HomeMy WebLinkAbout1975 GO I i
F 6
yREPORT ON ELECTRIC RAMS
DENTON MUNICIPAL UTILITIES
DENTON, TEXAS
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BLACK & VEATCH/consulting onalneArs
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BLACK & V EATCH TWL.18161361.7000
CONSULTING ENGINEERS TELEX 42.6263
1600 MRADOW LAKL PARKWAY
MARINO A00019 85i I,OX01 NO. 404
KAN4Af V7Y, MIt40UR1 64114
4 June 10, 1975
Mr. Douglas P. Blackburn
Director of Utilities
City of Denton
Denton, Texas 76201
Dear Mr. Blackburns
We are submitting herewith a report covering our study of rates of the
Denton electric system.
The scope of our work has included projections of energy sales and revenues
under present rates and revenue requirements of the electric system for a
period beginning fiscal year 1975 through fiscal year 1960. A determination
has been made on the basis of this analysis of the needed overall level of
rate adjustment by the utility. A complete set of electric rate schedules
has been designed that will provide a 13.1 per cent overall increase in
revenues from basic rates and are included herein for the Cityt+s consideration.
Tables have been prepared to shoo comparisons of Denton's present and
proposed electric rates with the rates of other utility systems to the general
region.
We appreciate the opportunity to be of service in this matter and will be
available to present the report at your convenience.
Very truly yours,
BLACK & VEATCH
P, K. Co.^krell
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TABLE 01 CONTENTS
Mot
INTRODUCTION 1
FINDINGS AND RECOMMENDATIONS 1
PRO FORMA STATEMENT OF INCOME 5
A. GENERAL 5
B, OPERATING REVENUES 5
1. Retail Sales 5
2. Sales for Resale 9
3. Other Operating Income 9
C, OPERATING EXPENSES 10
1. Fuel Expense 10
2. Other Production Expenses 10
3. Transmission and Distribution Expense 10
4. Administrative and General Expense 10
5, Reclassified to Capital Accounts 10
6. Depreciation 11
D, OPERATING INCOME it
E. OTHER INCOME 11
F, BOND INTEREST 11
G, NET INCOME 12
PRO FORMA CASH FLOW ANALYSIS 13
A. GENERAL 13
B. BOND RESERVE PAYMENT 13
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C. RESERVE FOR EXTENSIONS AND IMPROVEMENTS 1S
D. TRANSFERS TO CITY GENERAL FUND 1S
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E. ADEQUACY OF EXISTIA, RATES 15
ANALYSIS OF RATES 18
A. GENERAL 18
B, DESIGN OF RATES le
1. Rooldential Service 18
2. Commercial Service 19
3. Municipal Service 20
4. Lighting Service 21
S, Summary 21
TYPICAL SILL COMPARISON 23
APPENDICES
Appendix A - Proposed Rate Schedules
Appendix B - Present Rate Schedules
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LIST OF TABLES
Table 1 - Statement of Actual and Projected Energy Sales
and System Losses 6
4
Table 2 - Pro Forma Income Statement, FY 1970-1980 7
Table 3 - Pro Forma Cash Plow Analysis, FY 1970-1980 14
Table 4 - Relation of Surplus or Deficit Revenues to Revenues
from Base Rates 17
Table S - Comparison of Revenues Under Vxisting and Proposed
Rates, Fiscal Year 1974 22
Table b - Typical Bill Comparison 24
Tablu 7 - Typical Bill Comparison at $0.82 Pet Million
BTU Fuel Cost 26
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INTRODUCTION
This report" summarises a study of revenue requirements of the Denton
electric system and presents findings and recommendations concerning rate
` adjustments for consideration by the City. The analyses conducteJ are based
on results of operations during a teat year ended September 30, 1974,
Proposed rate schedules have been developed based on the cost of service
requirements during the tent year period and the indicated need for overall
rate adjustment to satisfy the financial obligations of the utility in
immediate future years.
Comparisons have been made of Denton's present and proposed electric
rates with the rates of others in the general region and are shown in
tabular form in the text of the report,.
A copy of both the present and proposed rates schedules have been :J
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included for reference purposes in Appendices to the report.
FINDINGS AND RECOMMENDATIONS
It is found that total revenues of the Denton electric system during
fiscal years ended September 300 1973 and 1974 were insufficient to provide
for revenue requirements of the utility by amounts of $201,000 and $337,000,
respectively. It is estimated that under present rate levels the deb cit
will increase in future years from $431,000 in fiscal year 1915 to
$1,013,000 in fiscal year 19804 The cumulative deficit for the period
beginning fiscal year 1976 through fiscal year 1980 (October, 1975, through
September, 1980) is estimated to be 11.2 per cent of total revenues from
basic rates.
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Bond ordinances require that 12.5 per cent of each dollar of gross
revenue be paid into the ut'iltky'e Extension and Improvement fund. As
a result, a rate increase of 12.8 per cent is necessary to net an 1162 per
cent increase in basic rates, A total increase in basic rates (before
fuel adjustment) of about 13.0 per cent is therefore recommended to
satisfy the financial obligations of the electric system for the next five
years and to provide a small surplus in immediate future years.
It is found that "small use" residential customers whose summer usage does
not exceed 700 kilowatt-hours are paying costs of service to a reasonable
degree. Residential customers that use over 700 kilowatt-hours per month
during the summer season have a highly seasonal load, on the average, and
fail ttb pay costs of service by 14 to 20 per cent, dependent on level of
usage, Separate rate scheeuler are therefore recommended for small use and
large use residential customers in order to reflect the difference in load
characteristics and coats of serving the two groups,
No change is recommended in the rate applicable to small use customers
with the excepts^.e of two minor modifications including an increase in the
minimum bill and a revision of the fuel adjustment feature of the rate
scheduler ',.i overall increase of 14.7 der cent in basic rate charges is
recommended for urge use residential customers,
A winter season rate is proposed for both small use and large use
residential customers. It is also proposed that an incremental rate charge
be continued for consumption of over 700 kilowatt-hours during winter
months fur homca that use electric heat as the sole source of a nu:urt heating,
2
'9"' 177
It is recommended that Rate Schedules B-1 and B-2, which are applicable
to 514811 and large use commercial and industrial customera, be continued
in about their present form, It is proposed that the fuel adjustment and
minimum charges of the 2•4 rate schedule be revised and that an expanding
block feature be added to provide the equivalent of a demand charge for
loads of over 20 kW, It is also proposed that where the last block of the
present B-1 rate for usage in excess of 109000 kWh is generally not applicable
to the loads of 20 kW or lose served under this rate, that it be eliminated.
The small use commercial customers served under Rate Schedule B-1 make an
eAsquate payment towarde costs of service, and, except for the foregoing,
no change in the B-1 rate is recommended.
The proposed B-2 rate has been revised in accordance with cost of service
considerations to provide an overall increase in the basic rate charges of
4
12,5 per cent. The level of increase is somewhat lower than 12.5 per cent
for smaller customers and about 15 per cent for the largest customers served
under the rate. The winter rate feature of the proposed B-2 rate schedule
applicable to apartments has bean simplified,
A fuel cost Adjustment provision, wherein any increase in fuel coats
above a base amount to passed cn to consumers, is presently applicable
as a feature of the residential and the commercial and industrial rate
schedules, Current fuel coats are approximately 140C per kilowatt-hour
of generation which amount is over three times greater than the allowance
for fuel cost included in the present basic rates. In order to better
reflect actual costa of service, it is recommended that the fuel cost
of 1.0C per kilowatt-hour be included as an integral part of all rate
3
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charges of the utility, It is also recommended that the present fuel
adjustment clause be concurrently revised in statement to provide that
•
the fuel adjustment amount be based on actual cost of generation, rather
• than average cost of fuel, and to incorporate the cost of purchased energy
each month. The proposed adder to all rates under this procedure is 0.850
per kilowatt-hour and the level of charges under the revised fuel adjustment
clause have been reduced a like amount.
It is recommended that the fuel adjustment clause be made applicable
to the City's municipal rates as a means to recover out-of-pocket energy
related costs on a cvrrent basis. It is also recommended that the municipal
rates along %tth all present rates for lighting service be increased 0,850
per kilowatt-hour to include the increase in energy related costs since the
rates were established. In the future, the rates for righting service
should be reviewed by the utility on a regular basis to insure that an
adequate allowance is included for costs of fuel and purchased energy.
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PRO FORMA STATEMENT OF INCOME
A. GENERAL
A pro form statement of revenues and revenue requirements for the
Denton electric utility system for fiscal years ending September 300 1975
through 1960 has been developed based on analysis of historical financial
data, average number of customers, and nat system generation and energy
sales. In making the projections, historical trends have been adjusted
to reflect anticipated future conditions.
8. OPERATING REVENUES
1, Retail Sales. Table 1 presents a summary of total kilowatt-hours
bold by customer class and system losses for fiscal years 1970 through
1974 along with projected sales and losses by years through fiscal year (FY)
1980, Actual and projected revenues by customer classes are shown in
Table 2 as a part of the pro forma statement of income for fiscal years
1970 to 1980. The projectione of future revenues from sales are based on
an analysis of the historical number of customers, average annual kilowatt-
hour consumption per customer, and ~init revenue per kilovott-hour,
The following tabulation is presented to show the total customers by
rate classes served during FY 1974, the test year of this study, along
witn kilowatt-hour sales and revenues.
