

During the year, development activities continued on the Gorgon Stage 2 project and Jansz Io Compression project.

Papua New Guinea

ExxonMobil’s net acreage totaled 2.1 million onshore acres at year-end 2022.

In 2022, ExxonMobil relinquished 1.2 million net offshore acres.

The Papua New Guinea (PNG) liquefied natural gas integrated development includes gas production and processing facilities in the PNG Highlands, onshore and offshore pipelines, and a 6.9 million tonnes per year liquefied natural gas facility near Port Moresby.

Net acreage totaled 2.1 million onshore acres at year-end 2023.

During the year, a total of 0.4 net development wells were completed.

The Papua New Guinea (PNG) liquefied natural gas (LNG) integrated development includes gas production and processing facilities in the PNG Highlands, onshore and offshore pipelines, and a 6.9 million metric tons per year LNG facility near Port Moresby.

Worldwide Exploration

At year-end 2022, exploration activities were under way in several areas in which ExxonMobil has no established production operations and thus are not included above.

A total of 18.8 million net acres were held at year-end 2022 and 1.2 net exploratory wells were completed during the year in these countries.

Exploration activities were under way in several countries in which ExxonMobil has no established production operations and thus are not included above.

Net acreage totaled 18.5 million acres at year-end 2023.

During the year, a total of 0.6 net exploratory well was completed.

Delivery Commitments

37 unchanged sentences

2,145 1,526 2,113 1,509

1,238 580 1,234 580

Europe 983 560 1,238 580

Africa 2,109 704 2,186 736

9 unchanged sentences

Total gross and net developed acreage 25,363 12,263 26,574 12,519

(1) Includes developed acreage in Other Americas of 490 gross and 311 net thousands of acres for 2022 and 2021.

(2) Year-end 2021 developed acreage in Europe was restated for gross and net.

(1) Includes developed acreage in Other Americas of 559 gross and 342 net thousands of acres for 2023 and 490 gross and 311 net thousands of acres for 2022.

Separate acreage data for oil and gas are not maintained because, in many instances, both are produced from the same acreage.

9 unchanged sentences

30,773 15,012 32,441 15,838

12,592 8,231 14,811 6,163

Europe 12,489 8,173 12,592 8,231

Africa 18,309 12,696 20,620 13,113

10 unchanged sentences

(1) Includes undeveloped acreage in Other Americas of 24,221 gross and 11,548 net thousands of acres for 2023 and 25,096 gross and 11,977 net thousands of acres for 2022.

(2) Year-end 2021 undeveloped acreage in Europe was restated for gross and net.

ExxonMobil’s investment in developed and undeveloped acreage is comprised of numerous concessions, blocks, and leases.

8 unchanged sentences

Mineral interest owners include the Federal and State governments, as well as private mineral interest owners.

Leases typically have an exploration period ranging from one to 10 years, and a production period that normally remains in effect until production ceases.

Under certain circumstances, a lease may be held beyond its exploration term even if production has not commenced.

Leases typically have a primary term ranging from one to 10 years, and a production period beyond the primary term that normally remains in effect until production ceases.

Under certain circumstances, a lease may be held beyond its primary term even if production has not commenced.

In some instances regarding private property, a “fee interest” is acquired where the underlying mineral interests are owned outright.

3 unchanged sentences

In general, these license and lease agreements are held as long as there is proven production capability on the licenses and leases.

Exploration licenses in offshore eastern Canada and the Beaufort Sea are held by work commitments of various amounts and rentals.

They are valid for a term of nine years.

Offshore exploration licenses are generally held by work commitments of various amounts and rentals.

Offshore production licenses are valid for 25 years, with rights of extension for continued production.

3 unchanged sentences

In 2019, the government granted three offshore exploration licenses, with terms of eight years, divided into two exploration periods of four years, with an optional extension of five years for each license.

The exploration and production of oil and gas are governed by concession contracts and production sharing contracts.

The exploration and production of oil and gas are governed by concession contracts and production sharing contracts (PSCs).

Concession contracts provide for an exploration period of up to eight years and a production period of 27 years.

Production sharing contracts provide for an exploration period of up to seven years and a production period of up to 28 years.

The Petroleum (Exploration and Production) Act authorizes the government of Guyana to grant petroleum prospecting and production licenses and to enter into petroleum agreements for the exploration and production of hydrocarbons.

Petroleum agreements provide for an exploration period of up to 10 years and a production period of 20 years, with a 10-year extension.

PSCs provide for an exploration period of up to seven years and a production period of up to 28 years.

The Petroleum Activities Act 2023 authorizes the Government of Guyana to license and enter petroleum agreements for petroleum exploration, development, production, and storage operations.

