2001 Triple Bottom Line Report - BC Hydro

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28. LOCAL AIR QUALITY INDICATORS EMISSIONS OF SULFUR DIOXIDE 1997 1998 1998 2000 Total Gross Annual SO 2 Emissions (tonnes) 40 75 50 61 Mass Gross SO 2 Emitted Per Unit of Net Fossil Generation (g/kW . h) 0.028 0.028 0.028 0.02 Mass Gross SO 2 Emitted Per Unit of Net System Generation (g/kW . h) 0.0008 0.0015 0.0009 0.001 EMISSIONS OF SULFUR DIOXIDE FROM CANADIAN UTILITIES 1997 1998 1999 2000 Total Gross Annual SO 2 Emissions (tonnes) 501 841.00 628 128.00 598 133.00 621 791.00 Mass Gross SO 2 Emitted Per Unit of Net Fossil Generation (g/kW . h) 5.22 5.14 5.06 4.86 Mass Gross SO 2 Emitted Per Unit of Net System Generation (g/kW . h) 1.05 1.3 1.21 1.21 BC Hydro emits small quantities of SO 2 compared to the Canadian average because our primary fossil fuel source for thermal generation is natural gas, which is low in SO 2 emissions. EMISSIONS OF NO X 1997 1998 1999 2000 Total Gross Annual NO x Emissions (tonnes) 638 1213 801 1048 Mass Gross NO x Emitted Per Unit of Net Fossil Generation (g/kW . h) 0.45 0.45 0.45 0.34 Mass Gross NO x Emitted Per Unit of Net System Generation (g/kW . h) 0.013 0.024 0.016 0.02 EMISSIONS OF NO X FROM CANADIAN UTILITIES 1997 1998 1999 2000 Total Gross Annual NO x Emissions (tonnes) 203 047.00 246 935.00 234 324.00 232 273.00 Mass Gross NO x Emitted Per Unit of Net Fossil Generation (g/kW . h) 2.11 2.02 1.98 1.82 Mass Gross NO x Emitted Per Unit of Net System Generation (g/kW . h) 0.42 0.51 0.48 0.45 Since 1993 we have voluntarily upgraded and modernized the equipment at Burrard Generating Station, our natural gas-fired facility near Vancouver and BC Hydro's principal source of thermal power. In May 2000 we completed installation of selective catalytic reduction (SCR) technology installation on all six power generating units. This marked the first time in Canada that SCR technology was installed on utility boilers. The project achieved a 90 per cent reduction in emissions of nitrogen oxide (NO x ) from the plant. T R I P L E B O T T O M L I N E A P P E N D I C E S | 8 7
P E R F O R M A N C E M E A S U R E S E C O N O M I C I N D I C A T O R S 29. SHAREHOLDER VALUE- ADDED ( SVA) FISCAL YEAR MILLIONS OF DOLLARS 2000/2001 Actual 103 2000/2001 Target (55) 1999/2000 Actual 129 SVA is net income before finance charges and the transfer to the Rate Stabilization Account, minus Capital Charge (invested capital multiplied by cost of capital) and measures how well BC Hydro performed beyond the return expected for a company with a similar level of risk. It is calculated as: Net Operating Profit less Capital Charge. Net Operating Profit is net income before finance charges and the transfer to the Rate Stabilization Account. Capital Charge is Invested Capital x Cost of Capital. In fiscal 2001, the SVA result of $103 million was well above target. SVA before the Customer Profit Sharing was $412 million, $467 million higher than target and $283 million higher than the prior year. The substantial increase in SVA from Target and Prior Year is primarily attributed to the increase in electricity trade margins. Optimizing the use of storage and generation facilities to maximize profitable import and export of energy allowed BC Hydro to take advantage of significant opportunities created by a strong electricity trade market and high electricity trade sales prices. High prices were mainly due to several factors relating to the Californian market and its restructuring problems. 30. PROPORTION OF REVENUE FROM CUSTOMER GROUPS YEAR PER CENT 1997 1998 1999 2000 2001 Residential 35.70 32.85 28.10 25.69 11.31 Light Industrial & Commercial 33.35 32.42 27.54 24.40 10.98 Large Industrial 19.41 16.60 16.04 13.85 6.64 Other & Miscellaneous 4.78 4.78 4.04 3.62 1.89 Electricity Trade 6.76 13.35 24.29 32.44 69.18 Total 100.00 100.00 100.00 100.00 100.00 31. REVENUE ALLOCATION YEAR PER CENT 1997 1998 1999 2000 2001 Energy costs 20.94 23.45 34.77 38.33 65.43 OMA 18.10 16.09 14.56 13.65 9.57 Taxes 6.97 6.93 5.69 4.94 2.21 Depreciation 13.48 13.39 11.40 10.78 4.82 Finance Charges 25.76 22.91 20.21 16.64 7.09 Payment to the Province 11.50 14.33 10.71 9.86 4.72 Restructuring Costs 0.78 0.00 0.00 0.00 0.00 Customer Profit Sharing 0.00 1.25 0.00 0.00 3.93 ETO costs 0.00 0.00 0.39 0.00 0.00 RSA 0.00 0.00 0.00 3.71 1.31 Retained Earnings 2.47 1.64 2.27 2.10 0.94 100.00 100.00 100.00 100.00 100.00 T R I P L E B O T T O M L I N E A P P E N D I C E S | 8 8
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2001 Triple Bottom Line Report - BC Hydro

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