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TABLE 1
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DENTON, TEXAS
ELECTRIC SYSTEM
STATEMENT OF ACiIJAL AND PROJECTED ENERGY SALES
AND SYSTEM LOSSES
~1) (2) (3) (4) (5) (6)
Commercial Municipal System Sales
Fiscal and and Dusk-to-Dawn System Plus Losses
Year. Residential Industrial Stregt Lights Lights Losses ,_(I) to 5 -
MwId Mwh Mwh Mwh Muh MWh
Actual
1970 80,313 1830054 16,814 377 19,734 3000292
1971 85,933 1910351 18,061 414 23,210 3196169
1972 x45,412
1913 1050412 2212380706 18,642 457 16,386 368;804
,135 209103 520 2x,640 384'0500
1974 106,251 251,315 200374 392 27,887 406,419
Projected
1975 1179146 260,275 21,233 683 27,fbb2 427.00
1976 122,917 274,500 21,8!3 717 29,241'1 445 21
1977 128,878 290,970 229438 894 30,809 413,989
1978 13300311 309,883 23,031 14035 32,604 3019-603
1979 141,468 331,373 23,672 10200 34,614 532,529
1980 1480004 356,443 24,314 19365 36,854 566,980
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TABLE 2
DOWNS TEXAS
AT,IFMIC SYSTEM i
PRO FORMA INCOME STATEMENT
FY 19%0-1980
(1) (2) (3) (4) (5) (6) (7) (8) (9)I~ (10) (lI)
scal Year Ending September 30 _
Actual Projected Uain Preset Rates
1970 1971 1972 1973 1974 1975 1976 1977 197 1979 1980
1,000 1,000 $1,000 1,000 10000 1,000 $10000 1,000 1,0 0 $1,000 $1,000
Operating Revenues
Retail Sales
Residential 1,734 10855 2,172 2,145 21337 2,413 29520 21629 2,741 2,858 29975
Commercial 21483 2,596 2;946 3,247 3,350 30540 39733 1,937 492X4 40509 40848
Municipal(a) 199 214 196 215 220 226 232 238 2~5 252 258
Dusk-to-Dawn Lights 16 18 19 22 25 29 33 38 4 51 58
Fuel Adjustment - - - 479 786 1#963 2,842 3,821 4,916 6.150 741
Total 4,432 40683 5,333 6,108 6,718 8,171 9,360 10,683 129140 13,820 15,680
Sales for Resale 8 23 40 '88 367(d) (e) (e) (e) (e) (e) (e)
Other Operating Revenues 70 88 92 84 134 95 95 95 95 95
Total Operating Revenue 49510 41794 59465 69280 70219 8,266 99455 100778 12,25 13,915 15,775
Operatin4 "'gxpensae
Fuel 887 951 18155 1482 2,340 3,289 40259 5,337 6j51 7,892 99412
Other Production 397 466 464 564 647 725 812 909 19018 1,141 1,277
Transmission b Distribution 409 531 521 384 428 454 481 510 5.0 573 607
Administrative 6 General 540 431 A4 575 532 600 630 662 615 730 767
Reclassified to Capital Accts.(b) (131) (126) (189) i - - - -
Dtpreciation 739 777 810 ss2 973 1j042 1.069 1,095 1j,1 3 11151 1,179
Total Operating Expenses 2,841 39030 3,305 40258 4,920 6,110 7025;, 89513 9,9 .7 11,487 13,242
Operating income 1,669 1,764 2,160 2,022 2,299 21156 2,204 20265 29318 2,428 29533
Other Income (Interest) 81 241 196 1 9 197 226 243 234 2 5 216 208
1,750 20005 2,356 25221 2,496 2,382 2, 4 2,7199 2,5 3 2,644 2,741
Bo,td Interest (c) 446 623 537 X868 8741
1.033 1,001 951, 8 9 847 793
1
Net Income 1$04 10382 19799 1,r351 11619 1,349 10446 10548 1164 1,797 1,948
(a) Includes street lighting and sales to state highway department,
(b) Reclassi;ications are principally capitalized wages and salaries.
(c) InclUO.ca proposed $2,000,000 issue in FY 1976 at 6 per cent.
(d) Includes $185,000 settlement of inadvertent power exchange.
(e) Resale revenues and corresponding full expense omitted.
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Number of Customers, Energy Sales, and Revenues
Fiscal Year 1974
Average Energy
Number of Energy Sales per Revenues Unit
Customers Saltss Customer from Sales Revenues
ea Mwb. kWh S ' C/kWh
Residential 100850 106,251 9,793 2,5720051 2.42
Commercial 7,829 2519315 137,406 3,900,316 1.55
Municipal(a) 271 15,268 560338 1670810 1,10
Lighting Services
Street Lights 3,375(b) 5,106 1,513 52,073 1.02
Dusk to Dawn Lights 546(b~ 592 10084 25,229 4.26
Total 3 W(b 5,698 77,302
Total, Retail 1212 0f ) 378,532 6,717,979 1777
(a) Includes municipal and county agencies and local school districts.
(b) Average number of lights.
(c) Excludeq lighting units.
• Service to residential customers includes sales to approximately 64
per cent of the customers and accounts for 28 per cent of the kilowatt-
hours sold du...tng the test year. Analysis of historical data for residential
/ service generally indicates a stable increase in the number of customers but
a reduced rate of increase in average use per customer, The base rate revenue
for kilaAtatt-hours sold in fiscal years 1970 through 1974 (revenues excluding
amount for fuel adjustment) has served as the basis for projecting revenues
from this class, An approximate level of fuel adjustment has been applies
to estimated kilowatt-hours sold to develop estimated revenues which would
be derived from appli.:ation of the fuel cost adjustment clause in future
years,
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A similar analysis was applied to customers served under Denton`s
commercial rates. Projections or revenue from sales to governmental agencies
and for street lighting and signal systems exclude the application of fue'.
cost adjustment charges in accordance with present practice of the utility.
Projected revenue for Dusk-to-Dawn lights is based on a projection of the
number of lights times the e%erage unit charge per fixture.
The total retail sales including fuel adjustment are estimated to increase
from $6,718,000 in FY 1974 to $15,680,000 in FY 1980. It should be noted
that $7,5410000 of the estimated revenues in FY 1980 are expected to be
derived under the automatic rate adjustment clause for increased fuel costs.
i
2. Sales for Resale. Sales for 4'.+eale represent the dollar value of
net interchange between Denton and the bEcer members of the Texas Municipal
Power Pool (TMPP). Revenues from this source were not significant in the
past except during FY 1974. Sales to TMPP during the test yeo.r PY 1974
Included 50,089,836 kilowatt-hours generated with fuel purchased by Denton
and 56,580,500 kilowatt-hours generated with fuel purchased and supplied
to Denton by other members of TtU'P. Due to tiie nature of these off-system
sales and the lack of effect on revenue requirements from retail customers,
no attempt has been made to project future revenues from this source.
3. Other Operating Income. This 4ategory includes revenues from
penalties, reconnection fees, collection of charged-off accounts and other
misael'taneous sources. In recent years, this category of revenues hai
averaged about $99,600 per year. An amount of $95,000 has been used as an
estimate of revenues from this source througho+it the study period.
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C, OPERATING EXPENSES
1. Fuel Expense. Currently', Denton receives gas supply from the
Lone Star Cas Company and from the Pitts gas field which is leased jointly
r by the members of TMPP. In addition, Denton used a small amount of diesel
fuel during the teat year. Fuel expense, shown in Table 20 has increased
from $887,318 in FY 1970 to $2,339,827 in FY 1974. The average cost of fuel
per kilowatt-hour of generation has increased from 0.2950 in FY 1970 to
0.5130 in FY 1974. The cost of fuel is expected to continue to rise
throughout the study period.
2. Other Production Expenses. This category of expense includes all
operation and maintenance expense for power production other than fuel
expense. Based on an analysis of recent experience this category is
projected to increase at a 12 per cent annual rate,
3, Transmission and Distribution Expense. The primary elements of
transmission and distribution expense are salaries and wages and mainte-
nance expenses. These expenses have been projected at a b per cent annual
growth rate,
4. Administrative Arid General Expense. This category includes the
electric utility's pro rata share of utility administration and its share
of administrr:tive services provided by the city government. The projected
annual rate of increase for this expense is 5 per cent.
5. Reclassified to Capital Accounts. The amounts included in this
category represent adjuotments to capitalize portions of certain items,
such as salariest which were charged to expense during the year.
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6. Depreciation. Depreciation expense has been developed by a.pplying
a cotoptsite depreciation rate to projected average plant in service during
ecah year. Investment in plant at the end of each year has been determined
by adding estimated normal additions to be financed from the Extension and
Improvement Fund, plus expected major additions to be financed with revenue
bonds, to the beginning plant balances each year less estimated retirements
during the year.
D. OPERATING INCOME
Operating income, which is the difference oetween operating revenues
and operating expenses of the utility, is projected, as shown in Table 2, to
be a relatively constant amount in future years. This residual amount is
referred to as the "return on investment" for investor ownrd utility systems,
%nd is availaile for all other fiscal needs of the utility including debt
service on revenus bonds, reserve funds, financing of extensions and
betterments, and payment to the City General Fund.
