Exhibit 99.9
PECO ENERGY
Schedule of Rates
Schedule of System Average Rates
(cent)/kWh
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Effective Date Transmission(a) Distribution T&D Rate CTC/ITC Credit for Generation
Cap(b) Delivery Rate
Service Only Cap(c)
(1) (2) (3) (4) (5) (6)
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January 1, 2002 0.45 2.35 2.80 2.51 4.47 6.98
January 1, 2003 0.45 2.35 2.80 2.47 4.51 6.98
January 1, 2004 0.45 2.41 2.86 2.43 4.55 6.98
January 1, 2005 0.45 2.41 2.86 2.40 4.58 6.98
January 1, 2006 0.45 2.53 2.98 2.66 4.85 7.51
January 1, 2007 N/A N/A N/A 2.66 5.35 8.01
January 1, 2008 N/A N/A N/A 2.66 5.35 8.01
January 1, 2009 N/A N/A N/A 2.66 5.35 8.01
January 1, 2010 N/A N/A N/A 2.66 5.35 8.01
<FN>
(a) Transmission prices listed are for illustration only. The PUC does not
regulate rates for transmission Service.
(b) T&D Rate Cap (column 3) = sum of columns (1)+(2).
(c) Generation Rate Cap (column 6) = sum of columns (4)+(5).
</FN>
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Notes:
o Average figures for CTC/ITC from 2002-2010 in column 4 are fixed, subject
to reconciliation for actual sales levels.
o The credit (paid to delivery-service-only-customers) figures in column 5
will be adjusted to reflect changes due to the CTC/ITC reconciliation.
o Average transmission and distribution service rates will not exceed the
figures in column 3.
o The generation portion of bills for customers who remain with regulated
PECO generation supply will not, on average, exceed figures in column 6.
o Calculation of average rates for 2002:
9.96(cent)/kWh (existing rate cap) - 1.8 percent reduction = 9.78(cent)/kWh
9.78(cent)/kWh = 2.80 (column 3) + 2.51 (column 4) + 4.47 (column 5)
PECO ENERGY
CTC Amortization
Annual Stranded Cost
Amortization and Return(a)
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Annua Revenue Excluding GRT
Year Sales CTC Total Return @ 10.75% Amortization
---- ----- --- ----- --------------- ------------
MWh (cent)/kWh ($000) ($000) ($000)
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2002 34,381,485 2.51 825,004 516,869 308,135
2003 34,656,537 2.47 818,352 482,401 335,951
2004 34,933,789 2.43 811,540 444,798 366,742
2005 35,213,260 2.40 807,933 403,555 404,378
2006 35,494,966 2.66 902,623 353,070 549,553
2007 35,778,925 2.66 909,844 290,627 619,217
2008 36,065,157 2.66 917,123 220,312 696,811
2009 36,353,678 2.66 924,459 141,229 783,231
2010 36,644,507 2.66 931,855 52,381 879,474
<FN>
(a) Subject to reconciliation of actual sales and collections. Under the settlement, sales are estimated to
increase 0.8 percent per year.
</FN>
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Other Features
o The transmission & distribution and capacity market price bidding
rate cap of 2.98 cents per kWh process. PECO-affiliated suppliers
includes .01 cent for a sustainable will be prohibited from bidding for
energy and economic development this block of customers.
fund during the rate cap period.
o As of January 1, 2001, PECO (as
o PECO is permitted to transfer PLR) will price its service to
ownership and operation of its residential customers within a
generating facilities to a separate specified range.
corporate entity. The generating
facilities will be valued at book o A Qualified Rate Order authorizing
value at the time of the transfer. securitization of up to $4 billion
is included (subsequently increased
o Twenty percent of residential to $5 billion).
customers will be assigned to a
provider of last resort (PLR),
other than PECO, on January 1,
2001. The PLR will be selected on
the basis of a PUC-approved energy