Our Performance

We use key metrics to measure and monitor our performance and progress managing sustainability risks. This data is presented by year or by country and easily downloaded as XLS or PDF spreadsheets.

Performance by year
Performance metrics by Country
AXPC ESG metrics template
API template for GHG reporting

Performance by year1

Net Equity Total2,3

METRIC 2019 2020 2021 20224 20234 GRI IPIECA SASB
CLIMATE
Net Equity Greenhouse Gas Emissions (thousand tonnes CO2e) n/a 16,700 18,300 18,358 20,070   CCE-4  
Net Equity GHG Intensity (kg CO2e/BOE) 5 n/a 40.8 32.9 28.9 30.1 305-4 CCE-4  
Target Related Net Equity Intensity (kg CO2e/BOE) 6 n/a 40.2 32.4 28.5 29.7 305-4 CCE-4  

Operated Total7

METRIC 2019 2020 2021 20224 20234 GRI IPIECA SASB
CLIMATE AND AIR EMISSIONS
GHG Intensity (kg CO2e/BOE)
Total GHG Intensity 36.5 34.3 26.9 23.3 25.3 305-4 CCE-4  
Target Related GHG Intensity 6 35.9 33.8 26.6 22.9 24.9 305-4 CCE-4  
GHGs (thousand tonnes)
CO2 from Operations 17,700 13,800 15,900 13,229 13,113 305-1 CCE-4  
CO2 from Imported Electricity (Scope 2) 1,000 700 1,000 1,060 1,001 305-2 CCE-4  
Methane (CO2e) 8 1,700 1,600 1,800 1,758 3,298 305-1 CCE-4  
Nitrous Oxide (CO2e) 100 100 20 21 21 305-1 CCE-4  
Total GHGs (thousand tonnes CO2e) 20,500 16,200 18,720 16,068 17,433   CCE-4  
CO2e Per Dollars of Revenue (tonnes/$thousand) 9 0.63 0.86 0.41 0.20 0.31 305-4    
Potential CO2e from Proved Reserves (million tonnes) 2,190 1,875 2,525 2,699 2,821     EM-EP 420a.2
Scope 1 Emissions by Source Category (thousand tonnes CO2e)10
Flaring 2,300 1,300 1,900 1,560 2,283 305-1 CCE-4  
Combustion 15,200 12,300 13,800 11,536 11,402 305-1 CCE-4  
Process Venting 1,500 1,500 1,500 1,461 2,599 305-1 CCE-4 EM-EP 110a.2
Fugitive Venting 200 200 220 168 147 305-1 CCE-4 EM-EP 110a.3
Other 11 300 200 300 282 <1 305-1 CCE-4  
Total Scope 1 Emissions 19,500 15,500 17,720 15,008 16,432 305-1 CCE-4 EM-EP 110a.1
Percent of Scope 1 Emissions Covered by Regulation 40% 40% 38% 43% 39%     EM-EP 110a.1
Methane
Methane Intensity (kg CO2e/BOE) 8 3.0 3.4 2.6 2.6 4.8   CCE-4  
Methane Emitted as Percent of Natural Gas Production 0.24% 0.28% 0.23% 0.30% 0.61%   CCE-4 EM-EP 110a.1
Methane Emitted as Percent of Total Hydrocarbon Production 0.08% 0.10% 0.07% 0.07% 0.14%   CCE-4 EM-EP 110a.1
Methane Emitted as Percent of Scope 1 Emissions 9% 10% 10% 12% 20%   CCE-4  
Flaring
Routine Flaring Volume (million cubic feet) 12 n/a n/a 1,030 111 13 305-1 CCE-7  
Total Flaring Volume (million cubic feet) 13 24,600 14,500 20,500 17,858 21,867 305-1 CCE-7 EM-EP 110a.2
Flaring Intensity (Total Flaring Volume as Percent of Gas Produced) 2.60% 1.97% 1.81% 2.39% 3.36%      
Flaring Intensity (Total Flaring Volume MMSCF/Total Production MMBOE) 43.8 30.8 29.5 25.9 31.8      
Other Air Emissions (tonnes)
Volatile Organic Compounds (VOCs) 69,900 60,800 96,400 98,508 115,587 305-7 ENV-5 EM-EP 120a.1
Nitrogen Oxides (NOx) 36,100 28,200 42,000 48,528 47,682 305-7 ENV-5 EM-EP 120a.1