E. OTHER INCOME
Other income consists primarily of interest earned on invested funds.
The amount of interest earned fluctuates annually depending upon the availa-
bility and balances of funds and vary'ng interest rates. For this study,
other income has been projected based on the historical experience shown by
Table 2 with consideration of expected balances of construction funds
provided by the sale of revenue bonds.
P. BOND INTEREST
The total interest expense includes that shown by payment schedules for
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.6 ,
existing bonds, plus estimated 6 per cent interest on a $20000,000 issue of
revenue bonds assumed to be sold at the beginning of FY 1976 to finance
transmission and distribution system improvements in fiscal year 1976.
G. NET INCOME
Net income from the electric system operation, shown as the resultant
amount in Toble 2, was $1,619,000 during FY 1974. It is projected to
decrease to $1,349,000 in FY 1975 and then to increase to $1,948,000 by
FY 1980.
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PRO FORMA CASH FLOW ANALYSIS
A. CENERAL
,
Table 3 presents a summary of the cash requirements of the electric system
for the period FY 1970 through 1980. This table reflects the same revenues
as Table 2. The totals shown for operation and maintenance expense in Table 3
exclude allowance for depreciation which is a non-cash expense. The amounts
shown for debt service in Table 3 include principal payments on revenue bonds
as well as the Interest expense previously shown. The funds provided by
depreciation expense and net income are available to meet the non-expense
cash requirements of the utility which include in addition to bond principal,
Bond Reagrve payments, funding of the Reserve for Extension and Improvements,
and tfansfers to the City Cenernl Fund.
B. BOND RESERVE PAYMENT
Existing bond ordinances require that a monthly payment to be made into
a Bond Reserve Account so that an aggregare amount equal to the maximum future
principal and interest payment is accumulated within a period of 60 months. The
total requirement for this fund is estimated to be $1,947,000, the maximum
principal and interest on all outstanding bonds including the $2,000,000 to be
issued in FY 1976. if the account ie depleted by any amount, additional payments
are required until the fund is restored. The monies available in this fund
may only be used for meeting debt service requirements when the funds at?ailable
in the Interest and R9demption Fund are insufficient to meet the then maturing
principal and interest requirements. Annual payments to the Reserve Account,
shown in Table 3, are estimated at $60,000 throughout the study period.
13
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TABLE 3
DEl^t i'ON j TLUS
ELECTRIC SYSTEK
PRO FOW{A CASH FLOW ANALYSIS
PY 1970-1980
(1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11j
Fiscal Year Endin September 30
Actual Pro ected Using Preset Rates
1970 1971 1972 1913 1974 1975 1976 1977 197 1979 1 8fl
$1,000 $ I.
Revenues 1 ► 000 T1-'000 $1,000 $1 ,Q00 ,000 $1,000 1,000 *11090 1,000 l~ pp
Retail Sales 49432 4,683 5,333 60108 6,718 80171 9,360 100683 12,160 13,820 150660
Sales for Resale 8 23 40 88 334 (b) (c) 95 `c95 (c95 (c) (c)
Other Operating Revenues 70 88 92 84 (c95
TOther; ,come es (Interest) 81 241 196 199 5 95
197 226 243 234 2 5 216 205
Requirements 4,591 5,035 5,601 6,479 W1 6 8,492 9p698 11,012 12, q0 14,1 1 15,983
Revenue Requirements
Operation and Maintenance Expense
Excluding Depreciation
Debt 21102 2,253 2,445 31446 3,947 5,068 6,182 7,418 8,7414 10,336 12,063
vica(a~ 11057 1,9417 1,465 10644 19932 19881 20071 2,041 2, 9 ,
1974 10041
Bond ' ,,~serve Payment 64 46 78 88 200 - 119 b0 60 0
Reserve for Extensions and Improvements 119 596 708 810 927 1.062 1 212 1 377 1 5 0 1 7660 6 M OR
Subtotal '
► 3,j65 To '31 4,746 5., 810
7,006 8,130 9,525 10,89 12, 14 1 16
6 1 0'
Payment to City 429 653 680 732 747 793 811 834 8 2 895 934
Total Revenue Requirements 4,394 49635 5,426 6 0 7,753 8,923 10,336 11,730 13,2 5 15,031 -1 9-6
Surplus or (Deficit) 197 70 235
(301) (337) (431) (638) (718) (805) (900) (1,013)
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(a) Includes debt service on existing Issues and a proposed $2,000,000 issue in FY 1976,
(b) Includes $185,000 settlement of inadvertent power exchanges
(c) Resale revenues and corresponding fuel expense omitted.
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C. ASERVE FOR EXTENSIONS AND IMPROVEMENTS
Under existing bond ordinances, the utility is required to deposit not
less than 12-1/2 per cent of the gross revenues of the utility in a reserve
for extensions and improvements. Monies in this fund may be used only for
the purpose of making extensions and improvements to the system or to retire
revenue bonds prior to their maturity. In addition, the monies may be used
to augment the Interest and Redemption Fund and Reserve Account when the
amounts in those funds are insufficient to meet principal and interest
requirements.
D. TRANSFERS TO CITY GENERAL FUND
The electric utility makes a payment to the City Cenerai Fund, in
accordance with the Clty Charter and terms of the revenue bond ordinances,
based on a maximum allowed rate of 6 her cent of the City's equity in the
electric system at the end of the previous year. The City's equity is defined
as being equal to the sum of the balances in the Bond Reserve Account and the
Extension and Improvement Fund plus the unrealized increment in valuation of
utility plant in service, contributions in aid of construction, and retained
earnings. Transfer to the City has been projected at the present 6 per cent
rate during the study period.
E. ADEQUACY OF EXISTING RATES
Table 3 summarizes the cash requirements of the electric system. As shown
in the table, it is projected that the utility will incur deficits in each
year of the study period. The deficits are expected to increase in size
throughout the period from $431,030 in FY 1975 to $1,013,000 in FY 1980.
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Table 4 shows the relationahip of system surpluses, or deficits to
revenues from basic rates. The cumulative deficit over the study period is
estimated to be $4,505,000 and would required 10.5 percent more revenues
from the basic rates to break even. An 11.2 per cent rate increase at the
beginning FY 1976 would be necessary to offset the estimated deficits to be
incurred FY 1976 to FY 1980, and an even larger increase is necessary to
offset the cumulative deficits if any part of the FY 1975 deficit is included.
Because of the ordinance requirement that 12-1/2 per cent of each dollar
of gross revenue be paid into the Extension and Improvement Fund, a rate
increase of 12.6 per cent, for example, is necessary to net an 11 per cent
increase in base rates (without fuel adjustment clause). Therefore, an
overall increase of at least 13 per cent is indicated to provide adequate
operating revenues to fulfill the financial obligations of the Denton
elegtric system its near future years.
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TABLE 4
DENTON, TEXAS
ELECTRIC SYSTEM
RELATION OF SURPLUS OR DEFICIT REVENUES TO REVENUES FRAM BASE RATES
evenues (3) (4) {5) Surplus or (Deficits Rgvr Pies
Fiscal Retail Sales Other Total R(~ver-,e Amount 'kkW4io
Year Base Rates Fuel ~ Revenue (1)+(2)+(3) Requirements - 5 (6) -t (1)
Actual $11000 10000 $I.000 $10000 $1,000 $1400 x
1970 4,432 - 159 4,591 4,394 197 4.4
1971 4,683 - 352 5,035 4,965 70 1.5
1972 59333 - 328 5,661 5,426 235 4.4
1973 3,629 479 371 6,479 6,680 (201) (3.6)
1974 5,932 786 698 7,416 7,757 (337) (5.7)
r
Projected
1975 6,208 1,963 321 8,492 8,923 (431) (619)
1976 6,518 29842 338 9,698 10,336 (638) (9.8)
1977 6,862 3,82`. 329 110012 11,730 (718) (1015)
1978 1,244 40916 320 12,480 13,285 (805) {11.1)
1979 7,670 69150 311 14,1.31 152031 (900) (21'.7)
1980 89 139 79541 303 15,933 16,996 (1,013) (12,4)
1975-80 429641 (41505) (10.6)
1976-80 36,433 (40074) (11,2)
i
I
i
ANALYSIS OF RATES
I
A. GENERAL
Present and propoo:d rate schedules al
commercial and industrial customers, and toduakltotda~ service lights are incluL,td
appendix to this report,
B. DESIGN OF RATES
The proposed rates have been designed considering principally the overall
revenue requirements of the utility along with Cost of service by type and
character of loads. In addition, recognitiool has been given to the level and
Aestgn of Denton'e existing rates and to the rates for comparable service by
other electric utility systems.
1, Residential Service, Tha existing rate schedule for Residential
Service A-1 has been divided into two schedules, The proposed schedule A-1
to intended for small residential customers whaAe maximum monthly summer us
does not exceed 700 kilowatt- e
hours and who use little or no summer season air
conditioning equipment, The proposed schedule retains the declining block
feature) of the existing rate schedule, It provides a separate rate applicable
to usage during the billing months of November through April, in addition to
an incremental charge for use over 700 kilowatt-hours in the winter months for
homes k-hich use electric heat as the sole source of comfort heating;.
