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We demonstrate our commitment to transparency by reporting metrics and performance data annually so we can hold ourselves responsible for our progress and our stakeholders can hold us accountable.
The chart generator shows data for three new metrics currently reported in the October version of our 2021 Climate Change Resilience Report. These metrics include portfolio carbon intensity, refinery carbon intensity, and enabled reductions.
The remainder of the data reflects metrics as currently reported in our 2020 Corporate Sustainability Report.
Data restatements are available for review in the ESG Performance Data Table. We consider reporting guidelines, indicators and terminology from IPIECA, the International Oil and Gas Producers (IOGP) Association, the American Petroleum Institute (API), as well as other leading reporting frameworks, to determine which data to report and how to report our data.
Year 2020 performance data reflect varying impacts from changing market conditions and COVID-19.
global notes from 2021 Corporate Sustainability Report
- All restatements for greenhouse gas (GHG) emissions, associated emissions intensities, the category of energy efficiency and the category of water withdrawn are restated against the March 2021 release of the Climate Change Resilience: Advancing a Lower-Carbon Future report. All other restatements are restated against the May 2020 release of the 2019 Corporate Sustainability Report.
- We used the general SASB topics to organize Chevron’s table and provide an index column to identify common reporting elements between our current reporting data and the related SASB standards. The SASB index is based solely on Chevron’s interpretation and judgment. The inclusion of the SASB index does not indicate the application of definitions, metrics, measurements, standards or approaches set forth in the SASB framework. Please refer to the relevant footnotes for information about Chevron’s data-reporting basis. As reflected in the table, Chevron currently discloses data on a number of issues recommended in the SASB Oil and Gas Exploration and Production, Midstream, and Refining and Marketing standards. Further, there are many topics on which Chevron discloses data beyond the SASB framework.
SASB recommendations not addressed in the data table are being studied by Chevron for potential future inclusion. Chevron could determine that some SASB recommendations do not reflect useful sustainability performance information or would be overly burdensome to implement on a global basis; such disclosures will not be included in a future data table. We strive to continually improve our data- performance reporting, and we believe that our SASB index is a positive step in further aligning our ESG reporting to SASB framework recommendations. We also continue to assess alignment with other emerging frameworks.
- Our performance data table includes an index column that maps Chevron’s data to the corresponding relevant 2020 IPIECA standards.
- Numbers in table may not sum due to rounding.
- Unless otherwise noted, this section reflects 2020 data collected as of May 6, 2021. All data are reported on an operated basis unless otherwise noted.
- The “w” identifies common reporting elements between our current reporting data and the related September 2020 World Economic Forum (WEF) sustainability metrics. The WEF indictor symbol is based solely on Chevron’s interpretation and judgment. The inclusion of the WEF indicator symbol does not indicate the application of definitions, metrics, measurements, standards or approaches set forth in the WEF sustainability metrics.
- The World Resources Institute/World Business Council for Sustainable Development Greenhouse Gas Protocol: A Corporate Accounting and Reporting Standard defines three “scopes” that Chevron uses to report GHG emissions.
- Emissions reported are net (Scope 1 and Scope 2). The emissions included in the metrics generally represent Chevron’s equity share of emissions, which are emissions from operated and nonoperated joint-venture (NOJV) assets based on Chevron's financial interest. The scope may include sources outside traditional scoping of equity emissions, including captive emissions from processes like drilling and completions, and tolling agreements up to the point of third-party custody transfer of the oil or gas product. For oil and gas production intensity metrics, production is aligned with net production values reported in the Chevron Corporation Supplement to the Annual Report, which represent the Company’s equity share of total production after deducting both royalties paid to landowners and a government’s agreed-upon share of production under a Production Sharing Agreement. Chevron’s equity-share emissions include emissions associated with these excluded royalty barrels in accordance with IPIECA guidance. Also in accordance with IPIECA guidance, Chevron’s equity-share emissions do not include emissions associated with royalty payments received by the Company. Allocation of emissions between oil and gas is based on the fraction of production represented by liquids or gas. Flaring and methane intensities use the total of liquids and gas production. Oil and gas production intensities use liquids production and natural gas production, respectively.