Sulfur Oxides (SOx) 4,700 2,700 2,900 2,701 2,607 305-7 ENV-5 EM-EP 120a.1
Particulate Matter (PM) 1,400 1,100 1,700 1,978 1,818 305-7 ENV-5 EM-EP 120a.1
Energy Use (trillion BTUs)
Combustion Energy 217 179 211 199 197      
Imported Electricity 4 4 6 8 8      
Total Energy 222 183 217 206 205 302-1 CCE-6  
Energy Intensity (trillion BTUs/MMBOE) 0.40 0.39 0.31 0.30 0.30 302-3 CCE-6  
ENVIRONMENT
Water
Fresh Water Withdrawn (million cubic meters) 14.4 10.6 9.7 9.2 10.5 303-3 ENV-1 EM-EP 140a.1
Fresh Water Consumed (million cubic meters) 14 12.1 8.5 7.5 7.3 8.5 303-5 ENV-1 EM-EP 140a.1
Fresh Water Withdrawn in Regions with High Baseline Water Stress 15 8.0% 5.0% 17.0% 6.3% 14.7% 303-3 ENV-1 EM-EP 140a.1
Fresh Water Consumed in Regions with High Baseline Water Stress 16 8.0% 2.0% 20.0% 2.4% 18.3% 303-5 ENV-1 EM-EP 140a.1
Non-Fresh Water Withdrawn (million cubic meters) 17 51.3 48.7 55.3 52.6 0.5 303-3 ENV-1  
Total Produced Water Recycled or Reused (million cubic meters) 18 82.3 63.8 80.0 74.0 73.6   ENV-1 EM-EP 140a.2
Municipal Wastewater Reused (million cubic meters) n/a n/a 1.3 1.8 0.5   ENV-1  
Produced Water Recycled or Reused 66% 67% 48% 49% 46%   ENV-1 EM-EP 140a.2
Produced Water Injected or Disposed 22% 16% 42% 41% 44% 303-4 ENV-2 EM-EP 140a.2
Produced Water Discharged Offshore 12% 17% 10% 10% 11% 303-4 ENV-2 EM-EP 140a.2
Hydrocarbons in Overboard Discharges (tonnes) 145 124 147 129 129   ENV-2 EM-EP 140a.2
Water Intensity
Unconventional Fresh Water Consumption (barrels/BOE EUR) 19 0.22 0.23 0.08 0.06 0.06   ENV-1  
Conventional Fresh Water Consumption (barrels/BOE) 20 0.05 0.05 0.03 0.03 0.03   ENV-1  
Biodiversity
Operated Area Overlapping With IUCN Protected Areas 21 0.25% 0.24% 0.03% 0.04% 0.03% 304-1 ENV-4  
Number of IUCN Protected Areas Near Operated Assets 21 7 7 8 10 12 304-1 ENV-4  
Habitat Areas Protected or Restored by ConocoPhillips (thousand acres) 22 316 275 550 409 540 304-3 ENV-4  
Number of Operated Assets with IUCN Red List Species 23 15 13 12 12 9 304-4 ENV-4  
Liquid Hydrocarbon Spills to the Environment24
Number of Spills > 100 Barrels 2 1 4 2 0 306-3 ENV-6 EM-EP 160a.2
Volume of Spills > 100 Barrels (barrels) 1,100 100 734 299 0 306-3 ENV-6 EM-EP 160a.2
Number of Spills > 1 Barrel 89 83 178 99 38 306-3 ENV-6 EM-EP 160a.2
Volume of Spills > 1 Barrel (barrels) 1,800 600 2,194 861 303 306-3 ENV-6 EM-EP 160a.2
Volume Recovered from Spills > 1 Barrel (barrels) 1,200 400 1,410 496 155   ENV-6 EM-EP 160a.2
Liquid Hydrocarbon Spills in the Arctic25
Number of Arctic Spills > 1 Barrel 1 1 3 1 2     EM-EP 160a.2
Volume of Arctic Spills > 1 Barrel (barrels) 2 2 5 5 7     EM-EP 160a.2
Volume Recovered From Arctic Spills > 1 Barrel (barrels) 2 2 5 5 7     EM-EP 160a.2
Wastes (tonnes)26, 27
Hazardous Wastes 21,900 28,200 23,000 78,600 107,611 306-3 ENV-7  
Nonhazardous Wastes 279,000 159,400 213,200 322,489 1,352,155 306-3 ENV-7  