It was found, in general, that small non-air conditioning customers are
meeting their costs ui service. This group represents about 20 per cent of
the residential users but only accounts for about 5 per cent of the residential
kilowatt-hour sales. Only the so-called "convenience users'' (such as unoccupied
18
residences, etc.) with usage of less than 50 kilowatt-hours per month in
this class failed to meet their allocated cost. To adjust for this condition,
the minimum bill has been raised. All steps of the rate, incluAing the minimum,
reflect the approximate current cost of fuel of 1.0c per kilowatt-hour.
Schedule A-2 is intended for the large use residential customers whose
requirements during summer months exceed 100 kilowatt-hours. The proposed
rate schedule consists of a fixed cost charge plus a flat rate energy charge
in the summer billing months and the same fixed cost charge plus a two stej~
energy rate in the winter billing months. An incremental rate is provided'
for customers whose e( home is electrically heated. As with Ratc Schedule
A-11 all charges have been adjusted to reflect fuel cost of 1,Oo per
kilowatt-hour.
2, Commercial Service. Under existing rate,.,service to commercial and
industrial customers is provided under tvo rates - Schedule B-1 which is
intended for commercial customers whose nonthly demand is less than 20 kilowatts,
and schedule B-2 which is intended for larger customers whose monthly demand
exceeds 20 kilowatts. Of the approximately 1,800 customer's served under
these ser.edules in FY 19740 10375 received service under the B-1 rate and
425 under the B-2 rate.
The proposed B-1 rate is an energy rate intended to be applicable to the
same types of commercial customers as the existing rate. The basic rate
charges have been adjusted to reflect the increased coat of fuel and tht
minimum charge has been increased to more closely reflect the costs to
serve this class of service. In addition, an expanding block feature
applicable to customers with power demand of greater than 20 kilowatts has
19
I
'y
has been incorporated into the rate. This feature was designed to recover
costs of serving large commercial customers with low load factors and to
provide transition with tLe B-2 rate when demand exceeds 20 kilowatts.
The propose!.:: B-2 rate is a demand-energy rate with about the same features
as the existing rate. The proposed rate is designed to serve loads of 20
kilowatts and larger. The proposed overall increase in rates to customers
served under this rate is 12.5 per cent, with the average being somewhat
lower for smaller customers and a greater amount (about 15 per cent) for
customers whose demand is greater than 300 kilowatts.
3. Municipal Service. Service under this rate is restricted to city,
Bounty, and local school districts. It does not apply to state or federal
agencies, North Texas State University or Texas womens University all of
which are served under either B-1 or the B-2 rates. Under the present
agreement with the City, the rate for municipal service is 1.250 per
kilowatt-hour for all sales except those to the water utility and the
sewage utility. For these latter services, the rate is 1.00 per kilowatt-hour.
Because of the rapidly escalating cost of fuel, it is recommended the fuel
cost adjustment charge be made applicable to sales under this classification.
Based on the fuel cost incorporated into retail rates, the basic rate proposed
for municipal service is 2.100 per kilowatt-hour and for sales to the water
utility and sewage utility is 1.850 per kilowatt-hour. These rates will be
adjusted as necessary based on the fuel cost adjustment rate applicable to
retail sales. If the fuel cost adjustment had been applied during the test
year, the additional revenue from this class would have been $44,000.
20
4. Lighting Service. Service provided under this classification consists
of sales to the city for street lights and signal systems, sales to the State
Highway Department for lighting on the interstate highway, and rental of dusk
to dawn lights. Under the existing agreement with the City, the electric
system receives 1.00 per kilowatt-hour for energy requirements of the street
lighting and signal systems. The State Highway Department povs 1.00 per
kilowatt-hour plus the costs of maintenance. The rate schedule for
-'Us{.-to-Dawn lights is shown in the appendix. At 1.00 per kilowatt-hour,
the rate for street lighting and signal systems presently only covers the
fuel expense portion of costs and therefore should be adjusted to at least
include the increase in energy related costs rsalized since the rate was
established, This adjustment amounts to 0,850 per kilowatt-hour.
The existing rates for Dusk-to-Dawn lights have been adjusted to
reflect the increased cobt of fuel, In addition, it is recommended
that no new rentals of 250 watt lamps be accepted after the effective
date of the proposed rate schedules.
5. Summary. A sv=ary of revenues under existing and proposed rates
is shown in Table S, It is calculated the proposed rates will produce an
overall increase in revenues from sales of 13.1 per cent roldted to basic
rate charges and 12.2 per cent when compared with total rata charges,
including the amount for fuel adjustment, during PY 1974,
21
i
TABLE 5
DENTON, 'T'EXAS
ELECTRIC SYSTEM
COMPARISON OF REVENUES UNDER EXISTING
AND PROPOSED RATES
Fiscal Year 1974
Without Fuel Adjustment With Fuel Ad ustment(a)
Zxisting Proposed Per Cent Existing Proposed Per Cent
Rates Rates Increase Rates Rates Increase
Rejidential (A-1) 2,337,377 2,6810000 14.7 2,5729051 2,9169000 13.4
N
N Commercial
Small Users (B-1) 684,810 731,000 6.7 741,654 7880000 6.2
Large Users (8-2) 2.664,658 21999,000 12,5 3,159.162 3 493,0(10 10.6
Total 3,3499468 3,730,000 11.4 3,900,816 412819000 9.7
Municipal 1679810 168,000, - 167,810 212,000 26.3
Lighting Service
Street Lights 51,073 96,000 84,4 52,073 969000 84.4
Dusk to Dawn Lights 25,x,,229 3_„ 3,000 30.8 25,229 33,000 30.8
Total 770302 129,000 66.9 77,302 1290000 66.9
Tots), Retail 509319957 6,708,000 13.1 617170979 705381000 12.2
(a) includes actual FY 1974 revenues from fuel cost adjustment
TYPICAL BILL COMPARISON
In Tables 6 and 7, typical bills under present and proposed rates ate
compared with bills for several other utility systems in Texas. It should
• be cautioned that because of the many cost related differences such as type
of service area, rate of growth, tax requirements, etc. which exist between
utilities, these comparisons are useful for general information only. All
bills shorm in fable 6 are based on rates and fuel adjustment charges or
fuel costs as of Jr..suary, 1975. Table 7 represents estimates of typical
bills applying the same cost of fuel (Denton's approximate cost of fuel at
year end 1974) to all system. This analysis indicates a favorable
comparison of Denton's present and proposed rates to the present rates of
other systems.
23
TABLE 6
OENTON, TEXAS
ELECTRIC UTILITY
TYPICAL BILL COMPARISON
i
Denton-Ex{sting Rates Dallas Power 6 Light Co. Texas Power t light Co, Bran Texas Garland,-Texas Greenyl
Greenvllle, Texas
Basic Fuel Basic Fuel Basic Fuel Basic Fuel De crl tin Rate Ad ustment(°) Total Rate AAdlu_ 5 stm_ent(°) Total-
.Raja . Ad ustment(°) Total Rate Ad ustment(l) Total BRate AdFustmcnt(I) ota) Basle Adl Basle Fuel
Rat Ad ustme,ht (I) Total
Fuel Cost Per M1111on BTU (b) 0, ~ OS SS s 0,21 0,28 0, $
2D 0,24 -f- p p O,S4 - I $ $ $ $ 0.34 (9) _ 0,20 0
Residential, Summer 0,20 0117
Designatlon A-1 R-S RS-1 R RS L-1 I
Date Effective 1/65 8/74 3/74 2/25/75
L-I
100 kWh 4,32 U,72 5,04 4,48 044 4,82 S 14 0132 5,46 4,49 0,16 i $,45 4.16 0,45 4,61 4,56 0
254 kWh 1461 1019 9,40 8,38 OA 9,22 915 0.80 9495 8.71 1,89 10,60 8,28 1,12 `.9,40 8,42 I500 kWh 11488 3,58 15,46
13.55 1,68 15,23 14,28 1,61 15,89 13,48 3,78 17,26 13,28 2.23 15,51 14,21 2 4.56 0,48 5,04
8,42 1,21 9,63
750 kWh 16,16 5037 21,53 18,73 2,52 21,25 19,40 2,41 21,81 18,26 5.67 43 18,28 3,35 21,63 19,55 3. 14,21 2,42 16,69
