At California Resources Corporation (CRC), we believe transparent reporting of our environmental, social and governance (ESG) data enhances our stakeholder engagement, strengthens our performance, and further supports our role as a dependable and dedicated energy producer in the State of California. Accordingly, we have continued to expand our sustainability disclosures, and are providing the tables below to summarize a subset of our publicly reported ESG performance data. A PDF of these tables can also be downloaded for your convenience. Our Annual Report and Proxy Statement provide additional details on our financial and governance information. CRC’s 2030 Sustainability Goals and our ongoing sustainability strategy align with California’s climate goals under the Paris Climate Accord and its sustainable development by providing safe, affordable and reliable energy sources necessary to ensure human welfare and a more inclusive and equitable economy and society in the context of the United Nations’ Sustainable Development Goals.
For additional information, please refer to the following reference guides which identify sector-specific Sustainability Accounting Standards Board (SASB) guidelines and Global Reporting Initiative (GRI) Core Option standards that we find to be most important and relevant to all stakeholders and where those items are disclosed:
- SASB Index (PDF)
- GRI Index (PDF)
| UNITS | 2019 | 2018 | 2017 | Footnote | |
|---|---|---|---|---|---|
| Greenhouse Gas Emissions | |||||
| Percent of production subject to carbon tax | % | 100% | 100% | 96% | |
| Operated upstream direct emissions by source | Million tonnes CO2e | 1.2 | 1.5 | 1.5 | (a) |
| CO2 | Million tonnes CO2e | 1.1 | 1.4 | 1.4 | (a) |
| CH4 | Thousand tonnes CO2e | 99.1 | 98.0 | 165.7 | (a) |
| N2O | Thousand tonnes CO2e | 0.9 | 1.1 | 0.8 | (a) |
| Operated upstream & midstream direct emissions by source | (a), (b) | ||||
| Flaring/venting | % | 5.4% | 5.5% | 5.1% | (a), (b) |
| Fuel combustion | % | 94.3% | 94.3% | 93.0% | (a), (b) |
| Other | % | 0.3% | 0.2% | 1.9% | (a), (b) |
| Operated midstream emissions (gas processing + elec production) | Million tonnes CO2e | 2.0 | 2.0 | 2.1 | (b) |
| CO2 | Million tonnes CO2e | 2.0 | 2.0 | 2.0 | (b) |
| CH4 | Thousand tonnes CO2e | 7.5 | 12.9 | 4.9 | (b) |
| N2O | Thousand tonnes CO2e | 1.0 | 0.9 | 1.1 | (b) |
| Upstream greenhouse gas emission intensity | Tonnes CO2e/thousand BOE | 22.2 | 26.5 | 25.9 | (a) |
| Total GHG emissions from upstream and midstream operations | Million tonnes CO2e | 3.2 | 3.5 | 3.6 | (a), (b) |
| Volume of flared and vented hydrocarbons | MMSCF | 1,219.4 | 1,519.5 | 1,280.7 | |
| Flaring intensity | SCF/BOE | 23.2 | 27.4 | 21.5 | |
| Energy Use | |||||
| Production energy intensity | Gigajoules/BOE | 0.58 | 0.67 | 0.62 | (c) |
| Energy extracted (GJ) per energy used (GJ) | Unitless | 10.5 | 9.2 | 9.9 | (c) |
| Operated direct energy use for oil and gas production | Thousand gigajoules | 30,479 | 36,948 | 36,768 | (c) |
| Operated indirect energy use (electricity purchase) | Thousand gigajoules | 4,270 | 4,144 | 4,216 | (c) |
| Renewable energy used | Thousand MWh | 376 | 361 | 339 | (c) |
| Net purchased electricity by primary energy source | Thousand MWh | 1,186 | 1,151 | 1,171 | (c) |
| Renewable purchased electricity | Thousand MWh | 376 | 361 | 339 | (c) |
| Renewable % of purchased electricity | % | 32% | 31% | 29% | |
| Water Conservation | |||||
| Fresh water withdrawn from all operations | Gal/BOE | 33.7 | 34.5 | 28.5 | |
| Net fresh water used/(supplied) from all operations | Gal/BOE | (68) | (61) | (54) | |
| Potable water purchased | Acre-Feet | 481 | 619 | 412 | |
| Non-potable water purchased | Acre-Feet | 4,960 | 5,262 | 4,795 | |
| Total fresh water purchased | Acre-Feet | 5,441 | 5,881 | 5,207 | |
| Reclaimed water delivered to agriculture | Acre-Feet | 16,405 | 16,214 | 15,035 | |
| CRC water conservation ratio metric (reclaimed water to agriculture over purchased fresh water) | % | 302% | 276% | 289% | |
| Produced water reused/recycled/reclaimed | % | 90% | 89% | 89% | |
| Spills | |||||
| Number of reportable releases | # | 23 | 9 | 17 | (d) |
| Net oil released | Barrels | 134 | 192 | 46 | (d) |
| Oil spill prevention rate | % | 99.9997% | 99.9996% | 99.9999% | |
| Air Emissions | |||||
| Sulfur dioxide (SO2) | Tonnes | 30 | 29 | 30 | (a) |
| SO2 intensity | Tonnes/Million BOE | 0.57 | 0.52 | 0.50 | (a) |
| NOx | Tonnes | 271 | 363 | 428 | (a) |
| NOx intensity | Tonnes/Million BOE | 5.16 | 6.54 | 7.19 | (a) |
| Volatile organic compounds (VOC) | Tonnes | 399 | 457 | 445 | (a) |
| VOC intensity | Tonnes/Million BOE | 7.59 | 8.24 | 7.48 | (a) |
| Other Economic Indicators | |||||
