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Fuel Switching For A Small Boiler Operator Using 6 Fuel Oil On An Interruptible Natural Gas Supply

Scope Of Main Energy Operations. 2 Train Cogeneration With Supplemental Fired Heat Recovery Steam Generators. Natural Gas Fired,

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Fuel Switching For A Small Boiler Operator Using 6 Fuel Oil On An Interruptible Natural Gas Supply

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    1. Fuel Switching For A Small Boiler Operator Using #6 Fuel Oil On An Interruptible Natural Gas Supply James H. Connolly, P.E. Hoffmann-La Roche Inc.

    2. Scope Of Main Energy Operations 2 Train Cogeneration With Supplemental Fired Heat Recovery Steam Generators. Natural Gas Fired, #2 Fuel Oil Backup. Peak Boiler Capacity Approximately 112 MMBTU/hr Including Waste Heat From Turbines. 4 Boilers, 90 to 186 MMBTU/hr Each.

    3. Energy Center Operation Summertime: Cogeneration With One Boiler In Low Fire “Swing” Mode. Wintertime: 4 Boilers Carried Site Through Winter 2003 – 2004 Without Cogeneration During Cogeneration Repowering. Largest Boiler Essentially Used Exclusively During Winter Months.

    4. 5 Year Boiler Energy Profile Based On Gross BTUs Average 77% Natural Gas, 23% Oil Peak Oil Use 50% Natural Gas, 50% Oil Low Oil Use 99.5% Natural Gas, 0.5% Oil Using Current Energy Demand, Operational Ability Is 100% On Either Fuel For Boiler Operations (Not The Case When Permitted In 1990s).

    5. #6 Fuel Oil Use Vs. Allowable Permit Limit For The Entire Boilerhouse 4,233,000 Gallons Per Year (Smallest Boiler Can Burn >600 GPH). Peak Oil Use 2000 – 2004 1,126,300 Gallons. Oil Use Occurs Chiefly When Temperatures Drop Below 20 Degrees F.

    6. Emission Reduction Basis SO2 – NJAC 7:27-9.2 Table 1, Zone 4. NOx – NJAC 7:27 19.7 Table 4 and Table 5. CO/VOC – Assume Unchanged NJAC 7:27-16.8. PM/PM10/PM2.5 – Original Basis: Assume Unchanged Due To Insufficient Data. Refined Basis: Worse AP-42 Ratios

    7. Original Emission Reduction Estimate Based On Peak Allowable Fuel Use: SO2 31.7 TPY NOx 32.0 TPY (Estimates not adjusted for 8.9% higher gross heat value of #6 fuel oil, used permit/historical fuel volumes)

    8. Refined Emission Reduction Estimate Based On Peak Allowable Fuel Use: SO2 28.9 TPY NOx 32.0 TPY PM 7.9 TPY (Estimates adjusted for 8.9% higher gross heat value of #6 fuel oil, used permit/historical fuel volumes)

    9. Original Emission Reduction Estimate Based On Peak Actual Fuel Use During Last 5 Reporting Years: SO2 8.4 TPY NOx 4.3 TPY (Estimates not adjusted for 8.9% higher gross heat value of #6 fuel oil, used permit/historical fuel volumes)

    10. Refined Emission Reduction Estimate Based On Peak Actual Fuel Use During Last 5 Reporting Years: SO2 7.7 TPY NOx 4.3 TPY PM 2.1 TPY (Estimates adjusted for 8.9% higher gross heat value of #6 fuel oil, used permit/historical fuel volumes)

    11. Burner/Fuel Infrastructure Retrofit Cost Estimate Submitted To NJDEP Based On Peak Allowable Fuel Use: $35,000/TPY (Corrected) Emission Reduction. Based On Peak Actual Fuel Use For Last 5 Years: $173,000/TPY Emission Reduction.

    12. Burner/Fuel Infrastructure Retrofit Cost (Emission) Estimate Refined Based On Peak Allowable Fuel Use: $33,000/TPY Emission Reduction. Based On Peak Actual Fuel Use For Last 5 Years: $156,000/TPY Emission Reduction.

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