L,000 kWh 20,43 7,16 21659 23, 19.55 3462 23.17
00 kWh 23,90 3,36 27,26 24,53 3,21 27 74 2; 03 7&56 1$5 23,28 4,47 2745 24.82 4 5 28,98 10,73 3901
33,48 5,04 38,52 ;4,01 4.82 38,83 32o58 11034 1 34,82 4,83 29,65
3,000 kWh 'k92 32,62 6.13 39d32 35,91 54,63 21,47 76,10 60,93 10,08 4 61,46 9,63 11,02 61,23 22,66
6,5F, 58,12 13640 71,52 61,77 14. 35.37' 7025 42.62
06 kWh 86,49 35,78 122,27 97,53 16,80 1114,33 98,06 16,o5 114,11 99.43 37,80 ;137123 92,12 22,33
114,45 96,97 24, 61,17 14,49 76,26
96,97 24,15 121`.12
Residential, Winter
106 kWh (Same as Summer Rate) 4,48 0,34 4,82 S,14 0,32 5,46 4,49 0'76
250 kWh 5,25 Game as Summer Rate) (Same as (Same as summer Rate)
9,22 9,15 0480 9195 8,71 1,89 10,60 700 kWh 8 0,84 13, S 1,68 15,23 14028 1,61 15,89 13,48 3,78
17,26
150 kWh 17x89 2,52 I! Al 18,58 2,41 20,99 17,#95 5,67 29662
1,o30,kwh 21,84 3836 2 ,20 22,3 3. 23,74 21,177156 (28,73
OO kWh 29,74 5,04 3x',78 30, 3 4,82 35,25 27,62 11,34 38,96
MOO k 53,44 10,08 63152 54,13 9,63 63,76 46,97 22,68 69,65
S,oDO kWh h 85,04 16,80 101,84 85.73 16,05 101,78 72,77 37,80 110,57
Commercial
Designation B-1 GS GS-I GS-S LC
Date Effective 1/65 8/74 3114 2/25/75
-3 X0-3
25% Load Factor
100 kWh - I kw 3,78 002 4,so 5609 0,34 5.43 5,66 0,32 5.98 5639 0,76 6115 4.61 0,45 5.06 5,62 h) 0,
250 kWh - I kW 9,45 1079 11,24 11,66 0,84 12,50 13,08 0 80 13,88 1213 189 14 02 10,46 112 11 58 :0,06 h) 5,62
h 0,48 6.10
1 500 kWh - 3 kW 18,90 3158 22,48 20,59 1,68 22,27 22,73 1061 24434 2;,35 3 78 27,13
20,21 2,23 22,44 23197 2, ;4,06 h) 1121 11,27
750 kWh - 4 kW 26,78 5,37 32,15 29,54 2,52 2,06 2o 4l 1,000 kWh 3 31,35 51 21 33 76 33 34 5 61
39 01 26 64 3435 305944
0 19 31139 3s e 5 kW 34,65 1,16 41,81 38,50 3,36 41,86 40 3,21 4;,72 38,39 7,56
45,95 33,34 4.47 37,81 11,22 4, 1139 3.62 26,2 1 35,21
I , 500 kWh - 8 kW 48,15 10, , 10,73 1088 54 02 5,011 S906 S8,51 24 4s82 63s06 48,49 d) 11
;4 S9 83 46;4 6.70 53,04 54 05 1 !1,22 4,83 4205
3,000 kWh - 16 kW 88,65 21,47 110,12 98 38 10,08 108,46 109 S4 9 6; 119,17 80641 )22 68 1103 39 82.89 13M 96029
lot, 26 its. ;4,05 7.25 61,30
5,000 kWh - 27 kw 137,25 35,78 173,03 158,06 16180 174,86 164,40~~) 16 05 180.45 138,63 d 37 80 176 43 124 8g 22 33
141 22 160 96 24 0-it. Ih no lot -or
1 ~
25,000 kWh -137 kw 5 240-75 0,75 178,88 689,63 644,52 84,00 728,52 626 21:40~J) 31*10 328,60 265.49 )85,60 341,02 218,30"' 44,65
322,65 303,46 48, ~w-s 1
80,25 701,65 613,12 ~8g,00 e02,12 615,80 111,63 127,4; 643,46 120, i
r
24
t~
n 1. 1 r .K rX
TABLE 6 (Cont'd)
• DENTON$ TEXAS
ELECTRIC UTILITY
TYPICAL BILL COMPARISON
I
_ Denton• j1t11Lq Aates Dallas Power b Llcht.5o _T'exa_ s Poser b l
Des rl lion Basic Fuel ia) Basic Fuel ~a~ Basic F'ue; Orvan. Texa Garland Te+•~ _ g Ad u ment Total Rate Ad
ustment Total Rate gd UStment(a) otal Basle _ ~reenvllle Tax~__
9as1c Fue1
AdFuelment T I BRata AdF $ ustment~t) Basic Fuel Cost Per Million BTU (b) S
$ S $ ; S --r - s - ..j..$ Total te ; 0,25 0.55 0.21 0.28 0.20 0.24 0,30 n,54 S S $
I ate Ad s m n To_otta_1_
Large Commercial ! o,34 (9) 0,20 0,20 0,37
De$IgmatIof) B, 2
Date Effective 1165 8LGS LP-20 lP•IK; LP-2(e)
3174 2125115 CS.L LC-3 LC-3
4096 load Factor
25 kW - 71300 kWh 178 052 4 230 20;N 25 228 196 23 2f
SO kW • 14,600 kWh 300 104 404 c)
!13 SS I 228 187 100 kit • 29~~OGO kIfi 1 Sf,042 9 S22 209 12 1►121 1628 49 394 331 4! 38
313 Ito 33 220 198
250 kV • ~ 1 628 98 726 595 9 689 5991 22i 8 2 S92 130 392 344 198
500 kW - 1 4b,000 kWh 1,845 1 245 10574 1009 234 1549 1 263 722 617 344 rjl 415
1,000 kW • 292,000 kWh 0045 2,690 2,241 491 2,732 2,245 469 2,114 2,192 1;504 1815 1, 13 326 1,639
1,436
2,500 kW . 730,000 kWh 3,214 2,089 5363 40054 481 5,o3S 3►960 931 4,897 3,900 2,206 6~,I96 3944 1652 521 281
2'80 p 304 1509 5223 12,732 9,493 20453 11,946 90107 2,343 11,450 9,025 50319 14,544 8,954 3,265 12821; 13,132 1,617 ! 1061
I3.5758
0g , 2802 5
60% load Factor 0 5,534 1,110 60944
25 kW • 10 95d kNh c215 78 3 246 ) 13,730 3626 17j256
50 kW - 2190o kWh 362 157 519 4 c) 37 283 248 35 283 216 83 3
100 kit • 43,$00 kVh c) 74 505 418 01 233 49 282 599 31 /0 488 403 166 1 569 416
254 250 303
250 kW - 109,500 kWh 1;217 912 799 141 97 106 946 756 141 8 ~ $14 429 3 3311 I ,031 152 196
948 788 429 106 535
500 kW - 219,000 kWh 78 2,OO1 1,591 3&S 19959 1,610 351 1,961 I,S31 3 828 788 212 1,000
i,0oo kW • 438400 kWh 4,0 0 3,534 3'144 4642 736 3,318 21690 703 3093 20681 1656 4319 1,641 489 2,130
1,863 1,863 529 20392
2,500 kW -I,o95,Da0 kWh 701857 1,471 6028 4,651 1,406 6,257 4,818 3,311 8,18 4, 64 1;nS6 6;8x0 7j243 9,349 1,835
(7,184 11,500 3►679 15,179 11034 3,657 1,058 41115
3,515 14j849 111470 8,278 19,74811,253 4,889 16,142 18,001 7,243 21116 9059
18,001 51789 23,290
a) Based on fuel adjustment applicable to January, 1975 bills.
b) Fuel cast darlyed based on actual fuel cost adjustment rate and rate formula,
c) Rate OS; Rate LGS has minimum billing 'demand of 100 We
d) Rate LP- I; Rate SC allows maxin,uri demand of 15 kW,
(e) Rate lP•I applicable to demands from IS to 350 kW; Rate LP-2 epplicable to demands over 300 kW
(f) Rate GS-L; Rate 05-S has maximum demand of 30 kW,
9 Fuel cost not determinable from rate formula,
h3 Rate LO-1; Rate LC-3 has minimum demand b1111ng demand of 5 kW,
JI) Indicated by source material to be based on cost of generation January, 1975, k
Rate LP-20
1
25
TABLE 7
DENTON, TEXAS
ELECTRIC UTILITY
TYPICAL BILL COMPARISON AT $0.82 PER MILLION BTU FUEL COST
- Denton. Texas Dallas, Texas
Existing Proposed Power S Power & Bryan, Greenville,
Rages ! $ Rates $ Li Liahc Texas Texas
Description
Reatdential, Summer
Posignation A-1 A-1(8) A-2 RS a5-1 R L-1
100 kWh 5,06 5.20 7.15 5.21 5.96 5.22 5.37
250 klih 9.46 9.76 11.28 10.21 11.20 10.53 10.47
500 kWh 15.59 16.16 18.15 17.21 18,37 17.12 18.36
750 kWh 21.72 25,03 24,22 25.54 23.72 25.69
1,000 kWh 27.84 - 31,90 31.22 32.71 30.31 33.00
1,500 kWh 40410 - 45,65 44.46 46,29 43.50 47,65
3,000 kWh 76,86 - 86.90 82.89 86001 83,07 86.32
50000 kWh 123.54 - 141.90 134.13 138.98 135.83 137.89
Residential, Winter
2 0 kWh kWh (same 5.20 L IS 5,21 5.96 5.22 (Same
9176 11,28 10,21 1140 10.53 as
5010 kWh summer 16x16 18,15 17.21 18,37 17,12 summer
750 kWh rate) 2244 24,93 23.38 24,72 23.41 rate)
1,000 kWh 28.93 31,33 29,16 30,71 28,45
1,500 kWh 41.73 44,13 40.72 42,71 38,54
3,000 kWh 80,13 92453 75,40 78.68 68.81
5,000 kWh 131.33 133,73 111.64 126.65` 109.17
Commercl.al
Designa:;ion B-1 B-1 CS GS-1 SC LC-3
25% load factor
kWh kW
100 - 1 4,52 5.47 5.82 6.48 6.12 6,44(d)
250 - 1 11.30 12,42 13,49 15,13 13,95 12.11(d)
500 - 3 22,61 24.00 24.25 26.82 26.99 27.96(d)
750 - 4 32.34 34400 35.03 37.49 38.80 37,73
11060 - 5 4246 44.00 45,82 48.69 45,67 45.40
1000 - 8 59,27 61,75 65.00 70,52 59,41 66,33
3,600 - 16 110.88 115,00 120,34 134.09 10245(e.) 326.81
5,000 - 27 174.30 19044 194,66 201.60 175.03(c) 101.88
100000 - 55 314485 377,50 37548 310,90 338.29(c) 381,90
(b)
26
ac'
A
TABLE 7 (Ccnt'd)
DENTON, TVUS
ELECTRIC UTILITY
TYPICAL BILL COMPARISON AT $0.82 PER MILLION BTU FUEL COST
Denton. Texas _ Dallas Texas
Existing Proposed Power & Power 6 Bryan, Greenville,
Rates Rates LIS- t Light Texas „ Texas Description
Large Commercial LP-1
Designation B-2 B-2 LGS(e) LP-20 6LP-2(f) LC-3
40% load Factor
kW kWh
25 71300 232 256 256 256 236 258
SO ,14,600 408 460 452 456 419 463
100 29,200 728 815 842 834 $04 856
250 730000 1,590 19797 1,863 10906 11794 2,033
S00 1469000 2,927 39,313 3010 30440 30255 30997
10000 2929000 5,438 60204 61191 6,350 60026 79924
2,500 7300000 12,918 149805 14,837 159081 141339 19,704
61% load Factor
kW, kWh
25 100950 296 329 326 338 298 340
50 21,9$0 524 591 591 597 562 608
100 430800 924 1,041 10120 11114 1,025 11146
250 109,500 2,079 29358 21393 20506 20348 2,759
S00 219,000 3,853 49396 4,245 49482 49275 5,449
1,000 438,000 70256 8,321 8,136 89436 89067 100828
2,500 1,0959000 11,463 200098 19,515 20,295 199442 26,692
(a) Maximum 700 kWh allowed under this rate during eummer months.
