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Summary of Data

PDF Version 

Energy (a)

Type Unit 2007 2012 2013 2014 2015 2016 2017 2018 2019
Total Combustion On-site (Direct) (d) 1,000 GJ 2,151 1,790 1,828 1,744 1,828 1,660 2,090 1,766 1,543
Natural Gas 1,000 GJ 1,848 1,390 1,400 1,322 1,371 1,207 1,100 1,017 1,009
Diesel 1,000 GJ 303 390 416 411 448 443 988 748 533
Propane 1,000 GJ - 10 11 11 10 9.3 2.6 1.2 1.2
Total Purchased Energy (Indirect) (e) 1,000 GJ 2,190 2,059 1,990 1,962 1,983 1,876 1,619 1,518 1,551
Fossil Fuel 1,000 GJ 1,541 1,545 1,435 1,418 1,419 1,314 1,039 937 894
Hydro 1,000 GJ 287 191 210 200 217 123 131 129 133
Nuclear 1,000 GJ 240 195 185 185 178 148 141 132 96
Nonspecified Renewables 1,000 GJ 106 114 152 144 156 277 299 301 347
Nonspecified 1,000 GJ 16 13 8.3 14 13 13 8.3 19 81
Total Energy 1,000 GJ 4,341 3,849 3,817 3,706 3,812 3,535 3,709 3,284 3,094
Total Energy Normalized to Net Sales 1,000 GJ/$B net sales 303 231 210 192 182 161 170 146 139
Confirmed Results of Energy Reduction Projects (b,c) 1,000 GJ - 919 106 131 175 244 397 524 598

Carbon (a)

Type Unit 2007 2012 2013 2014 2015 2016 2017 2018 2019
Total Carbon Combustion On-site (Scope 1) (f) 1,000 MT CO2Eq 126 98 101 96 103 94 125 104 89
Natural Gas 1,000 MT CO2Eq 104 70 71 67 71 62 56 51 51
Diesel 1,000 MT CO2Eq 22 27 29 29 32 31 68 52 37
Propane 1,000 MT CO2Eq - 1 0.7 0.7 1.0 0.6 0.2 0.1 0.1
Total Carbon Purchased Energy (Scope 2) (g) 1,000 MT CO2Eq 290 287 263 258 266 198 154 160 160
Electricity 1,000 MT CO2Eq 284 283 259 254 263 195 150 156 160
Steam 1,000 MT CO2Eq 6 4 3.8 3.9 3.0 3.0 3.5 4.2 0.6
Total Carbon from Energy 1,000 MT CO2Eq 416 385 363 354 369 291 278 263 249
Total Carbon Normalized to Net Sales 1,000 MT CO2Eq/$B net sales 29.1 23.1 20 18 18 13 13 12 11
Total Carbon Normalized to Total Energy MTCO2Eq/GJ 0.095 0.100 0.095 0.10 0.097 0.082 0.075 0.085 0.080
Confirmed Results of Carbon Reduction Projects (b,c) 1,000 MT CO2Eq - 84 8 10 13.5 20.2 34 42 48

Other Carbon (h, i , j)

Type Unit 2007 2012 2013 2014 2015 2016 2017 2018 2019
Carbon Sales Fleet (Scope 1) 1,000 MT CO2Eq 13 15 16 13 13 16 32 44 40
Carbon Sales Fleet Emissions Avoided (Scope 1) 1,000 MT CO2Eq - 4 1 2 2.3 2 3 3 4
Carbon Executive Air Fleet (Scope 1) 1,000 MT CO2Eq 5 6 5 5 6 6 5 4 4
Carbon From Fugitive Emissions (Scope 1) 1,000 MT CO2Eq - - 4 5 4 2 2 9 3
Carbon from Purchased Goods and Services (Scope 3: Category 1) - - - - - - - - 2,414 2,324
Carbon from Capital Goods (Scope 3: Category 2) - - - - - - - - 263 258
Carbon from Fuel- and Energy-related activities (Scope 3: Category 3) - - - - - - - - 29 53
Carbon from Upstream transportation & distribution (Scope 3: Category 4) 1,000 MT CO2Eq - 25 27 25 29 24 40 33 23
Carbon from Waste generated in operations (Scope 3: Category 5) 1,000 MT CO2Eq - - - - - - 1.6 1.4 3.5
Carbon from Business Travel (Scope 3: Category 6) 1,000 MT CO2Eq - 65 67 65 74 78 85 59  56
Carbon from Employee Commuting (Scope 3: Category 7) 1,000 MT CO2Eq - - - - - - 60 56 56