- Scope 1 includes direct emissions. Direct GHG emissions related to production of energy in the form of electricity or steam exported or sold to a third party are included in the reported Scope 1 emissions to align with IPIECA’s Sustainability Reporting Guidance for the Oil and Gas Industry (2020). Chevron’s Scope 1 includes emissions of six Kyoto GHGs—carbon dioxide (CO2), methane (CH4), nitrous oxide (N2O), sulfur hexafluoride, perfluorocarbons and hydrofluorocarbons. Calculation methods are based on API’s Compendium of Greenhouse Gas Emissions Methodologies for the Oil and Natural Gas Industry (2009) or, where relevant, local regulatory reporting methodologies.
- Where limited emissions information is available for NOJVs, Chevron's equity share of total CO2-equivalent (CO2e) emissions is allocated to Scope 1 CO2 emissions.
- Restated 2016–2019 Scope 1 equity emissions include Chevron's equity-share emissions for Chevron Phillips Chemical Company LLC (CPChem) and reporting improvements. Additionally, restated 2019 Scope 1 equity emissions include Chevron’s equity-share emissions for NOJVs in which Chevron has less than a 16 percent equity share (where previously excluded).
- Chevron’s equity-share emissions for Loma Campana concession excluded for 2016–2018 and included for 2019–2020. Restated 2018 and 2019 numbers include Chevron’s equity-share emissions for Clair Ridge NOJV. Chevron’s equity-share emissions for CalBioGas LLC and Brightmark RNG Holdings LLC NOJVs excluded for 2020.
- As governments update their Global Warming Potentials (GWPs), we anticipate updating methane data reporting in our environmental tables and the associated performance evaluation. For transparency, and to enable stakeholders to make their own calculations based on their preferred timeline and GWPs, we provide methane emissions data and intensity performance as a mass of methane as well as its conversion under the AR4 100-year GWP to a CO2-equivalent. Although we strive to provide consistent data from our operated and nonoperated assets, some nonoperated assets may provide their data only on a CO2e basis. Given the common industry practice of using the AR4 100-year GWP, we have assumed that those nonoperated assets that did not provide methane mass data use a 100-year GWP of 25. We continue to work with our joint-venture partners to provide information on a standardized basis to increase transparency.
- Downstream includes emissions from refineries and terminals. Chemical and base oil facilities located within refineries are included in refinery emissions.
- Chemicals includes emissions from stand-alone chemical, additive and lubricant facilities.
- Other emissions include GHG emissions from Chevron Power and Energy Management, Corporate Aviation, Chevron Environmental Management and Real Estate Company, and North American Data Center.
- Upstream flaring emissions closely represent the contribution of flaring to Chevron’s total GHG emissions.
- Exported emissions are direct GHG emissions related to production of energy in the form of electricity or steam that are exported or sold to a third party.
- Scope 2 includes indirect emissions from imported electricity and steam. CO2, CH4 and N2O are accounted for in Chevron’s Scope 2 emissions. Scope 2 emissions are accounted for using the market-based approach as described in the World Resources Institute’s GHG Protocol Scope 2 Guidance (2015).
- For equity reporting, sales or storage of company CO2 (Chevron and NOJV) includes both CO2 sold to third parties and CO2 (and other gas) injected for carbon storage. Credits generated from CO2 injection by NOJV partners may be sold. For operated reporting, sales or storage of company CO2 (Chevron) includes both CO2 sold to third parties and CO2 (and other gas) injected for carbon storage.
- For equity reporting, purchase or injection includes third-party CO2 purchased and injected for enhanced oil recovery, excluding equity-share NOJV data. For operated reporting, purchase or injection includes third-party CO2 purchased and injected for enhanced oil recovery.
- Includes offsets retired in compliance programs. For programs with multiyear compliance periods, offsets are apportioned according to the compliance obligation for each year.
- Excludes offsets sold as part of a divestiture. Offsets are reported for the year in which the offset was generated (vintage year) only if subsequently sold.
- Chevron calculates emissions from third-party use of our products in alignment with methods in Category 11 of IPIECA’s Estimating Petroleum Industry Value Chain (Scope 3) Greenhouse Gas Emissions (2016). Emissions are based on aggregate production, throughput and sales numbers that include renewable fuels.