(b) Rate 8-2
(c) Rate LP-1 for demands over 15 W.
(d) Rate LP-1
(e) Rate GS for demands under 100 W.
(f) Rate LP-1 for demands under 300 kWi Rate LP-2 for demands 300 kW and over.
2,
1 „,„p wWr VP ~,.y Sa t y•W+ 4~, ,4 "nip" Y~~x b?N ~~Z'+n k "r7r , d f ,W
r. 4 rY.a \ 4 y+"~M s y rw , c. r v~y '}.f. ✓ .tu ~ 1r ~ F `ir - ~
37~ y,
1 y'0' r ✓kG ' r ~I i 11. I + t°~ t y r ~ f ~.Y Y 1'f: SmxVti`~,r
APPENDIX A
Froposed Rate Schedules II
F, 4 .j 1 AI 7
,
r fP k
F
~ W r ~ ' ~ gar 9 iK . '
f
i
1 w+
'IT
PROl`OSED
ELECTRIC RATE SCHEDULES
(a) tesidential Service Rate
Schedule A-1
(1) Net Monthly Rate:
Billing months of May through October
First 50 kWh @ $3.15
Next. 75 kWh @ 4.090 per kWh
Next 75 kWh @ 3.010 per kWh
Next 500 kWh @ 2.560 per kWh
1.111ing months of November through April
First 50 kWh @ $3.15
Next 75 kWh @ 4.090 per kWh
Next 75 kWh @ 3.010 per kWh
All additional kWh @ 2,560 per kWh
Energy used during each of the months of November through April
which is in excess of 700 kWh will be supplied at 1.650 per kWh
if the entire home is electrically heated - heat pump or
resistance.
(2) Minimum Charge: $3.15 prr month
(3) Availability:
Rate Schedule A-1 is applicable to all electric service required
for single family residential purposes where usage is not in excess
of 700 kWh par, month during the billing months of June, July,
August, or September. In any such month if usage exceeds 700 kWh,
billing will be rendered that month under Rate Schedule A-Z and
thereafter for, a period extending through the 12 billing months of
the next fiscal year ending September 30.
In instances where multiple dwelling ur;its (family or housekeeping
units) are being served through the same meter as of the effective
date of this rate schedule and the kWh in the billing months of
June, July, August, or September does not exceed a total of 700
kWh times the number of dwelling units so served (and has not
exceeded such total during the next preceding billing months of
June, July, August, or September), the number of kWh in each block
of the rate and the minimum charge will be multiplied by the number
of family or housekeeping units. In any such month if the total kWh
exceeds 700 kWh times the number of dwelling unite, the billing for
that month and thereafter will be rendered under Rate Schedule A•-2.
A-1
. j.:. .`7. ';;Y ,I ft 1 r '1.-: ~:.2 xru x~," a ya .}:.Y 4 t~~.,,r, , i; 'i
(4) Service.,
Single pease service at utilization voltage will be supplied here-
under. In the event three phase service is required by the user
and is available at the premises to be served, a charge of $100.00
will be made for such installation.
(5) Payment:
Billing for service hereunder will be at the net monthly rate,
payment of which is due when bills are issued. Bills which are
not paid within 10 calendar days from the date of Issuance there-
of will be considered overdue.
Service to users having overdue bills may, at the discretion of
the Utility, be discontinued without notice, and a charge of 10
per cent of the billing sht.ll be paid by the user in addition to
the net monthly amount. There shall be a charge of $4.00 for
reconnecting such discontinued service.
(6) Fuel Adjustment:
All charges of the Net Monthly Rate will be increased or decra.ased
0.0122e per kWh for each whole 0.01: per kWh by which the average
coat of fuel used in the Utility's electric generating plants* plus
the cost of purchased energy during the calendar month next pre-
ceding the billing month is above or below 1.UOe per kWh. Such
average cost is determined based on the sum of net kWh generated
in the Utility's plants* and the kWh purchased during each said
month. The cost of purchased energy does not include demand
charges for purchased power or rental charges for facilities.
*The determination of cost of fuel and net kWh asneration will exdlude
the 'cost of specific fuel purchased for and the related kWh generation
supplied for off-system contractual sales.
(b) Residential Service Rate
Schedule A-2
(1) Net Monthly.Rates
Billing months of May through October
Fixed cost of $4.tO plus
All kWh @ 2.75c per kWh
Billing months of November through April
Fixed cost of $4.40 plus
First 700 kWh @ 2.75e per kWh
All additional kWh @ 2.560 per kWh
A-2
x ,y e 9"7 SL+:T' ._tT
Energy used during each of the months of November through April
which is in excess of 700 kWh will be supplied at 1.85,C per kWh
if the entire home is electrically heated - hert pump or
resistance.
(2) Minimum Charge: $4.40 per month plus the charge for energy used.
(3) Availability:
Applicable for single family residential use. Where multiple
dwelling units are served through the same meter, the fixed
coat and the number of kWh in each block of the rate will be
multiplied by the number of family or housekeeping units.
(4) Services
(Same as Rate Schedule A-1)
(5) Payment
(Same as Rate Sc%edule A-1)
(6) Fuel Ad ustment:
(Same as Rate Schedule A-1)
I
A-3
1 i. .,6, T .r 1J } ♦ ~4rvi~'.r ' nsi~~ ~4?"dfY;'
. r
.fir. . y r r .+r ~ 'f
K Y .i 11 r.. 5.,.
(c) Commercial and Industrial Lighting and Power Service Rate
(O-Approximately 20 kW Demand)
Schedule B-1
(1) Net Monthly Rate:
First 50 kWh @ $3.15
Next 450 kWh* @ 4.63C per kWh
Next 500 kWh @ 4.000 per kWh
Next 2,000 kWh @ 3.55c per kWh
Next 2,000 kWh @ 3.28C per kWh
All additional kWh @ 2.920 per kWh
* For each kW of Demand in excess of 20, add 100 kWh to the 4.630
block.
(2) Minimum Charge:
53.15 per >ronth plus $1.70 for each kW of Demand in excess of
10 kW based on the highest Demand established during any month of
the preceding 11 months.
(3) AvailableI
AvaiiA le to commercial Lnd industrial users having a power require-
ment 1A approximately 20 kW or lees, except that service hereunder
is nci available for resale, breakdown or standby power.
(4) Demands
The kW load metered during the 15-minute period of maximum use
during the current monthly billing period.
(5) Services
At the utility's available secondary voltage and phase.
(6) Payment:
(Same as the payment conditions under Rate Schedule A-1.)
(7) Fuel Adjustment:
(Same as the fuel adjustment under Rate Schedule A-1.)
A-4
`$K~yT wT "Wtni .r .hr YV ^ti13S,. vS~ ry,c ~:i y~. yq.N{{ 'lk i.'yyr T'cq .~J T^', } al. t' ti i L~ •
I
(d) Commercial and Industrial Lightiag and Power Service Rate
For Medium and Large :sage)
Schedule B-2
(1) Net Monthly Rate:
Demand Charges
$40.00 per month for the first 20 kW of billing demand
$ 1.50 per month per kW for the 80 kW of billing demand
$ 1.30 per month per kW for all over 100 kW of billing demand
Energy Charges
2.851 per kWh for the first 300 hours use per month of the billing
demand, but not more than 10,000 kWh
1.95E per kWh for the next 180 hours use per month of the billing
demand, but not more then 60,000 kWh
1,550 per kWh for the next 200 hours use per month of the billing
demand
1,450 per kWh for all additional kWh per month
(2) Billing Demands
Equal to the kW load metered during the 15-minute period of
maximum use during the current monthly billing period. The billing
demand for service hereunder shall not be less than 20 kW.