Recycled Wastes 130,400 107,500 191,700 265,508 38,075 306-4 ENV-7  
Total Waste Generated 431,300 295,100 427,900 666,596 1,497,841 306-3 ENV-7  
Waste Disposed 300,900 187,600 236,200 401,088 1,459,766 306-3 ENV-7  
SAFETY
Safety (rate per 200,000 hours worked)
Workforce Fatalities 1 0 0 0 1 403-9 SHS-3 EM-EP 320a.1
Workforce Total Recordable Rate 0.15 0.12 0.15 0.14 0.17 403-9   EM-EP 320a.1
Workforce Lost Workday Rate 0.03 0.04 0.04 0.04 0.04      
Employee Total Recordable Rate 0.05 0.09 0.14 0.12 0.19 403-9-a-iii SHS-3  
Employee Lost Workday Rate 0.03 0.02 0.05 0.06 0.05   SHS-3  
Contractor Total Recordable Rate 0.18 0.13 0.16 0.14 0.16 403-9-b-iii SHS-3  
Contractor Lost Workday Rate 0.03 0.04 0.04 0.04 0.04   SHS-3  
Process Safety (rate per 200,000 hours worked by operations)
Tier 1 Process Safety Event Rate 28 0.03 0.03 0.09 0.05 0.04   SHS-6 EM-EP 540a.1
SOCIAL
Economic Contribution
Payments to Vendors and Suppliers ($ billion) 29 9.4 7.3 7.9 10.9 12.5      
Shareholder Dividends ($ billion) 1.5 1.8 2.4 5.7 5.6      
Capital Investments ($ billion) 6.6 4.7 5.3 10.2 11.2      
Cash Contributions ($ million) 43.9 31.3 33.6 33.9 33.8   SOC-13  
Global Workforce
Employees at Year-End 30 10,400 9,700 9,900 9,500 9,900 2-7-a SOC-5  
Part-Time Employees 1.4% 1.0% 0.9% 0.7% 0.6% 2-7-b SOC-5  
Employees - Women 26% 27% 26% 27% 27% 405-1-b-i SOC-5  
All Leadership - Women 24% 23% 25% 26% 26% 2-7-a SOC-5  
Top Leadership - Women 20% 19% 22% 25% 26% 2-7-a SOC-5  
Junior Leadership - Women 25% 24% 25% 26% 26% 2-7-a SOC-5  
Professional - Women 28% 29% 29% 30% 30% 2-7-a SOC-5  
Petrotechnical - Women 20% 20% 20% 21% 21% 2-7-a SOC-5  
Non-U.S. Employees 45% 41% 39% 34% 34%   SOC-5  
All Non-U.S. Leadership 47% 44% 41% 35% 33%   SOC-5  
Non-U.S. Top Leadership 31% 25% 24% 23% 23%   SOC-5  
Non-U.S. Junior Leadership 50% 49% 44% 37% 35%   SOC-5  
Avg. Years of Service 11.4 11.9 11.3 10.9 10.9   SOC-5  
Avg. Years of Experience 17.5 17.9 17.5 17.5 17.9   SOC-5  
Employees by Age Group             SOC-5  
Under 30 8% 8% 8% 8% 7% 405-1-b-ii SOC-5  
30 - 50 60% 60% 62% 62% 61% 405-1-b-ii SOC-5  
51+ 31% 33% 30% 31% 31% 405-1-b-ii SOC-5  
U.S. Workforce Demographics31
Employees - POC 32 24% 25% 28% 30%   405-1-b-iii SOC-5  
All Leadership - POC 19% 19% 21% 23%   405-1-b-iii SOC-5  
Top Leadership - POC 13% 13% 15% 18%   405-1-b-iii SOC-5  
Junior Leadership - POC 21% 22% 23% 25%   405-1-b-iii SOC-5  
Professional - POC 24% 24% 26% 28%   405-1-b-iii SOC-5  
Employees covered by a collective bargaining agreement 4% 4% 4% 4%   2-30-a SOC-5  
Veterans 6% 6% 6% 6%   405-1-b-iii SOC-5  
Employees with disabilities n/a 5% 5% 5%   405-1-b-iii SOC-5  
U.S. Employees by race/ethnicity and gender
White Women 20.9% 21.2% 20.0% 19.9% 19.0% 405-1-b-iii SOC-5  
White Men 54.6% 54.0% 51.8% 49.9% 49.2% 405-1-b-iii SOC-5  
Hispanic Women 2.5% 2.6% 3.0% 3.6% 3.9% 405-1-b-iii SOC-5  
Hispanic Men 7.9% 7.8% 11.7% 12.0% 12.4% 405-1-b-iii SOC-5  
