C A L I F O R N I A E N E R G Y C O M M I 

Status of Biofuel Production Facilities 

September 2009

Energy Commission Staff Updat

2010-11 Investment Plant

Jim McKinney

Emerging Fuels and Technologies O

California Energy Commission

AB 118 INVESTMENT PLAN BIOFUELS 

Sacramento, California

September 14 and 15, 2009
C A L I F O R N I A E N E R G Y C O M M I 

Existing California Ethanol Plant Status 

Plant/Company 

Name

Location Capacity

MMGPY

1st

production

year

Status 

Parallel Products Rancho

Cucamonga 5 1984 Only plant cur

operating 

Altra 31.5 2005 Production ceased 1

Idle 

CalgrenRenewable Fuels

Pixley 52.5 2008 Prod. ceased 1/09, p

modifications unde

Cilion Keyes 55 2008 Production ceased 3

Idle

Pacific Ethanol Stockton 60 2008 Production ceased 3

Idle

Pacific Ethanol Madera 40 2006 Production ceased 

Idle

Golden Cheese Company 

Corona 3.5 1985 Production ceased 

Closed permanen

Installed Capacity 247.5

Capacity operating 5 98 % of Calif

Ethanol Production C

Capacity Idle 242.7
C A L I F O R N I A E N E R G Y C O M M I 

California Ethanol Produc

• Dry mill ethanol plants in California are “Destination 

meaning that the ethanol is made at the destination mafeedstocks.

• All plants produce distillers wet grains as animal feed 

within 50 miles of the plant (when operating)

• Economics – at a disadvantage to Midwest plants that 

benefits from not drying grains and reduced transporta

• All can be candidates for “front-end” retrofit to proces

cellulose and purpose grown California crops. 

• Some plants are planning or undertaking value added 

extraction of corn oil for biodiesel

• Improvements are necessary to remain competitive wi

improving plants in the Midwest and other states
C A L I F O R N I A E N E R G Y C O M M I 

California Ethanol Demand RelatState Production Capacity (Approx

Annual 

Demand

MM 

Gal/Yr

2004 9002005 9502006 9452007 9302008 960

•Existing In-State Production Capacity •If all existing capacity was operationaethanol demand would be achieved•With the shift to 10 % ethanol blendingasoline on January 1, 2010, and ethanone billion gallons per year, existing p20 % production and use Bioenergy Aonly if all plants are fully operational•With additional growth in the E-85 mwill be hard to achieve in the near term•Bottom Line – New in-state productioneeded to assure adequate ethanol suppethanol demand increases
C A L I F O R N I A E N E R G Y C O M M I 

California Biodiesel Pla

(February 2009 EFTO Staff S

Existing Plants - Production and 

Capacity Summary

Million ga

(2009 / 2010 

2006 2007 2008 

Average Capacity 1.67 2.00 4.96 

Average Production 0.79 0.99 3.57 

Production % of Capacity 48% 50% 72% 
C A L I F O R N I A E N E R G Y C O M M I 

California Biodiesel Pla

February 2009

• 12 operating plants with annual capacities ran

30 million gallons per year

• About 105 million gallons of capacity in 2009 • Largest is located in Bakersfield, and smalles• Five plants intend to add capacity in 2009/20

facility doubling its capacity.

• Two new plants in Los Angeles and Chilcoot 

in 2009 – 10 million gal/yr combined capacity

• Focus of industry effort is improved capacity 

stood at about 50 percent in 2006/2007 and is over 90 percent in 2010.
C A L I F O R N I A E N E R G Y C O M M I 

California Nation-State 

• Population: 36.8 million• GDP: $1.8 trillion - 8th largest econom

• GHG Emissions: 440 MMT (2004)

– 7.2% of U.S. Emissions (Pew Center)– 10th largest emitter on global scale

– Transportation accounts for 38 % of all GH

• Vehicles: 26.3 million cars + 0.92 mill• Annual Fuel Consumption: 20 billion g

– 16 billion gallons gasoline (~1 billion gallo– 4 billion gallons diesel– 3rd largest consumer of vehicle fuels after 
C A L I F O R N I A E N E R G Y C O M M I 

State and Federal Policy Drivers 

GHGs Will Increase Demand fo

• California’s Climate Change Reduction Go

– 1990 Levels by 2020 (~30% reduction)– 80 percent reduction by 2050

• California’s Low Carbon Fuel Standard

– 10 % reduction in carbon intensity of transportation 

• BioEnergy Action Plan (Executive Order S-

–

“Maximize the contributions of bioenergy toward achiev

reduction, climate change, renewable energy, and enviro

– Policy goal to increase in-state production 

2010 – 20% 2020 – 40% 2050 – 7
C A L I F O R N I A E N E R G Y C O M M I 

• Federal Renewable Fuels Standar

– 2007 Energy Independence and Securit
C A L I F O R N I A E N E R G Y C O M M I 

AB 118 Investment Plan Projections for GHG 

2050 Vision

Fuel Mix

40% electricity

/ hydrogen

30% biofuels30% petroleum

Key

Low Carbon = 40% ReductionUltra Low Carbon = 60%Super UltraLow Carbon = 82% Reduction
C A L I F O R N I A E N E R G Y C O M M I 

AB 118 Investment Plan F

Allocations – First Two 

Fuel / Technology 

A

Electric Drive Hydrogen Ethanol (waste stream feedstocks) Renewable Diesel / Biodiesel (waste stream) Natural Gas (Includes $10 M biomethane) Propane Non-GHG Support 

Includes $4 million for sustainability research

Total Sub-total Biofuels (ethanol, biodiesel, biomethane)