(3) Minimum Charges
An amount equal to the demand charge as calculated above but not
less than 50 per cent of the maximum monthly demand charge for any
month during the preceding 11 months.
(4) Availability:
Available to coae,ercial and industrial users having a connected
load of approximately 20 kW or greater, except that service here-
under is not available for resale, breakdown or standby power,
(5) Commercial Residential Uses
Multiple apartments containing a minimum of five units may be
served under this rate. If in such service all apartments are
electrically heated - heat pump or resistance - the power and
energy used during each of the months of November through April
will be supplied at the following modified rates
A-5
,Y~ a1 ^'u ~1~~ ~ 1~ y ;F!'n }~'r Ye ru i t 1< P. .u v r "k
9. L `4 14r
For the Demand Charge only, the Billing Demand will be
adjusted by multiplying the 15 minute metered rate of
maximum usage during the month by fifty per cent (502).
The adjusted Billing Demand so determined will not be
less than 20 M
(6) Service:
At the Utility's available secondary voltage and phase. In the
event the Utility elects to meter the User'o service at the high
voltage windings of service transformers, the User will be allowed
a two per cent (2%) reduction from the net billing.
(7) Payments
Same as the payment conditions under rate Schedule A-1.
(8) Fuel Adjustments
Same as the fuel adjustment under rate Schedule A-1..
1A,
(9) Power „Factor Requirements and Adjustments
The Oh lity reserves the right to make tests to determine the
power factor of the User's installation served hereunder during
periods of maximum demand or by measurement of the average
power factor for the monthly billing period. Should the power
factor so determined be below 90 per cent, the demand for
billing purposes will be determined by multiplying the unconnected
kW Billing Demand by 90 per cent and dividing by the determined
power factor.
(10) Alternate Primary Service and Discount (Transformation Equipment
Owned by the User)t
Primary service will, upon request, be made available to users with
a 12 month average monthly demand of 750 kW or greater. Primary
service will be rendereli at one point on the user's premises at a
nominal voltage of 13,200 volts or 69,000 volts three-phase, at the
option of the Utility.
When the alternate primary service is supplied, the user shall own,
operate and maintain all :'ac.Mties necessary to receive primary
service and all transformation facilities required for conversion
to utilization voltage. The Utility shall own, operate and
maintain all metering facilities (either primary or secondary
metering at the Utility's option).
A-6
,ice
T-P
og
Where the user owns operates anel matettonapply its transformation
equipment and where the Utility TI,
re fteenrpetfceennttt(15%)
facilities the on the
ueehr $ili beaallowed affi
p Charge.
reduction from the monthly Demand
r owns, operates and maintains the transformation
Were the use
equipment and where the Utility elects ~o apply its metering
facilities on the low voltage side of such transformation
equipment, the user will bepemandeChargesr!hendifference(13x)
reduction from the monthly et sent being the allowance for
between 15 per cent and 13 p -
losses in the user's facilities,
1
A-7
713 T
(e) Dusk-to-Dawn lighting
(1) Net Monthly Rates
115 watt Mercury Vapor Lamp $4.35
250 watt Mercury Vapor Lamp* @ $5.35
400 watt Mercury Vapor Lamp @ $7.00
* No ne» or additional 250 watt lamps will be
installed after the effective date of this
schedule.
Where necessary for proper illumination or where existing
poles are inadequate the city will install or cause to be
installed one (1) pole for each installed light, at a
distance not to exceed eighty (80) feet from said existing
lines, at no charge to the customer. Each additional pole
span shall not exceed a span spacing of one hundred (100)
feet. Additional poles required tc install a light in a
customer's specifically desired location, and not having
a light installed on same, shall bear a cost of one Hundred
Sixty-Five Dollars ($16;.00) payable by the customer prior
to installation.
(2) Available:
To any customer within the area served by the City's Electric
Distribution System for outdoor area lighting when such lighting
facilities are operated as an extension of the City's Distribution
System.
(3) Service:
The City shall furnish, install, maintain and deliver electric
service to automatically controlled, mercury vapor lighting
fixtures conforming to the Utility's standards and subject to
its publie!-,ed rules and regulations.
(4) Payment:
(Same payment conditions as under Rate Schedule A-1)
A-8
e 1~ .'4' 4 M
a ..rd t. ~i:w \ "'.1 'a~ fi F`yr` r ,.'~}HAY. rr
(5) Term of Contract:
A two 12) year contract shall be agreed to and signed by each
customer desiring Dusk-to-Dawn Lighting Service authorizing
fixed c►onthly charges to be applied to the monthly municipal
utilities bill. In thi event that a customer desires the
removal of the unit or discontinuance of the service prior to
completion of two years, the remainder of the contract shall
become due and payable. After the completion of two years,
service shall continue on a month to month basis and may be
cancelled by either party upon 30 days notice.
A-9
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h s n b ~ i ,.55vy r i s ,uhf e 4` Y
I
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APPMIX B
ti+"* Preaer4t_itate Schedul®o
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1. 1. q r!° i c - _'~'7si" 9 ~ 3y w .r_ fi .
AN ORDINANCE AMFNDING THE CODE OF ORDrNANCES OF Tilp CITY
OF DENTON# TMSs PROVIDING NLV MONTRLY RATES
IITIL171Y SERVICE: PROVIDIN¢ A PENA1,Ty OR FOR ELECTRIC
PROVIDING CERTAIN OTHER REGULATIONS AND OVERDUE PAYMENT;
TA
POLICY. REPEALING CONFLICTING ORDINANCES PROVID OF
SAVINGS CLAUSE! AND DECiA RING AN EFFECTIVE DATE.
TH9 COUNCIL OF 7HE CITY OF DENTON HEREbY ORDAINS
SECTION I
That the Code of Ordinances of the City of Dentons Texas,
to hereby amended and supplanted by substituting new subsections
(a)s (b) and (c) of Article 17.09 in Chapter Seventeen of said
Code of Ordinances which shall hereafter read as followal
A_ RTI~LE 17 09 - ELECTRI I+ATE
(a) den a arvi_~e Ito
(1) et H nthl___-y Raton
First 50 kwhr. 0 5.400
per
next 75 kwhr 0 3.2.40 kwhr
Next 75 kwhr 0 2.150 per kwhr
p
Next 3500 kwhr 0 1 710 kwhr
per
All over 3700 kwhr 0 1.530 kwhr
per kwhr
Energy used during each of the months of November
througl,,April which is in excess of'700 kwhr will
be supplied at'0.90 per kwhr if the entire home
is electrically heated - heat
pump or resistance.
(2) s~inirnumgo, $1.00
(3) Ava`ilabilityf
Applicable for single family residential use.
Where multiple dwelling units are served through
r the came mater
s the number of kwhr in each block
of the rate and the minimum charge will be
multiplied by the number of family or house-
keeping units.
(4) S_..._._v_._ r
Single phase service at utilization voltage will
be supplied hereunder. In the event three
service is required by the users a charge phase
$100000 will be made for such installation.
f -
~ / d ~1 Y fy ♦y.
(5) Pa men ~ ;
Billing for service hereunder will be at tho not
monthly rate, payment of which Is clue when bills
are issued. Bills which are not paid within 10
calendar days from the date oi( irnsuance thereof
will be considered overdue.
Service to users having overdue bills may, at the
discretion of the Utility, be discontinued withaut
notice, and a Charge of 10 per cent of the billing
shall be paid by the uhcr in addition to the net
monthly amount. There shall be a charge of $3.00
for reconnecting such discontinued service.
(6) Fool Adjustment:
An amount of 0.00134 per kwhr will be added for
each 0.10 by which the average cost of fuel used
in the Utility's electric generating stations
{ during the preceding calendar month e ? ede 25¢
per million Stu.
(b) Commercial and industrial Liahtina and Paver Service a o
(0-Approximately 20 kw Demand)
S Nadu a B_1
(1) Nat_Monthlk Rate:
Pirot 500 kwhr 0 3.784 per kwhr
Next 50r kwhr ® 3.154 per kwhr
Next 2,000 kwhr- ® 2.700 per kwhr
Next 2,000 kwhr
Next 5,000 kwhr ® 2.434 per kwhr
All over 10,0'00 kwhr 0 2.074 per kwhr
® 1.604 per kwhr
(2) Minimum charge: $1.00 per kw of connected load
(3) Availability:
Available to commercial and industrial users raving
a power regviroment of app.,:oximately 20 kw or leas,
except that service hereunder is not available
for resale, breakdown or standby power.
i
(4) commercial Reri.dentfal Use:
Multiple apartments containing a minfrcum of five
(5) units may be served under this rate. if in
such service all apartments are electrically
heated - heat pump or resistance - the energy
used during each of the months of November through
April which is in exceos of 250 Ywhr multiplied by
the number of apartment units will be supplied at
0.94 per kwhr.
(5) Service:
At the Ut'lity's available secondary voltage and
phase.