Asian Women 2.0% 2.0% 1.9% 2.1% 2.1% 405-1-b-iii SOC-5  
Asian Men 4.7% 4.7% 4.2% 4.3% 4.5% 405-1-b-iii SOC-5  
Black/African American Women 1.8% 1.8% 1.6% 1.7% 1.8% 405-1-b-iii SOC-5  
Black/African American Men 2.2% 2.3% 2.2% 2.5% 2.6% 405-1-b-iii SOC-5  
American Indian or Alaska Native Women 1.0% 0.9% 0.9% 1.0% 1.1% 405-1-b-iii SOC-5  
American Indian or Alaska Native Men 1.6% 1.6% 1.3% 1.4% 1.5% 405-1-b-iii SOC-5  
Native Hawaiian or Pacific Islander Women 0.1% 0.1% 0.1% 0.1% 0.1% 405-1-b-iii SOC-5  
Native Hawaiian or Pacific Islander Men 0.1% 0.2% 0.1% 0.1% 0.1% 405-1-b-iii SOC-5  
Two+ races Women 0.2% 0.3% 0.4% 0.5% 0.6% 405-1-b-iii SOC-5  
Two+ races Men 0.3% 0.5% 0.5% 0.9% 1.1% 405-1-b-iii SOC-5  
Hiring (Global unless identified as U.S.)
University Hires 12% 25% 10% 8% 8% 401-1 SOC-15  
Diversity Hiring - Women 24% 29% 23% 29% 27% 401-1 SOC-15  
U.S. Hiring
Diversity hiring - U.S. POC 29% 28% 35% 41% 41% 401-1 SOC-15  
U.S. Hiring by race/ethnicity
White 69.7% 71.7% 63.1% 59.2% 59.1% 401-1 SOC-15  
Hispanic 14.8% 10.4% 21.9% 21.2% 21.8% 401-1 SOC-15  
Asian 7.8% 8.0% 5.3% 6.8% 7.5% 401-1 SOC-15  
Black/African American 3.9% 6.0% 5.0% 7.4% 6.5% 401-1 SOC-15  
American Indian or Alaska Native 0.8% 2.0% 0.8% 2.2% 2.5% 401-1 SOC-15  
Native Hawaiian or Pacific Islander 0.4% 0.4% 0.3% 0.5% 0.2% 401-1 SOC-15  
Two+ races 2.3% 1.6% 2.1% 2.4% 2.5% 401-1 SOC-15  
Undisclosed 0.2% 0.0% 1.6% 0.5% 0.0% 401-1 SOC-15  
External hire acceptance rate             SOC-15  
University hire acceptance (U.S.) 84% 85% 81% 70% 73% 401-1 SOC-15  
Interns acceptance (U.S.) 68% 74% 76% 68% 71% 401-1 SOC-15  
Conversions from Interns to Hires 73% 91% 82% 77% 82% 401-1 SOC-15  
Interns - U.S. Minorities 32% 36% 38% 40% 46% 401-1 SOC-15  
Attrition rate
Total Attrition Rate 11.2% 5.3% 14.5% 13.1% 4.9% 401-1 SOC-6  
Voluntary Attrition 4.1% 3.0% 5.0% 5.6% 3.9% 401-1 SOC-6  
Voluntary Attrition - Women 3.8% 2.8% 5.3% 5.0% 4.2% 401-1 SOC-6  
Voluntary Attrition - Men 4.1% 3.1% 4.9% 5.9% 3.9% 401-1 SOC-6  
Voluntary Attrition - U.S. POC 3.4% 2.9% 4.8% 5.7% 3.1% 401-1 SOC-6  
U.S. Voluntary Attrition by race/ethnicity
White 4.9% 3.7% 6.8% 6.7% 4.6% 401-1 SOC-6  
Hispanic 3.3% 2.2% 5.2% 4.7% 3.5% 401-1 SOC-6  
Asian 3.8% 4.1% 2.9% 6.7% 3.1% 401-1 SOC-6  
Black/African American 3.5% 4.2% 4.0% 6.9% 3.6% 401-1 SOC-6  
American Indian or Alaska Native 4.1% 1.4% 7.8% 6.5% 1.2% 401-1 SOC-6  
Native Hawaiian or Pacific Islander 0.0% 0.0% 6.7% 0.0% 6.6% 401-1 SOC-6  
Two+ races 0.0% 0.0% 7.3% 7.3% 1.9% 401-1 SOC-6  
Voluntary attrition less than 5 years of tenure 4.3% 2.5% 8.4% 7.6% 4.7% 401-1 SOC-6  
Training, Development and Promotions
Training of Petrotechnical employees (Hours of training/empl.) 28.5 27.1 21.5 23.1 28.5 404-2 SOC-7  
DEI Training courses completed by employees n/a 1,872 1,281 1,402 1,057 404-2 SOC-7  
Average spent on training per employee (in dollars) $1,277 $948 $889 $1,071 $1,043   SOC-7  