- Annual third-party verification covers Scope 1 and Scope 2 equity emissions, as first reported in Chevron’s Corporate Sustainability Report for each reporting year, but generally does not cover subsequent restatements and does not include Chevron equity-share emissions for CPChem.
- In the course of normal business processes, Chevron seeks limited assurance of prior-year GHG emissions data for publication in its Corporate Sustainability Report.
- Manufacturing Energy Index (Refining) is an analysis of Chevron’s refining energy performance based on the Solomon Energy Intensity Index methodology. Chevron’s MEI includes the refining assets at Chevron’s operated and non- operated joint-venture refineries.
- Pipeline Energy Intensity for 2020 does not include Noble Midstream Partners LP.
- Chevron’s Non-Manufacturing Energy Index includes Chevron’s terminals, chemical, additives and lubricant facilities. It reflects the energy required to produce Chevron products compared with the energy that would have been required to produce the same products in 1992 (the index’s base year).
- For compiling and reporting air emissions data, Chevron follows regulatory definitions of VOC. SOX emissions include SO2 and SO3, reported as SO2- equivalent. NOX emissions include NO and NO2 (reported as NO2-equivalent) and exclude N2O.
- Fresh water withdrawn from the environment is defined per local legal definitions. If no local definition exists, fresh water is defined as water extracted, directly or indirectly, from surface water, groundwater or rainwater that has a total dissolved- solids concentration of less than or equal to 2,000 mg/L. Fresh water withdrawn does not include effluent or recycled/reclaimed water from municipal or other industrial wastewater treatment systems, as this water is reported under nonfresh water withdrawn. Nonfresh water withdrawn could include: seawater; brackish groundwater or surface water; reclaimed wastewater from another municipal or industrial facility; desalinated water; or remediated groundwater used for industrial purposes. Produced water is excluded from fresh water withdrawn, fresh water consumed and nonfresh water withdrawn. Water quantities may be determined using direct measurement techniques or engineering estimation methods. Fresh water and nonfresh water withdrawn totals decreased in 2020 in part due to decreased activity across operations.
Refining includes data from refineries, including chemical and base oil facilities located within refineries.
Other includes, but is not limited to, chemical and lubricant facilities, as well as Chevron Environmental Management and Real Estate Company.
Chevron calculates fresh water withdrawn intensity for Upstream using gross operated production.
Chevron calculates fresh water withdrawn intensity for refining using total refinery inputs, which comprise all feeds into the refinery. This includes purchased crudes for crude units and third-party feeds for other processing units.
Oil concentration is determined by the sampling of effluent streams, using methods required or recommended by regulatory agencies or authorities, where applicable. Chevron reports the total cumulative amount of oil discharged to surface water excluding spills, which are reported separately.
Chevron reports petroleum spills to land and water to conform to the 2020 IPIECA Reporting Guidance. Spills to land and water that are greater than or equal to one barrel are included. Spills to secondary containment, chemical spills and spills due to sabotage are excluded. Accidental release prevention and response data for 2020 do not include data for the former Noble Energy, Inc. assets.
To conform to the 2015 and 2020 IPIECA Reporting Guidances, and where appropriate information and data exist, our hazardous waste numbers starting in 2015 exclude remediation waste generated; disposed of; and recycled, reused or recovered. Hazardous waste amounts are quantified using methods required or recommended by regulatory agencies or authorities, where applicable. In other instances, similar methods are used, including direct measurement onsite or at the point of shipping, engineering estimates and process knowledge. Chevron follows the regulatory definitions of hazardous waste applicable to the jurisdictions in which we operate, including de minimis specifications (below which hazardous waste quantities do not need to be reported).
The 2020 data are based on information received from government entities and recorded internally as of April 14, 2021.
Global employee diversity and U.S. Equal Employment Opportunity Commission percentages have been rounded to the nearest whole percentage. Global data are as of December of the year identified. Although gender is not binary, gender is currently reported in binary (men, women) terms to align with U.S. government reporting regulations. Our most recently filed Federal Employer Information Report EEO-1 is available for download at chevron.com/eeo-1. EEO-1 gender and ethnicity counts may vary from other methodologies.
Ethnicities with representation less than 2 percent such as, but not limited to, Native Americans, Pacific Islanders, and Two or More Races.