(6) Demand Limita tion_gr
If the User's measured demand is in excess of
20 kw for two (2) consecutive months or if the
monthly consumptian of energy is in excess of
8,000 kwhr for two (2) consecutive months,
subsequent usage will be at the option of the
Utility be billed at the rates applicable under
rate Schedule 8-2.
(7) Pa of is
Same as the payment conditions under rata Schedule
(8) uol Ad a en
same as the fuel adjustmont under rate Schedulo
A•• 1.
(e) ' Co Oz eiaand industrial L+~htina and Powur Sorvlee Iuite
(For Modicum and Large Usage)
6chedula 8 j?
• {1) ~.~~~1v Rater
Demand Charges
$36.00 per month for the first 20 kw of billing
desrwind
$ 1.35 per month por kw'for the next 80 kw of
billing demand
$ 1.125 per month per kw for all over 100 k,, of
billing demand
Energy Charges
2.1154'per kwhr for the first 180 hours use per
month of the billing demand, but not more
than 50000 kwhr,
1.444 per kwhr fur the next 120 hours use per
month of the billing demand, but not more
than 5,000 kwhr.
0.994 per kwhr for the next 180 hours use per
month of the billing demand, but not more
than 600000 kwhr.
0.634 per t:whr for the next 180 hours use per
month of the billing demand, .
0.5044 per kwhr for all additional kwhr per month.
• 8111ina nernande
Equal to the kw load metered during the l5-minute
poriod of maximum use during the current monthly
billing period. The billing demand for service
hereunder shall not be less than 20 kw.
,
t+
ffs i-
(3) Mir}jm= Cb9JLq s
An amount equal to the demand charge ar calculated
above but not less than 50% of the maximum monthly
demand change for any month during the preceding 11
months.
(4) Availbl! Uitys
i
Available to commercial ►nd industrial users
having r connected loa.l of approximately 20 kw
or greater, except that sor%r;;ce hereunder is not
available for rovale, breakdown or standby power.
(5) Commercial Residential Usoi
Multiple apartments containing a minimum of five
units may be served under this rate. if in such
service all apartments are electrically heated -
heat pump or resistance - the power and energy
used during each of the months of November through
April will be supplies] at the following modified
rates
Demand Charge - the billing demand will be
adjusted by multiplying the 15-minuto metered
rate of maximum usage during the month by
the factor
350 kwhr x Aumbor o2 t+trtme1.t unite )
total measured kwhr
This adjusted billing-demand will then be
applied to the rate Schedule B-at provided,
howovor, that the adjusted billing demand
for service hereunder Aell not be lees than
15 kw.
Energy Charge - an amount of energy equal to
350 kwhr multiplied by the number of apartment
units will be supplied at the basic rate of
this Schedule n-2, using the adjusted billing
demand to determine the Energy usago under
the respective blocks of the rate. All addi-
tional energy will be supplied at 0.94 per kwhr.
if a lower monthly billing would result, the demand
and energy will be billed in accordance with Schedule
B-2 without adjuptmant.
(6) setvic s
At the Utility's available secondary voltage and
phase. in the event the Utility elects to motor
the Usor's service at the high voltage windings
of service transformers, the User will be allowed
a two per cont (290 reduction from the not billing.
(7) P_ a_y_ments
Same as the paynent conditions under rate Schedule
A-1.
(S) Fuol AdiustmentI
Same as the feel adjustment under rate schedule A-1.
(9) Power Factor Rec~uirtmgnte and Adiudtments
The Utility reserves the right to make tests to
determine the power factor of the User's installation
served hereunder. Should the average power factor
for the monthly billing period be boluw 9076 or above
95% lagging, the demand for billing purposes will
be determined by multiplying the uncorrected
billing demand by 92.5% and dividing by the average
• power factor so calculated.
(10) Alternate Primary 6eryi~ an a s
nation F,quinment Owned by ! e U
Primary service will, upon ,request, be made
available to users with a 17-month average monthly
demand of 750 kw or greater. Primary service will
r be rendered at one point on the user's premises
at a nominal voltage of 13,20) volts or 690000
•i volts threo-phase, at the option of the Utility.
When the alternate primary service is supplied,
the user shall own, operate and maintain all
transformation facilitiejs required for conversion
to utilization voltage. The Utility shall own,
operate and maintain all metering facilities (either
primary or secondary metering at the Utility's
option.)
Where the user owns, operates and maintains the
transformation equipment and where the Utility
elects to apply its metering faeilitlan on the
hl voltage sidn of such transfo,rrAtion equipment,
the user will be allowed a seven per cent (7%)
reduction from the monthly billing.
Where the user owns, operates and maintains the
transformation equipment and where the Utility
elects to apply its metering facilities on the
IV voltage aide of such transformation equipment,
the user will by allowed a five per cunt (5%)
reduction from the monthly b).llingt the difference
between seven per cent and five per cent being
the allowance for losses in the user's transfor-
nation equipment.
:w;r i ~t t y ',1 A q
E
BECT-- ION~II s
That all ordinances or parts of ordinances in force when the
provisions of this ordinance become offective
or in conflict with the terms or p which are inconsistent
rovisions
ordinanco are hereby repealed to the extent of anynsuchnconflict.
n
____-pLU ,
That any section, subsecti
phrase or word in this ordinance, nce, ON paragraph, sentence, clause,
or application thereof to any
porson or circumstances is held invalid by any court of competent
jurisdiction, such holding shall not affect tho validity of the
remaining portions of this ordinanco, and the city Council of the
City of Denton, Texas, hereby declares it would have enacted such
remaining portions despite any such invalidity.
s• ECTION IV
That this ordinance shall become effective fourteen (14)
days from the date of its passage, and th• city Secretary
is hereby directed to cause the caption Of this ordinance to be
published twits in the Denton REcord Chronfclo within ten (10)
Rays of the date of its passage.
PASRED AND APPROVED this Ile- day of
A.U. 1965.
~ t
i
rren i
Whit;3on, Jr., Mayor
rity of Denton, Texas
ATTEM
146ZGkF,-
Holt, City secretary
'
City of Denton, Texas
i APPROVED As TO LEGAL MRMt
JtY Q. Sartan, Cit ~y Attorney
of Denton, Texas
_ r.
t E
! r
1i
17
1
E 100 _ i i' 1 I- :1. 'TM
901 Proposed A-1 t-bv to Apr Rate
i.. Existing A-1 Rate
1 Fadsting A-1 All Electric Rats
proposed A-1 All Electric Rate
1
{ 1
70 E ~
1 t t
}
60
so
J CITY OF ref"
1
JUNE 1975 ftWosed Ar
FATE
1 m~irrAtt
4 40 may to oct. Rate M k COIPARISM
! Baas FU91 Oust
60
30 JWJ Cost Adjustment
I of $0.00741/*M a
E 1 E` on' bdsting Rates ,
1 _ L_ i 1 AveralIe 1974 Mmth1Y Coc'a
`10 L t I i
i { 1 1400 1800 2200 2600, 3000
- ,
200 600 1 1400 ;T ` 11 1
1i.
t
ILL'
1111 %I1111"Ittas U, the c'M lnetc3
1
*I ..lot)'
100.
prqpowd A-2 xw, - Apr. Fite _
' PLVPOBed A-2 May - Oct. Rate \
90 Existing A-1 Rate
Existing A-1 All Electric Rate
PtOpaeed A-2 All Electric Rate
70
I
AvU-ap 1974 !mthly C"uTption
i I L
40
am or DEm
JWE 1975
- { - R£4IDFNPIAL RATE
30 OCWARISON
r
- j ; - Base Fwa Coet of f . _
I. 62MOM
-1 ~ AN1 Wit Ad ust~nt of
- 1.. _ *00741/%V on _
flcfsting Rates ~
10
77
E0 200 1000 1400 1800 2200 2600 r !
_ ~ 300
t
IL 4
L Fr
1.
A
LL
'1111~q, n.. l.Il l. i~lt I~tlllltlf t.l
4PI -7
7 _ _ r
_7 7T"
280
9 t f- I ~I j~
j 1,260 r ~ I
240
f E 8 Rate
220
bating A Rate f
200
180 f.:
f { f I CITY OF DER"
1.7
f + JU+W; 1975 f
160-- LL
O b= RATE MARI9CN {Bl) I +
Saw nal I
140 CABt Of $82/M"~'iV
7-1
f t! f I 'Fuel Cost Adjustment Wsting Rates . `
y 120 • _ f 8 $0.00741/ GM
-1000 17,
l00 t; 11
00
14 60
40
20
000 5000, 6000 7000 8000 9000 10,000 I
k i ~ i + ~ ~ I { F64F1 f +
z 7 t 5,"' y+ v'a ~ 3o~a. ~ 3 G
5 r•~ _
- - { T I r_.
f
,
I I.
a JT 177
•
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` I 3
6000
i
5000, ` , p ea B-2 Rate
i , i - ~ r ~ i r 1 ~ I
4000
cny Of DM
Ii
y j . r { I,n= )MEM
I
40% UAD FWWR
3000
a V
~'-X2000' ~ ~ • ~ ' ~ ~ ' i i ~ I , ~
1000 I ' t •k ` - f ' I. i E_
r 800 10,000
KH (Demand) j 200 i i• ,I 4(0 I 600 i 233,600 292,000
68,400.._. L16 ,b00 ; 175,200
f
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