Promoted - Women 31% 32% 33% 34% 32%   SOC-7  
Promoted - U.S. POC 27% 24% 26% 30% 33%   SOC-7  
U.S. Promoted
White 72.8% 76.5% 74.2% 69.9% 67.0%   SOC-7  
Hispanic 12.4% 9.6% 10.7% 16.2% 18.6%   SOC-7  
Asian 7.6% 5.7% 5.6% 5.4% 5.7%   SOC-7  
Black/African American 4.3% 4.1% 5.2% 4.1% 4.1%   SOC-7  
American Indian or Alaska Native 2.0% 2.8% 2.1% 2.8% 2.1%   SOC-7  
Native Hawaiian or Pacific Islander 0.2% 0.4% 0.6% 0.1% 0.5%   SOC-7  
Two+ races 0.7% 0.9% 1.3% 1.5% 2.0%   SOC-7  
Undisclosed 0.0% 0.0% 0.2% 0.0% 0.0%   SOC-7  
Promoted to Top Leadership - Women 9% 22% 31% 34% 25%   SOC-7  
Promoted to Top Leadership - U.S. POC 24% 6% 21% 28% 16%   SOC-7  
GOVERNANCE
Board33
Independent Members 91% 92% 80% 86% 83%      
Women 36% 31% 27% 29% 17% 405-1-a-i    
EXPLORATION AND PRODUCTION
Average Daily Net Production34
Crude Oil (MBD) 705 568 829 898 936     EM-EP 000.A
NGL (MBD) 115 105 142 252 287     EM-EP 000.A
Bitumen (MBD) 60 55 69 66 81     EM-EP 000.A
Natural Gas (MMCFD) 2,805 2,394 3,162 3,130 3,135     EM-EP 000.A
Total (MBOED) 1,348 1,127 1,567 1,738 1,826     EM-EP 000.A
Total Operated Production (MMBOE) 35 561 471 694 688 688      
Total Proved Reserves at Year-End (million BOE) 5,262 4,459 6,101 6,599 6,758      
Proved Reserves in Low Transparency Countries 36 4.4% 5.1% 3.6% 3.8% 3.4%     EM-EP 510a.1

Notes:
  1. Due to rounding, some total numbers may not equal the sum of the subcomponents.
  2. Based on the equity share approach as defined in "The Greenhouse Gas Protocol: A Corporate Accounting and Reporting Standard (WRI)."
  3. Baseline net equity emissions intensity data was estimated from the Long-Range Planning process and may be found within the Emissions Reduction Targets and Performance section of the Sustainability Report on www.conocophillips.com.
  4. Updated in 2022, GHG metrics are reported to the nearest whole number in each unit, except intensity or other metrics expressed as ratios.
  5. The denominator uses net production values reported in the ConocoPhillips Annual Report, which represent the company’s equity share of total production.
  6. GHG intensity target excludes emissions from exploration and transportation services (i.e., Polar Tankers and Global Aviation), which are not directly related to oil or gas production. This may give rise to small differences between the intensity we report for our GHG target purposes and our total greenhouse gas intensity. The company set a medium-term target to reduce our gross operated and net equity operational GHG emissions intensity by 50% to 60% by 2030, from a 2016 baseline.
  7. Data is based on assets where we have operational control. Environmental data is represented as 100% ownership interest regardless of actual share owned by ConocoPhillips with acquisitions and divestitures aligned with financial reporting. To provide the most current and accurate data available, we have updated previously reported data for prior years as needed.