Unless otherwise indicated, 2020 data include employees from 2020 acquisitions of Puma Energy (Australia) Holdings Pty Ltd and Noble Energy, Inc., where applicable. Data for all years do not include service station employees unless specifically stated.
Excludes data from 2020 acquisitions of Puma Energy (Australia) Holdings Pty Ltd and Noble Energy, Inc., pending integration of HR information systems.
For years 2016–2018, data collected as of February 20, 2019. For year 2019, data collected as of January 23, 2020. For year 2020, data collected as of February 24, 2021.
This section reflects Chevron data collected as of March 12, 2021, and excludes data from the 2020 acquisition of Noble Energy, Inc., pending integration of safety data systems. Health and safety performance rates include both injury- and illness-related incidents. API’s Benchmarking Survey of Occupational Injuries, Illnesses and Fatalities in the Petroleum Industry data, used in previous years as industry benchmarks, are no longer provided by API as of 2020.
Serious injuries are injuries that result in significant disfigurement, or typically result in permanent or long-term impairment of an internal organ, body function or body part.
Data include catastrophic and major incidents only.
Process Safety Tier 1 loss-of-primary-containment (LOPC) events are unplanned or uncontrolled releases resulting in consequences equivalent to those specified by American National Standards Institute/American Petroleum Institute (ANSI/API) Recommended Practice (RP) IOGP Report 456: Process Safety Recommended Practice on Key Performance Indicators.
Enabled emissions reductions are the estimated avoided emissions relative to fossil fuel use primarily associated with biofuels, hydrogen, CCUS, and offsets that the Company has marketed in the most recent calendar year, regardless of whether the Company retained rights to the emissions-reduction attributes.
Avoided emissions associated with natural gas–fired power generation via co-generation or coal-fired power generation displacement are excluded from this calculation for purposes of simplicity.
For biofuels and hydrogen products, the enabled emissions reductions are calculated based on the lifecycle GHG savings relative to the same amount of energy provided by diesel fuel. Where appropriate, energy efficiency factors are used to calculate the volumes of displaced fossil fuels. More details on emissions factors and calculation assumptions are available in the PCI methodology note (see pages 59–60).
Net GHG removal emissions associated with CCUS and offsets represent the volume of emissions that would be sequestered or utilized in other products. GHG emissions associated with CCUS or offset value chains would be netted from the reductions associated with the activity.
global notes from 2021 Climate Change Resilience Report
†Portfolio carbon intensity is calculated as described in the methodology on pages 59–60. Inputs are collected from financial disclosures and public GHG reporting, with the exception of the biofuels
component. Biofuel volumes are based on purchase data for ethanol, renewable diesel, sustainable aviation fuel, and biodiesel and production volumes for renewable natural gas in the United States,
Hong Kong, Malaysia, Philippines, Thailand, and Australia. Volumes from international GS Caltex operations in South Korea are assumed to be zero. For 2016–2020, aggregate biofuel volumes used
in the PCI calculation are 60,000, 58,000, 59,000, 64,000, and 57,000 barrels of oil-equivalent per day, respectively. Biofuel carbon-intensity values are based on California Air Resources Board
(CARB) Low Carbon Fuel Standard (LCFS) default pathway values. For 2016–2020, the weighted-average biofuel carbon-intensity values used in the PCI calculation were 52, 54, 53, 51, and 50 grams
carbon dioxide–equivalent GHG emissions per megajoule, respectively.
††The refining carbon intensity (RCI) provides a measure of GHG released during the transformation of raw materials into refined products. The RCI is throughput-based and includes GHG emissions from Chevron’s own refining operations and estimates of emissions associated with third-party processing of imported feedstocks such as hydrogen. Emissions from third-party processing of imported feedstocks are estimated using information including supplier data, industry segment averages, and engineering estimates. Emissions included in the calculation represent refinery processing only and do not include terminals or chemical, additive, base oil, and lubricant facilities not integrated into a refinery. Feedstocks include hydrogen and intermediate products that will be further refined or used in conversion units. Feedstocks do not include natural gas used as fuel or products intended solely for blending into finished products. Feedstocks are assessed on a net basis (imports minus exports).
§The refining carbon intensity in 2020 reflects decreased refinery utilization due to demand changes associated with the COVID-19 pandemic.