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<br /> TABLE 8
<br /> FRYINGPAN-ARKANSAS PROJECT
<br /> POWER SYSTEM AVERAGE RATE DETERMINATION STUDY December 1953
<br /> Assumed amortization of Power investment in 50 years following development period, interest at 3% Accompanies reply t0
<br /> letter of Nov. 109 1953
<br /> from John P. Saylor, Moot
<br /> (1 (2) (3) =(4) (5) (6) (7) (8) (9) (10) (11)' (12) (13) (3.4) (3,5) (16) (17) (1$)
<br /> Year Sales of electric energy Operating Revenues Revenue deductions Net Income deductions Investment repayment from pwor revenues Year
<br /> millions of Kilcwatthours Sales of electric energy . o o a e Plant in service at and of year gee
<br /> operating of Operation Provision Interest bearing Allowable Surplus of
<br /> Stud Total Firms Ikon-Firm Total Maintenance Total revenues -Interest Study
<br /> Y Ti.�t �� � for Cole. 8 do 9 Electric Balance to unpaid Cmm�l.atiw
<br /> �ols.2 k 3 5,5 mills 3.5 mills Cola. 5 Ec 6 & Overhead replaee'see2st Cols. 7-10 3x Principal plant be aid bal.�e
<br /> O $20,8h4,000 $'L0,864,00® $20,$64,000 0 F
<br /> i 177.2 45.1_ 222.3- - 974,600 157,9850- - _ 1 132 450 _.._-__269,360 -- ,_120,$00 -390,180 - 742,270 _ 625Q920 _ $_ -_116,350 27,1;$2,000t� 27 365 650- -_�,1t82,A0U - - - - "1-
<br /> - -
<br /> 2 222.3 61.8 284.1 1,222,656 216,300 Y k38,950 358,27o 165,160 523,430 915,520 820,970 .� 94,550 33,907,000 33;696,100 A3907#000 23 315.2 85.4 400.6 1,733,600 2980900 2,032,500 451,050 202,440 653,490 1,379,010 1,010,883 368,127 38,Ob7,000 37, 87,973 067,000 3
<br /> 4 339.5 97.2 436.7 1,867,256- 340,200 2,207,450 53o,410 224,980 7550390 1,452,066 .1,124,639 327:427 38,067,o00 37,1bo,546 38,067,E
<br /> 5 339.5 ,2 1.867.256 !;0 200 2 20 4 0 224 80 755 90 16452.066 T M.816 337 250 06 000 3s 067 000 5
<br /> 339. 97.2 3 .7 1,8 7,2 3 0,200 2,207,450 30, l0 22 ,980 7 ,390 1, 2, 19104,9699 3 79367 38, 7,000 ' 369475,929 , s
<br /> 7 339.e 97.2 436.7 198679256 34o,2oo 2,207,450 530,410 224,980 755,390 1,452,066 lo094.9278 357,9788 38,067,000 36,118.9Ial 38:o67,000 7 'I
<br /> 8_ 339.5 97.2 436.7 ,1,867,256 340,200 2,207,450 530,410 2241980 755,390 1:452,066 1,083,544 3689522 38 O67.OM 35,1492619 38,067.000 $
<br /> 9 339.5 97.2 436.7 198672256 3409200 2,207,450 530,410 2240980 755,390 1,452,066 1,a72,489 379,577 4z,043,00d 39,346,042 42,043,000 9
<br /> 3:iE3 0.0 7.2 467j2 2 035 000 0 200 2,375,200 86 90 ? 570 842 160 1,533 040 '�3 180 1 352 659 10
<br /> 11 Notes: 1 1 9, of 3630239 3896301,144
<br /> 12
<br /> 12' . Zols. 2-4. Sales were estimated from Market Area Data 1,158,904 3741136 3�,256,008
<br /> 13 2. Cols. -7. The aver 11:L47,680 385,360 $ t
<br /> _ 5 age rates required to produce an annual revenue sufficient to pay, all',operation, maintenance and overhead 6 21 37, 70 648 � .