  8. 2023 methane emissions are higher due to updated equipment inventory, equipment classification and real-time tracking of flare downtime.
  9. Scope 1 and Scope 2 emissions divided by sales and other operating revenues. Source: ConocoPhillips Annual Report
  10. Includes CO2 from operations, Methane (CO2e), Nitrous Oxide (CO2e).
  11. Includes emissions related to unplanned events/incidents and emissions from Sulfur Hexafluoride.
  12. Routine flaring is defined as flaring that occurs during the normal production of oil in the absence of sufficient facilities to utilize the gas onsite, dispatch it to market, or reinject it. In 2020, we endorsed the World Bank Zero Routine Flaring by 2030 initiative. Per the World Bank’s Zero Routine Flaring by 2030 initiative text, “Oil companies that endorse the Initiative will develop new oil fields they operate according to plans that incorporate sustainable utilization or conservation of the field’s associated gas without routine flaring. Oil companies with routine flaring at existing oil fields they operate will seek to implement economically viable solutions to eliminate this legacy flaring as soon as possible, and no later than 2030.”
  13. Total flaring volume represents total hydrocarbon content flared. Safety flaring is included in the total flaring volume.
  14. Calculated as total fresh water withdrawn minus total fresh water discharged.
  15. Based on World Resources Institute Aqueduct Risk Atlas water stress mapping layer as of Dec. 31, 2023, verification of water stress using local water supply and demand data for select assets and calculated as the percentage of total fresh water withdrawn.
  16. Based on World Resources Institute Aqueduct Risk Atlas water stress mapping layer as of Dec. 31, 2023, verification of water stress using local water supply and demand for select assets and calculated as the percentage of total fresh water consumed.
  17. Includes water withdrawn from saline/brackish groundwater aquifers and seawater.
  18. Includes produced water recycled for production (e.g. steam generation) or completions (e.g. hydraulic fracturing) and produced water reused for enhanced oil recovery.
  19. Calculated using Enverus data for the average volume of fresh water (BBL) divided by the average estimated ultimate recovery (EUR, BOE) as of April 1, 2024. Intensity value may change as EUR data are updated.
  20. Calculated using the average volume of fresh water (BBL) divided by the average annual production (BOE).
  21. Operated lease area overlapping with IUCN I-VI protected areas based on World Database on Protected Areas accessed on Dec. 31, 2023.
  22. Cumulative acreage includes impact avoidance, grassland and wetland restoration, habitat conservation, biodiversity offsets and voluntary conservation areas.
  23. Operated assets with species observed or known to occur based on IUCN Red List of Threatened Species mapping tool accessed on Dec. 31, 2023.
  24. The term “environment” refers to the natural environment, including soil, surface water, groundwater and ice-affected surfaces.
  25. No spills in this section were deemed as to the environment, per local regulatory requirements.
  26. Regulatory definitions for hazardous and nonhazardous waste vary between countries and jurisdictions. Data is based on country and jurisdictional definitions.
  27. The variance in waste volumes is due primarily to increased well production and an improved methodology to determine waste quantities and the allocation of hazardous and recycled waste in the Canadian and Lower 48 Business Units.
  28. Rate of process safety events of greater consequence as defined by API 752 and IOGP 456 Standards.
  29. Payments to vendors and suppliers is an estimate based on Production and Operating Expenses and Capital Program.
  30. Employee headcount based on active employees as of Dec. 31, 2023.
  31. U.S. workforce demographics account only for self-reported data.
  32. POC: People of Color (includes ethnic/racial groups defined per the U.S. Census).
  33. As of Dec. 31, 2023.
  34. Production data is average daily net production from continuing operations.
  35. Data is normalized using barrels of oil equivalent (BOE) from production operations, including gas plant liquid production of ethane, propane, butane and condensate and production from third-party gas not accounted for in production operations. For gas production, 6,000 standard cubic feet of gas is assumed to equal one BOE.
  36. In the 20 lowest-ranked countries per Transparency International's Corruption Perception Index.
REFERENCE: UNITS OF MEASURE

MBD - Thousands of Barrels per Day
MBOED - Thousands of Barrels of Oil Equivalent per Day
MMCFD - Millions of cubic feet per day. Represents quantities available for sale and excludes gas equivalent of natural gas liquids.
MMBTU - Millions of British Thermal Units