Water (a)

Type Unit 2007 2012 2013 2014 2015 2016 2017 2018 2019
Total Water Withdrawal (k,c) 1,000 CM 3,286 2,720 2,725 2,487 2,520 2,351 2,320 2,093 2146
Municipal 1,000 CM 3,249 2,707 2,712 2,482 2,453 2,341 2,293 2,080 2129
Other - (Reservoir) Trucked In 1,000 CM 8 0 0 0 0 0 0 0 0
Ground 1,000 CM 29 13 13 5 68 10 27 13 17
Total Water Withdrawal Normalized to Net Sales 1,000 CM/$B net sales 230 163 150 129 120 107 106 93 97
Water Fate (k) 1,000 CM - 2,720 2,739 2,487 2,512 2,335 2,319 2,093 2,146
Consumed Into Products 1,000 CM - 21 21 28 71 28 28 31 31
Lost to Evaporation 1,000 CM - 713 684 657 736 603 610 562 546
Discharged to Treatment 1,000 CM - 1,662 1,758 1,551 1,449 1,495 1,490 1,328 1,379
Discharged Directly to Environment 1,000 CM - 324 276 250 256 210 191 172 191
Recycled 1,000 CM - 535 655 525 759 642 608 572 548
Percentage of Water Recycled per Total Water Withdrawal % - 20 24 21 30 28 26 27 26
Confirmed Results of Water Reduction Projects (b) 1,000 CM - 686 19 36 142 203 266 278 284

Waste (a,c)

Type Unit 2007 2012 2013 2014 2015 2016 2017 2018 2019
Recycling Rate (l) % 34.9 52.8 51.3 50.4 52.1 54 49 49 48
Total Routine Waste MT 10,146 9,018 8,780 8,929 10,054 10,330 9,856 9,642 9,818
Hazardous Waste MT 1,343 1,180 1,157 1,113 1,455 1,815 2,179 1,984 2,179
Recycled MT 251 245 105 84 190 286 281 281 230
Incinerated for Energy Recovery MT 375 347 402 387 447 683 901 795 988
Incinerated Not for Energy Recovery MT 523 422 468 473 683 726 860 738 855
Landfilled MT 118 126 147 132 102 94 115 89 78
Treated (m) MT 76 40 36 38 33 27 22 81 28
Nonhazardous Waste MT 8,803 7,838 7,623 7,816 8,599 8,515 7,677 7,658 7,640
Composted MT 260 583 532 628 947 814 761 728 745
Reused MT 32 44 274 178 153 159 129 176 249
Recycled MT 2,999 3,890 3,583 3,610 3,945 4,258 3,620 3,441 3,522
Incinerated for Energy Recovery MT 432 576 604 605 700 762 601 603 594
Incinerated Not for Energy Recovery MT 194 79 48 88 259 188 162 202 183
Landfilled MT 4,885 2,662 2,530 2,661 2,543 2,273 2,367 2,462 2,302
Treated (m) MT - 4 52 47 52 61 38 46 45
Total Routine Waste Normalized to Net Sales MT/$B net sales 709 542 483 462 480 472 452 428 442
Total Nonroutine Waste (n) MT 31,415 16,902 8,452 3,722 2,253 4,529 4,852 7,509 3,128
Confirmed Results of Routine Waste Reduction Projects (b) MT - 1,094 320 441 688 850 1,038 1,297 1,426

Fleet

Type Unit 2007 2012 2013 2014 2015 2016 2017 2018 2019
Sales Fleet Fuel Efficiency (o) MPG-US 19 23 25 26 27 26 28 29 29
Sales Fleet Fuel Use Avoided 1,000 GL - 427 104 289 498 704 1,031 1,472 1,869
Sales Fleet Fuel Use 1,000 GL 1,498 1,739 1,738 1,381 1,414 1,750 3,415 4,695 4,227

Compliance (a)

Type Unit 2007 2012 2013 2014 2015 2016 2017 2018 2019
Environmental Notices of Violation (NOVs) (p) 1 NOV 8 2 2 6 0 1 1 3 2

General

(a)
Amgen data includes specific measurements for energy, water and waste obtained from our operations, representing 88 percent of Amgen's worldwide facility space based on total square feet. Included facilities are in Thousand Oaks, California, U.S.; West Greenwich, Rhode Island, U.S.; Louisville, Kentucky, U.S.; South San Francisco, California, U.S.; Cambridge and Woburn, Massachusetts, U.S.; Juncos, Puerto Rico; Burnaby, Canada; Breda, Netherlands; Dun Laoghaire, Ireland; Uxbridge and Cambridge, United Kingdom; São Paulo, Brazil; Yenibosna and Sekerpinar, Turkey; and Tuas, Singapore. Energy and carbon data for the remaining 12 percent of facility space is estimated based on building energy intensity factors and country specific emission factors. This includes leased buildings where we have operational control over building infrastructure, including utilities.