<br /> 1.4 expenses; provide ,a fund for replacement; repay the investment in the electric plant with interest ® 3 percent 1,1360119 396992 371473972?
<br /> 15 1,124,212 408,828 15..
<br /> •, .rt:, are shown below: a '
<br /> 1 l9lll,9 7 21,093 36 643 806
<br /> Firm Energy . 5.5 Mills per kilowatthour 19099014 433,?26 17
<br /> �7 Non FirmEnergy 3.5 Mills per kilowatthour36,210,O8o
<br /> ' 3. Col. 8. Operation, maintenance and overhead were estimated as follows: 1,0860302 446,738 63 342, 18
<br /> 19` Arkansas Power Canal . . $109 030 1,072,900 460,140 �35,303,202 19-
<br /> Tr t i �#,on Lines and Substations 62.2 0
<br /> $0, 1 o 6
<br /> 413,480 ...; t; l,o ,g78 88, , 1�1,0 6 21
<br /> Power Plants and Penstocks . . . . . . 2
<br /> P32
<br /> 33 99
<br /> _ _ _. - -w__ - 1,030,233 502,807 838,289 22
<br /> Allocation of- Joint Facilities- . . s . ;. 1 800 E - �
<br /> 23 � 190159149 517,891 33,3209398 23
<br /> 24N. 4. Col. 9• Re uirements for rdvision for re lacement were estimated as follows: 999,612 533,428 32,7860970 24
<br /> q p p 983 609 549 431 32 237,539 2
<br /> 2 P'oP.C.;;Adct. No. Item of .Froperty r. , Tn13ae3 g ,914 s625 2
<br /> 27., 321 Structures and Improvements .a. .ck . i4,880 $�,149 582.9891 31,088,734 27
<br /> 28 322 Reservoirs, Dams,, Waterways, nd•Pensto s 1, 70 93a,662 b00,378seb8'356 26
<br /> 323-325 Water Wheels, Generators, and Wise. Ace.. 82,300
<br /> 29 914,651 618,389 29, 9,967 29
<br /> �v.
<br /> r 0 343: Switchyards and Substations . . . . . . . . . .. 91,36o 896,o99 636,941 29,233,026 3p
<br /> ;•, 3?1 General Plant 3,110
<br /> 32 31
<br /> 345-346 Transmission Lines 52,150 246
<br /> 85T,309 675,731 27,901, 32
<br /> 4 57
<br /> 33 837,037 696,003 27,205,243 r .�
<br /> 34 5. Colo 14. The total estimated electric plant investment is determined as follows: 816,15? 716,883 26,488,360 � '
<br /> Investments Total 794,9651 738,389 25,749,97i _ .f . 35 ,
<br /> a Hunter,;reek-Aspen Canal . . . . . . . . . . . . . . . . . . . 5p
<br /> 37 36
<br /> 36 Replacement Reservoir Aspen. • . 8,32 ,000 , 83 ,35? 24,206�b7 •
<br /> . o 5
<br /> Collection System. . . . . . . . . . . . 31,5979000 749.o6 783
<br /> 3 37
<br /> 726,182 o6858 23,399,215 38
<br /> 'P inSpan-Arkansas Tunnel. . . . . . . . . . . . . . . 10 379>000
<br /> .39 701
<br /> I
<br /> 701,976 831,064 22,5689351 39
<br /> Sugar Loaf Reservoir . . . . . . 7 447 000 67704 ' 855,995 1712,15640
<br /> 40
<br /> 1 Snowden Diversion Canal. . 786,000
<br /> Twin hakes Reservoir . . . . . . . . . . . . . . . . . . . . 10 503 000tin '
<br /> `42 Arkansas Power Canals ' ': 6249914 9080126 19,922,355 !�2
<br /> 1 43 59T,671 935,369 l&9986,986 43
<br /> Elbert Canal . . 1,7290000 56q,b10 g63,430 18,D23,55644
<br /> Twin hakes-Otero Canal 1,595,0o0
<br /> Otero-Wapaco Canal . . . . . . . . . . . . . . . . e 2,151,000 S�tO,70? 992,333 17Ic
<br /> ,031�223 1�
<br /> ,
<br /> Wapaco Princeton Canal • 2,085,000
<br /> 47 vo 480,274 l,0 52,766 1lty 956,354 47' .