The Act enables petroleum agreements to provide for an exploration period to be established by subsidiary legislation by the Minister (typically up to 10 years) and provide for a production period of 20 years for an oil field and 30 years for a gas field, each with a renewal period of up to 10 years.

Exploration concessions are granted for an initial maximum period of five years, with an unlimited number of extensions up to three years each.

Extensions are subject to specific minimum work commitments.

Production licenses are normally granted for 20 to 25 years with multiple possible extensions subject to production on the license.

Production licenses were historically granted for 20 to 25 years with multiple possible extensions subject to production on the license.

Under the Mining Law, effective January 1, 2003, exploration and production licenses for both onshore and offshore areas are issued for a period as explicitly defined in the license.

18 unchanged sentences

The production period for crude oil is 30 years.

ExxonMobil is actively taking steps to exit its operations in the country.

Exploration and production activities are generally governed by concession contracts with the Government of the Republic of Mozambique, represented by the Ministry of Mineral Resources and Energy.

2 unchanged sentences

The EPCC expires 30 years after an approved plan of development becomes effective for a given discovery area.

In 2018, an interest was acquired in offshore blocks A5-B, Z5-C, and Z5-D.

Terms for the three blocks are governed by their respective EPCCs, with blocks Z5-C and Z5-D having an initial exploration phase that expired in 2022, resulting in a relinquishment of acreage in those blocks.

Block A5-B's initial exploration phase expires in 2023.

A5-B's EPCC provides a development and production period that expires 30 years after the approval of a plan of development.

Exploration and production activities in the deepwater offshore areas are typically governed by production sharing contracts (PSCs) with the national oil company, the Nigerian National Petroleum Corporation (NNPC).

NNPC typically holds the underlying Oil Prospecting License (OPL) and any resulting Oil Mining Lease (OML).

The terms of the PSCs are generally 30 years, including a 10-year exploration period (an initial exploration phase that can be divided into multiple optional periods) covered by an OPL.

Upon commercial discovery, an OPL may be converted to an OML.

Partial relinquishment is required under the PSC at the end of the 10-year exploration period, and OMLs have a 20-year production period that may be extended, subject to the partial relinquishment.

In August 16, 2021, the Petroleum Industry Act (PIA) was enacted to replace the Petroleum Act of 1969.

This granted Petroleum Prospecting Licenses (PPLs - replacing OPLs) with an initial term of five years and optional five-year extension.

Petroleum Mining Leases (PMLs - replacing OMLs) are granted for each commercial discovery in the PPL for a 20-year term.

The PIA also had a "savings provision" which allowed NNPC to renegotiate its PSCs and renew their OMLs for 20 years under existing 1969 Act terms, within 12 months from the enactment of the PIA.

On August 11, 2022, the leases for OML 133 and 138 were renewed under the savings provision.

OMLs granted under the 1969 Petroleum Act, which include all deepwater OMLs, have a maximum term of 20 years without distinction for onshore or offshore location and are renewable, upon 12-months written notice.

All future renewals will be conducted under PIA terms.

OMLs granted prior to the 1969 Petroleum Act (i.e., under the Mineral Oils Act 1914, repealed by the 1969 Petroleum Act) were for 30 years onshore and 40 years in offshore areas and have been renewed, effective March 11, 2011, for a further period of 20 years.

Operations under these pre-1969 OMLs are conducted under a joint venture agreement with NNPC rather than a PSC.

Commercial terms applicable to the existing joint venture oil production are defined by the Petroleum Profits Tax Act (PPT).

This was also repealed by the PIA in August 2021 with lease holders having the option to convert to PIA terms or retain PPT terms until their current leases expire.

In 2018, an interest was acquired in Area 5 offshore blocks A5-B, Z5-C, and Z5-D.

Blocks Z5-C and Z5-D were relinquished in 2022.

In 2023, the initial exploration phase expired on block A5-B, resulting in a relinquishment of the remaining Area 5 acreage.

Exploration and production activities in the deepwater offshore areas are governed by production sharing contracts (PSCs) with the national oil company, the Nigerian National Petroleum Company Limited (NNPCL).

NNPCL typically holds the underlying license or lease.

The terms of the PSCs are generally 30 years (comprised of a 10-year exploration period and a 20-year production period).

Exploration and production activities in the shallow-water offshore areas are governed by Oil Mining Leases granted prior to the 1969 Petroleum Act (i.e., under the Mineral Oils Act 1914, repealed by the 1969 Petroleum Act) and have been renewed in 2011 for a further period of 20 years.

Operations under these pre-1969 Oil Mining Leases are conducted under a joint venture agreement with NNPCL rather than a PSC.

Commercial terms applicable to the existing joint venture oil production are defined by the Petroleum Profits Tax Act.

