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Non-Utility Floor Allocation for Sulfur Dioxide. May 21, 2002 Presentation to the WRAP Market Trading Forum. Source Specific Allocations. Source Specific Allocations have two components Floor Allocation Reducible Allocation. Floor Allocation. - PowerPoint PPT Presentation
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Non-Utility Floor Allocation for Sulfur Dioxide
May 21, 2002 Presentation to the WRAP Market Trading Forum
Source Specific Allocations
• Source Specific Allocations have two components– Floor Allocation– Reducible Allocation
Floor Allocation
• The Floor allocation is defined as that portion of the facility's allocation that will not be reduced, it is the minimum allocation that the source would need to operate if it was controlled at a defined level. That defined level is either BACT, BART, LAER or is some cases NSPS. The floor allocation will be determined by the state on a source by source basis, based upon the methodology developed by the MTF for the non-utility sources. Those allocations will be allocated to the source prior to the allocation of the reducible portion.
Reducible Allocation
• This is the portion of the sources allocation over and above the floor allocation. It is that portion of the sources allocation that will be reduced over time in order to meet the milestones. The reducible portion will first be aggregated across the region and then distributed across both utility and non-utility sectors to meet the milestones.
Distribution Order of Allocations
• 20,000 ton for the tribes
• 9,000 ton for new sources
• California RECLAIM
• Floor Allocations
• Renewable energy allocations
• Early reduction bonus allocations
• Reducible allocation for existing sources
Non-Utility Source Categories• Smelters• Refineries• Natural Gas Processing Plants• Oil & Gas Production Plants• Lime Plants• Cement Plants• Utility Boilers (cogens, CHP)• Industrial Boilers• Pulp and Paper
Analysis Steps:
1. Assume CA sources at the floor.
2. Copper smelter allocations already determined.
3. Focus on non-CA, non-smelter sources >100 tpy.
4. Define floor by source category.
5. Gather data.
6. Estimate floor amounts by source category/plant.
SO2 Emissions of Interest - Annual Tons in 2000
State CHPs Non-Utility Point
Arizona 0 4,196
California 883 37,329
Colorado 2,583 6,856
Idaho 117 27,646
Nevada 0 743
New Mexico 0 36,934
Oregon 0 8,988
Utah 3,588 6,798
Wyoming 0 40,147
Totals 7,171 169,637
Non-California Totals 6,288 132,308
Issues:
Sulfur can be in the fuel, or the feedstock material.
Old information on factors/controls in AP-42.
Some simple relationships:
Boilers
Some complex relationships:
Lime
Cement
Floor Calculation Methodology
Smelters• Smelter-by-smelter analysis.
• Hidalgo smelter is the only BART-eligible source.
• Double-contact acid plant.
• Fugitive SO2 capture system at Hidalgo satisfies BART.
Copper Smelters
State Facility
1990 Annual
Tons SO2
2018 Allocation
Annual Tons SO2
Arizona ASARCO-Hayden 29,814 21,000
BHP-San Manuel 15,900 14,000
Cyprus Miami Mine 5,676 8,000
New Mexico Phelps Dodge-Chino Mines 28,058 14,200
Phelps Dodge-Hidalgo 41,433 20,000
Utah Kennecott Utah Copper 26,829 1,000
Total Copper Smelters 148,510 78,000
RefineriesThere are four sources of SO2 emissions at the refinery level. Floor based upon NSPS where applicable.
Description
Assumed Average Control Level
SRU 99.8% control or the equivalent of 3-stage Claus units with a tail gas unit (NSPS and the tail gas unit does not apply to Claus units smaller than 20 long tons/day or less)
Fuel gas combustion units
Fix at the NSPS emission limit rate of 0.026 lbs/mBtu assuming fuel gas input and not fuel oil.
Catalytic crackers
NSPS (J) selected: 9.8 lbs of SO2 per 1,000 lbs of coke burned.
Flares
Based upon average of the last 5 years' emission, AP-42 factors for calculated. No additional controls.
Floor Calculation Methodology
Petroleum Refining
10 refineries, 4 States.
Floor built up from applying emission limits/factors at 4 primary SO2 sources.
Natural Gas Processing Plant
Description Assumed Average Level of Control
Process Emissions
96.8% control 3-stage Claus unit to treat the acid gas off the amine unit.
Flaring
Based upon average of the last 5 years' emission.
Floor Calculation Methodology
Oil and Gas Production units
Description
Assumed Average Level of Control
Flaring
Based upon average of the last 5 years' emission.
Floor Calculation Methodology
Cement Plant• Two SO2 sources: feed material sulfur and kiln
fuels (coal, gas, tires, wood, petroleum coke).• Calculating the floor fuel source = coal control via
five-stage calciner assuming 85% control.
Floor Calculation Methodology
Cement
Wide variety of emission rates.
Difficult to estimate control technology effect on complex sources.
Lime Plants• No additional reduction.
• Approximately 50% control inherent in the process.
• Additional SO2 controls are not typically applied.
Floor Calculation Methodology
What do we know now?
Floor is close to recent historical emissions.
Source Categories/Sectors SO2 Year 2000 Annual Tons
Petroleum Refining 16,944
Lime Manufacturing 2,316
Cement Manufacturing 7,495
Natural Gas Processing 50,323
Elemental Phosphorus Production 15,861
Glass Manufacture 363
Pulp and Paper 9,628
CHPs 6,288
Compressor Stations 2,927
Industrial/Commercial Boilers 20-25,000
*Non-California, non-smelter.