<br /> Princeton-Pancho Canal
<br /> ,_ 44.8 691 1,9084049 13,872,005 48
<br /> -Salida usual• '318,000 �416,160 1,116..88o 12:755,125 4
<br /> 0 Salida 'Afterba . ;382 654 1 150 386 11,604,'�39 42 043 OOO ^ 5o 1,
<br /> Pueblo Reservoir . 44,648,0oo
<br /> 52 Powerplants and Penstocks. 19,786,000 1 2 1 1 9 1
<br /> 348, , , , , ,
<br /> 53 Transmission System. 7,312,000 312:595 I,220,445 911999396 14,561,000 52
<br /> 275.9982 1,2579058 7,942,338 8,136,000 53
<br /> General,Property 1,204,000 2389270 1,294,770 6,6479568 3,976,000` 54
<br /> 22 124,000 199 427 1333 613 5,313,955 976 Goo
<br /> 54 Municipal Water Facilities ,
<br /> Investment fully rei:mbursa 56
<br /> ke from power revenues $42,643,600 1 9, 19 1,373, 21 3,9 0,33 3,97 ,000
<br /> 57 118,210 19414,830 2,525,504 3,976,000 . 57
<br /> 58 75,765 1,457,275 1,o68,229 3,976,000 -0- 58
<br /> aco 200 200 57©. 84 10 13040 4
<br /> 3s976000 43276497.2 32047 1068229 59 370.0 59
<br /> Total _T
<br /> 21,251.7 5,635.5 26,887,2116 884 386 $19,724 250 $136 608 b36 $33n590,660 $11a,616n78o48 2oT 440 . 68 401 196 $45,925,43a42 a43,o0042 043,000 ' -o- -o- 432,764 Total
<br /> ANALYSIS OF 59-YEAR RATE DETERMINATION STUDY
<br /> ELECTRICAL GENERATION AND SALES AFTER DEVELOPMENT PERIOD
<br /> Average Annual Generation millions Average Annual Saleable Energy
<br /> A, Ave raze Production costs millions of Kilowatthours
<br /> j ,Annual Saleable energy Finn energy Secondary or on- r>A Power Plant Total Firm econ ry o Total Firm Secon wry or .E
<br /> 1 455 T� 000 KVIEI (360,200 000 K'MH) (95,50�, KNH Non-Firm Non-Firm
<br /> Components of Production
<br /> Coats Total annual per K11H cost per R11H Annualper Kilfi Elbert 3900 26.3 12 o7 36.1 24.3 11.8 k:!
<br /> costs cost Granite 66.8 48.8 18.0 61.8 45.1 16.7
<br /> Operating Costs ' Wapaco 125.9• loo04 25.5 116.5 92.9 23.6
<br /> Colo 8 Operation & Maintenance S 569033 $� .00125 Princeton 6805 5502 1303 63.4 51.1 12.3
<br /> Col. 9 Provision for Replace. 247,742 .00054 Johnson 69.4 5500 14•4 64.2 50.9 1303
<br /> Fixed Costa Salida 102.4 81.3 2101 9407 75.2 19.5
<br /> Col. 13 Payment to Principal 712,593 -00156 Pueblo 3300 33.0 0.0 30.5 30.5 0.0 '
<br /> Col. 12 Payment to Interest 7789397 .00171
<br /> Surplus Total 505.0 400.0 105.0 467.2 370.0 97.2
<br /> . Col. 17 Earned Surplus 7,335 1 .00002
<br /> � . Total $2,315,400 $ .00508 $1,981,091 $ .0055 $ 334009 $ .0035 r' ' ,
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