The 2021 Petroleum Industry Act will govern any further renewals to the term of the PSCs, licenses, or leases.

The production sharing agreement (PSA) for the development of the Azeri-Chirag-Gunashli field was established for an initial period of 30 years starting from the PSA execution date in 1994.

7 unchanged sentences

The contract provides for cost recovery plus per-barrel fees for incremental production above specified levels.

In early 2024, ExxonMobil closed on the sale of its remaining interest resulting in a full exit from the country.

Onshore exploration and production activities are governed by the production license, exploration license, and joint venture agreements negotiated with the Republic of Kazakhstan.

9 unchanged sentences

Extensions and terms are subject to State of Qatar approval.

Terms for ExxonMobil’s Sakhalin acreage were fixed by a production sharing agreement between the Russian government and the Sakhalin-1 consortium, of which ExxonMobil was the operator.

Effective October 14, 2022, the Russian government unilaterally terminated the Corporation’s interests in Sakhalin, transferring operations to a Russian operator.

Refer to “Note 2:

Russia” of the Financial Section of this report for additional information.

The Petroleum Act of 1971 allows production under ExxonMobil’s concessions for 30 years with a 10-year extension at terms generally prevalent at the time.

18 unchanged sentences

Petroleum retention licenses are granted for an initial five-year period, and may only be extended, at the Minister’s discretion, twice for the maximum retention time of 15 years.

Information with regard to refining capacity:

ExxonMobil manufactures, trades, and sells petroleum products.

The refining and supply operations encompass a global network of manufacturing plants, transportation systems, and distribution centers that provide a range of fuels, lubricants, feedstocks, and other products to our customers around the world.

Refining Capacity At Year-End 2022 (1)

Share KBD (2)

Information with regard to refining and chemical capacity:

ExxonMobil manufactures, trades, and sells petroleum and petrochemical products.

Our refining and chemical operations are highly integrated and encompass a global network of manufacturing plants, transportation systems, and distribution centers that provide a range of fuels, specialty products, feedstocks, olefins, polyolefins, and a wide variety of other products to our customers around the world.

Capacity At Year-End 2023 (1)

Interest % ExxonMobil’s Share of Refining Capacity (2)

Ethylene Polyethylene Polypropylene

(thousands of barrels daily) (millions of metric tons per year)

United States

Joliet Illinois n 258 100

Baton Rouge Louisiana n ▲ 523 100

Montana n 60 100

Baytown Texas n ▲ 565 100

Beaumont Texas n ▲ 369 100

Joliet Illinois ■ 100 258 — — —

Baton Rouge Louisiana ■ ▲ ● 100 523 1.1 1.3 0.9

Baytown Texas ■ ▲ ● 100 565 4.0 — 0.8

Beaumont Texas ■ ▲ ● 100 609 0.9 1.7 —

Corpus Christi Texas ● 50 — 0.9 0.7 —

Mont Belvieu Texas ● 100 — — 2.3 —

Total United States 1,955 6.9 6.0 1.7

Strathcona Alberta n 197 69.6

Nanticoke Ontario n 113 69.6

Sarnia Ontario n 123 69.6

Strathcona Alberta ■ 69.6 197 — — —

Nanticoke Ontario ■ 69.6 113 — — —

Sarnia Ontario ■ ● 69.6 123 0.3 0.5 —

Total Canada 433 0.3 0.5 —

Antwerp Belgium n 307 100

Fos-sur-Mer France n 133 82.9

Gravenchon France n ▲ 244 82.9

Karlsruhe Germany n 78 25

Italy n 132 75

Rotterdam Netherlands n ▲ 192 100

Fawley United Kingdom n ▲ 262 100

Antwerp Belgium ■ ● 100 307 — 0.4 —

Meerhout Belgium ● 100 — — 0.5 —

Fos-sur-Mer France ■ 82.9 133 — — —

Gravenchon France ■ ▲ ● 82.9 / 100 (3)

244 0.4 0.4 0.3

Karlsruhe (4)

Germany ■ 25 78 — — —

Rotterdam Netherlands ■ ▲ ● 100 192 — — —

Fawley United Kingdom ■ ▲ ● 100 262 — — —

Fife United Kingdom ● 50 — 0.4 — —

Total Europe 1,216 0.8 1.3 0.3

Fujian China n 67 25

Jurong/PAC Singapore n ▲ 592 100

Thailand n 167 66

Fujian China ■ ● 25 67 0.3 0.2 0.2

Singapore Singapore ■ ▲ ● 100 592 1.9 1.9 0.9

Total Asia Pacific 659 2.2 2.1 1.1

Yanbu Saudi Arabia n 200 50

Al Jubail Saudi Arabia ▲ ● 50 — 0.7 0.7 —

Yanbu Saudi Arabia ■ ● 50 200 1.0 0.7 0.2

Total Middle East 200 1.7 1.4 0.2

Total Worldwide 4,463 11.9 11.2 3.3

n Energy Products ▲ Specialty Products

(1) Capacity data is based on 100 percent of rated refinery process unit stream-day capacities under normal operating conditions, less the impact of shutdowns for regular repair and maintenance activities, averaged over an extended period of time.