(b)
Measurement and verification of conservation and reduction projects for energy and carbon, water and waste are based on adaptation of the International Performance Measurement and Verification Protocol (IPMVP). Project measurements are conducted using reasonable means, including direct measurements and scientific estimations as appropriate. Values for conservation and reduction projects represent year-over-year, cumulative and continuing avoidance based on a 2007 baseline, then re-baselined in 2012 to match the next-generation 2020 Target design.

(c)
Immaterial changes to 2007–2018 data may have occurred due to refinements in calculations. All changes have been confirmed through a documented change control process.

Energy

(d)
Direct onsite energy use results from the operation of equipment that is owned or controlled by Amgen. For facilities identified in note (a), data on the use of natural gas, propane and diesel in boilers, furnaces and HVAC is recorded from utility bills or purchase records. Data on the use of diesel in emergency generators is recorded from purchase records or meter readings and, in some cases, estimated from run-hours. Utility bills recorded in units of volume are converted to energy. Energy from emergency generators recorded as run-hours is estimated using the manufacturer's specified fuel-feed rate for each generator. For Amgen facilities where measurements are not obtained or available, usage is estimated from energy intensity factors based on building square footage.

(e)
Indirect onsite energy use results from purchased energy in the forms of electricity and steam. For facilities identified in note (a), data on the use of electricity and steam are recorded from utility bills. For Amgen facilities where measurements are not obtained or available, usage is estimated from energy intensity factors based on building square footage.

Carbon

(f)
Scope 1 carbon emissions result from direct energy sources defined in note (d). Additional Scope 1 Carbon emissions from sales fleet; executive air fleet; fugitive emissions from chillers, coolers and HVAC; carbon dioxide used for neutralization; and carbon dioxide resulting from cell respiration in manufacturing processes and biological wastewater treatment are found in the Other Carbon category in this data summary. Carbon emissions from natural gas sources are calculated using the U.S. EPA's Center for Corporate Climate Leadership Emission Factors for Greenhouse Gas Inventories (9 March 2018) for all U.S. sites and locations not specifically listed below; the 2018 B.C. Best Practices Methodology for Quantifying Greenhouse Gas Emissions for Amgen's facility in Burnaby, Canada; the Ireland Country Specific Net Calorific Values and CO2 Emissions Factors for use in the Annual Installation Emissions Report- 2019 for Amgen’s facility in Dun Laoghaire, Ireland; The Netherlands: list of fuels and standard CO2 emission factors version of January 2019 for Amgen’s facility in Breda, Netherlands; and the U.K. Defra's Greenhouse gas reporting: conversion factors 2019 for Amgen’s facilities in Uxbridge and Cambridge, United Kingdom. Carbon emissions data from propane and diesel fuel sources are calculated using U.S. EPA's Center for Corporate Climate Leadership Emission Factors for Greenhouse Gas Inventories (9 March 2018). Carbon data from direct energy sources prior to 2011 were calculated using emission factors from the Greenhouse Gas Protocol Cross-Sector Tools-Stationary Combustion-V.1.0 (July 2009).

(g)
Scope 2 carbon market-based emissions result from indirect energy sources defined in note (e). Carbon emissions from purchased electricity are calculated using emission factors from U.S. EPA eGRID Summary Tables 2018 for Amgen’s facilities in Thousand Oaks, California and Louisville, Kentucky. Amgen’s facility in San Francisco, California; Woburn and Cambridge, Massachusetts; West Greenwich, Rhode Island; Dun Laoghaire, Ireland; and Cambridge and Uxbridge United Kingdom carbon emissions are calculated using supplier specific emission factors. Amgen's facility in Puerto Rico are calculated using The Climate Registry Emission Factors for "U.S. territories (not an eGRID Region)" (May 1, 2018). Carbon emissions from purchased electricity for Amgen's facility in British Columbia, Canada are calculated using regional emission factors. Carbon emissions from purchased electricity for Amgen's Netherlands facility are covered by a renewable energy certificate. Carbon emissions from purchased electricity for Amgen's facility in Singapore are calculated using emission factors from the International Energy Agency's CO2 emissions from fuel combustion 2019 and a renewable energy certificate covering electricity purchased during the fourth quarter 2019. Carbon emissions from Amgen’s remaining locations (including Brazil and Turkey) are calculated using emission factors from the International Energy Agency's CO2 emissions from fuel combustion 2019. Carbon data from purchased steam is calculated using an emission factor provided by the supplier for Amgen's facility in Cambridge, Massachusetts. Carbon data from indirect energy sources prior to 2011 were calculated using emission factors from U.S. EPA eGRID2007 Version 1.1 for U.S. facilities.