| Environmental fines and penalties – operated | $ Million | $0.6 | $0.2 | $0.8 | |
| Environmental expenditures – remediation | $ Million | $1.3 | $3.2 | $1.0 | |
| Environmental expenditures – demolition and remediation | $ Million | $3.5 | $6.4 | $2.3 | |
| Percent of production and reserves on federal land | % | 4.80% | 4.46% | 4.20% | |
| Percent of production subject to carbon tax | % | 100% | 100% | 96% | |
| Taxes paid to CA state and local govt. | $ Million | $150 | $166 | $143 | (e) |
| Royalties paid to individuals, businesses and non-profits | $ Million | $222 | $208 | $127 | (f) |
| Exploration and Production | |||||
| Total net hydrocarbons produced | Thousand BOE/D | 128 | 132 | 129 | |
| Total gross hydrocarbons produced | Thousand BOE/D | 144 | 152 | 163 | |
| Proved reserves (total) | Million BOE | 644 | 712 | 618 | |
| Liquids (crude oil, condensate & NGLs) | % | 83% | 83% | 81% | |
| Natural Gas | % | 17% | 17% | 19% | |
| Reserve life | Years | 14 | 15 | 13 | |
| Organic reserve replacement ratio | % | 111% | 127% | 119% | (g) |
| Workforce Diversity | |||||
| Number of permanent employees | # | 1,251 | 1,502 | 1,448 | |
| Part-time employees | % | 0.24% | 0.00% | 0.00% | |
| Full-time employees | % | 99.76% | 100.00% | 100.00% | |
| Female employees | % | 20.46% | 19.57% | 19.20% | |
| Ethnically diverse employees | % | 35.49% | 33.75% | 32.73% | |
| Female senior managers | % | 24.14% | 17.86% | 18.18% | |
| Ethnically diverse senior managers | % | 24.14% | 14.29% | 15.15% | |
| Workforce Safety | |||||
| Fatalities – workforce (employees + contractors) | # | 0 | 0 | 0 | |
| Hours worked – workforce | Million hours | 9,337,897 | 10,100,148 | 8,348,295 | |
| Employee total recordable incident rate | Per 200,000 hours worked | 0.00 | 0.39 | 0.45 | |
| Contractor total recordable incident rate | Per 200,000 hours worked | 0.52 | 0.56 | 0.72 | |
| Workforce total recordable incident rate | Per 200,000 hours worked | 0.34 | 0.50 | 0.62 | |
| Employee lost time incident rate | Per 200,000 hours worked | 0.00 | 0.13 | 0.13 | |
| Contractor lost time incident rate | Per 200,000 hours worked | 0.13 | 0.17 | 0.19 | |
| Workforce lost time incident rate | Per 200,000 hours worked | 0.08 | 0.15 | 0.17 | |
| Social Investment | |||||
| Total social investment | $ Million | $4.3 | $3.1 | $1.7 | |
| Civic Empowerment | % | 35% | 30% | 43% | |
| Public Health, Safety & Environmental Stewardship | % | 18% | 24% | 18% | |
| Education and Job Training | % | 13% | 17% | 27% | |
| Military and Veterans Recognition | % | 35% | 29% | 11% | |
| 2019 Board of Directors | |||||
| Number of Independent Directors | # | 9 | 8 | 8 | |
| Percent independent | % | 90% | 80% | 80% | |
| Independent Chair | Y/N | Y | N | N | |
| Number of female Directors | # | 2 | 1 | 1 | |
| Percent female Directors | % | 20% | 10% | 10% | |
| Annual election of all Directors | Y/N | Y | Y | Y | |
| Annual Board performance reviews | Y/N | Y | Y | Y | |
| Compensation | |||||
| Total compensation of median employee (excl. CEO) | $ | $154,051 | $145,578 | $142,136 | |
| Percent of CEO annual incentive compensation related to HSE targets | % | 10% | 5% | 10% | |
| Annual advisory say on pay support | % | 97% | 97% | 85% | |
(a) Direct upstream emissions include Scope 1 GHG emissions from oil and gas drilling and production at fields operated by CRC and exclude those from the midstream operations of the Elk Hills gas and power plants, Ventura gas plant and Long Beach power plant. Emissions for 2019 do not include the portion of the Lost Hills field that was sold on May 1, 2019. Emissions are calculated in accordance with California regulations and emissions estimation protocols.
(b) Total direct emissions include direct upstream emissions plus Scope 1 GHG emissions from the midstream operations of the Elk Hills and Long Beach power plants, as well as gas processing at Elk Hills and Santa Clara Valley Gas Plants.
(c) Energy use and intensity exclude energy used by the midstream operations of the Elk Hills and Long Beach power plants, as well as gas processing at Elk Hills and Santa Clara Valley Gas Plants.
(d) Reportable release definitions vary by location. Any volume of oil released into state waters must be reported in California. Net oil released means the volume of oil and condensate spilled in reportable releases outside of containment and not recovered in liquid form.
(e) Taxes include state and local property, sales, use, severance and payroll taxes, and exclude GHG allowances.
(f) Excludes payments made to the State Lands Commission.
(g) See CRC.com, Investor Relations for a discussion of these performance and non-GAAP measures, including a reconciliation to the most closely related GAAP measure or information on the related calculations.