The listing excludes refining capacity for a minor interest held through equity securities in the Laffan Refinery in Qatar for which results are reported in the Upstream segment.

(2) Thousands of barrels per day (KBD).

ExxonMobil share reflects 100 percent of atmospheric distillation capacity in operations of ExxonMobil and majority-owned subsidiaries.

■ Energy Products ▲ Specialty Products ● Chemical Products

(1) ExxonMobil share reflects 100 percent for operations of ExxonMobil and majority-owned subsidiaries.

For companies owned 50 percent or less, ExxonMobil share is the greater of ExxonMobil’s interest or that portion of distillation capacity normally available to ExxonMobil.

(3) The Corporation announced sales agreements relating to these assets and expects the transactions to close in 2023.

(2) Refining capacity data is based on 100 percent of rated refinery process unit stream-day capacities to process inputs to atmospheric distillation units under normal operating conditions, less the impact of shutdowns for regular repair and maintenance activities, averaged over an extended period of time.

The listing excludes refining capacity for a minor interest held through equity securities in the Laffan Refinery in Qatar for which results are reported in the Upstream segment.

(3) ExxonMobil ownership in Gravenchon is split 82.9 percent and 100 percent between the refining and chemical operations, respectively.

(4) The Corporation announced a sales agreement relating to ExxonMobil's ownership interest in this asset and expects the transaction to close in 2024.

Due to rounding, numbers presented above may not add up precisely to the totals indicated.

Information with regard to retail fuel sites:

3 unchanged sentences

United States — 10,722 10,722

— 11,139 11,139

Canada — 2,477 2,477

197 5,830 6,027

Europe 169 3,573 3,742

Asia Pacific 284 931 1,215

563 1,438 2,001

Latin America — 523 523

1 unchanged sentence

Worldwide 622 18,481 19,103

(1) In October 2022, the Corporation reached an agreement with Par Pacific Holdings for the sale of the Billings refinery and select midstream assets, which includes about 300 retail fuel sites, and expects the transaction to close in 2023.

(2) In December 2022, the Corporation reached an agreement with Italiana Petroli for the sale of the Italy fuels business, which includes about 2,300 retail fuel sites, and expects the transaction to close in 2023.

(3) In January 2023, the Corporation announced the sale of its interest in Esso Thailand, which includes a network of about 800 retail fuel sites, and expects the transaction to close in 2023.

Information with regard to chemical complex capacity:

ExxonMobil manufactures and sells petrochemicals.

The large/integrated chemical complexes supply olefins, polyolefins, and a wide variety of other petrochemical products.

Chemical Complex Capacity At Year-End 2022 (1)

(millions of metric tons per year, unless otherwise noted) Ethylene Polyethylene Polypropylene ExxonMobil

North America

Baton Rouge Louisiana 1.1 1.3 0.9 100

Baytown Texas 4.0 — 0.7 100

Beaumont Texas 0.9 1.7 — 100

Corpus Christi Texas 0.9 0.7 — 50

Mont Belvieu Texas — 2.3 — 100

Sarnia Ontario 0.3 0.5 — 69.6

Total North America 7.2 6.5 1.6

Antwerp Belgium — 0.4 — 100

Fife United Kingdom 0.4 — — 50

Gravenchon France 0.4 0.4 0.3 100

Meerhout Belgium — 0.5 — 100

Total Europe 0.8 1.3 0.3

Al Jubail Saudi Arabia 0.7 0.7 — 50

Yanbu Saudi Arabia 1.0 0.7 0.2 50

Total Middle East 1.7 1.4 0.2

Fujian China 0.3 0.2 0.2 25

Singapore Singapore 1.9 1.9 0.9 100

Total Asia Pacific 2.2 2.1 1.1

Total Worldwide 11.9 11.2 3.2

(1) Capacity reflects 100 percent for operations of majority-owned subsidiaries.

For companies owned 50 percent or less, capacity is ExxonMobil’s interest.

Due to rounding, numbers presented above may not add up precisely to the totals indicated.

Compared sentence by sentence after normalising whitespace, quotation marks, case and digits, so re-formatting and restated figures do not read as changed language. Wording changes appear as one removal and one addition. The current filing and the prior one are authoritative.

What changed 10-K

Item 2. Properties