Other Carbon

(h)
The Other Carbon category contains additional Scope 1 and Scope 3 carbon emissions. Carbon emissions from our executive air fleet and sales fleet are calculated using emission factors from the U.S. EPA's Center for Corporate Climate Leadership Emission Factors for Greenhouse Gas Inventories (9 March 2018). U.S. sales fleet fuel usage and mileage data are collected at the pump for Amgen leased vehicles. Beginning in 2017, sales fleet incorporated international fleets, and in 2018 estimates were included for additional international locations and field workers operating long-term rental vehicles. Fugitive emissions from process equipment (e.g., refrigerant from refrigeration and HVAC equipment) are calculated using emission factors from the Intergovernmental Panel on Climate Change. Processes are in place to maintain chillers, coolers and HVAC equipment to prevent unintended emissions. Beginning in 2019 fugitive emissions include carbon emissions from purchased carbon dioxide and from on-site cell respiration in manufacturing and wastewater treatment operations. Scope 3 carbon emissions are a consequence of the activities of the company but occur from sources not owned or controlled by the company. Scope 3 carbon emissions that are currently tracked include emissions from Amgen's purchased goods and services, capital goods, fuel-related activities, upstream material transportation, waste generated in operations, commercial business travel (air and rail), and staff commuting.

(i)
Carbon emissions for Scope 3 Purchased Goods and Services and from Scope 3 Capital Goods are calculated using spend data and the Greenhouse Gas Protocols Scope 3 Evaluator tool. Carbon emissions from Scope 3 Fuel- and Energy-related Activities are calculated using the U.K. Defra's Greenhouse gas reporting: conversion factors 2019. Carbon emissions from Scope 3 Upstream Transportation and Distribution have been provided by Amgen’s transportation carriers using their own specific methods or calculated using carrier data and emission factors from the U.S. EPA's Center for Corporate Climate Leadership Emission Factors for Greenhouse Gas Inventories (9 March 2018). Carbon emissions from Scope 3 Waste Generated in Operations is calculated using the U.K. Defra's Greenhouse gas reporting: conversion factors 2019. Carbon emissions from Scope 3 Business Travel are calculated by Amgen's travel provider. Carbon emissions Scope 3 Employee Commuting are calculated using the Global Fuel Economy Initiative’s International Comparison of Light-Duty Vehicle Fuel Economy 2005-2015.

(j)
Carbon emissions from commercial business travel was not tracked in 2007 or 2008. Carbon emissions from material transportation was not tracked from 2007 to 2011. The accuracy of carbon emissions tracking from fugitive refrigerant emissions improved in 2013 and will now be reported going forward. Carbon emissions from staff commuting and waste disposal was not tracked prior to 2017. Carbon emissions from purchased goods and services, capital goods, and fuel-related activities were not tracked prior to 2018.

Water

(k)
Immaterial discrepancy between values for total water fate and total water withdrawal is due to rounding and compilation of individual facility totals.

Waste

(l)
The recycle rate is the total routine recycled, composted and reused weight divided by the total weight of routine waste.

(m)
Treatment means the physical, thermal, chemical or biological processes that change the characteristics of the waste in order to reduce its volume or hazardous nature, facilitate its handling or enhance recovery.

(n)
Nonroutine waste constitutes waste generated outside the normal operations of our facilities and consists mainly of construction and demolition waste.

Fleet

(o)
Emissions and fuel use avoided are the result of improvements in fleet efficiency from years 2007 through 2012 based on a 2007 baseline and years 2013+ based on a 2012 baseline.

Compliance

(p)
Environmental notices of violation (NOVs) reported that resulted from agency inspections.

Apex Companies, LLC (Apex) has been engaged by Amgen to provide limited assurance of selected environmental and safety data. This Assurance Statement applies to the Subject Matter included within the scope of work. Please see our Independent Verification Statement for additional information.

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