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" TABLE 9
<br /> 1PRYINGPAN ARKANSAS PROJECT
<br /> POKER SYSTEM AVERAGE RATE DETERMINATION STUDY Deosmber' 1953
<br /> Assumed amortization of Power investment in 50 years following development period, interest at 2
<br /> Accompanies reply t4 ,
<br /> letter of Nov. 10, 1953
<br /> from John P. Saylor, Moog
<br /> (1 (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (1.3) (i4) (16) (17) (18) x
<br /> Sales of electric energy Operating es Re�vs7� deductions : Net Income deduetims investment '1� rgy ing repayment tZ�ois gvr+rer raucous: Sear a
<br /> millions of Kilawatthoure 5. Sales of electric energy operating f ihv nt Plant in service st end of .year Earned � .
<br /> of Operation 'Provision - ° - e Interest bearing o!
<br /> Interest Allowable
<br /> Total Maintenance., Total re�nues mautiv S�tuttr
<br /> .9fi,#ldy �'12s Nacr-� , Ibta3. � ' Tir1s i�D�u-M.Ynt ��o i _for -
<br /> Cols.2 & 3 5.2 rills 3.5 mills 5 & 6 & Overhead Cols. 8 & 9 Electric Balance to Ca�nlatiw
<br /> / i' xtoeme Cols. 710 2 ;6 Principal dent be repaid balance
<br /> 0 i $20,8649000 $20 864,0M 0
<br /> 1 177.2 45.1 222.3 $ 921 440 $ 15T,850 $1 079,290 269 380 $ 134,080 403 460 $ 675 $30 . $ 521 600 $ 154 230 27i482 000 2 2 27,482,000 1 wry
<br /> --- -_ 3 4 -
<br /> 1- ].55,960 _ --21b 3 -- --1� - , _ ., , , ?, 7➢770_ 183 320- �41 590__ 830 670_ b8�,_194-� -_lh� 4?6-- -,33� s�': 3��291t --�-3i9�?s
<br /> 3 315.2 85.4 400 6 1 639 o40 298 900 1 937,94o 451,05a
<br /> 2 -- 222.3-- -- - 1.8-- _28 t , � p372,260 �_ ,270
<br /> ` "
<br /> 5 97.2 � �360? 1�765�400 340'2ao 2 105 600 53o�bla 224,700 b75,760 1,262,190 840,132 422,058 38,t�i7,000: 37,343,236 38,06?,000
<br /> 4 339. , s , , 2499720 780.9130 1,325,470 933,581 391,889 38,o67,000 369951,347 38,067,000 ;`.
<br /> 2 1.765.400 2oo 2.lo5.600 10 20.720 7800130 10325047081L L01,686- 38.o67.000. 382067,9000 5
<br /> 339.5 97.2 436#7 1,765, �00 34Ot2OO 2,1051,600 3o,4io 249,720� 780,130 1,325,470 913,742 Oily 728 380670000 36,137,933 3Uj,067vO00
<br /> .7 339.5 97.2 436.7 1,97659400 340,200 2,105,600 53oAlo 249,720, 780,130 1,325,470 9�03,448 4229622 38:0679,000 35,;715,9U 38,©67,000 7
<br /> 8 339.5 97.2 436.7 1,765,400 340 200 2 105 600 530,410 249 720 780 130 1 32S 470 892 898 432 572 38,0670000 35 283 339 8.067,OOc1 8
<br /> 9 33905 97.2 43697` r,765,400 340,200 2,105,600 530,410 249,720 780,130 1,325,4?'0 882,083 443,387 42,043,000 . 38,815,952 42,043,000 9
<br /> 10� 0.0 .2 7.2 1,924 000 200 2,264,200 M6 9Q 284 210 870,800 1 3 00 9 0 2 001 8 2 1 lO
<br /> 11 959,d24 3,576 37,959,375
<br /> 12 Notes: 948,984 444,41612
<br /> r 3 7,514,959
<br /> 13 U ols, 2-4. Sales were estimated from Market Area Data, 937,874 455,52b ` , " � 37,059 433 13
<br /> 14 2. Cols, age rates required to 5-7. The aver qu produce an annual revenue sufficient to pay all operation, maintenance, 926,486 46b,914 36,59 519 14 +
<br /> and overhead expenses; provide a fund for replacement aryl repay the investment in the electric plant 81 478.587 6 11" 2 15 �.
<br /> 16 with interest @2-1/2 percent. 902,8 6 49o,552 3 -623,384
<br /> 17 Firm Energy. 5.2 mills per kilowatthour 890,585 502,815 35,12Q,565 '17
<br /> Nonfirm Ene 878,014 515,386 34,605,179 18
<br /> Zg 3.5 mills per kilowatthour
<br /> 3. Col. 8. Operation, maintenance, and overhead were estimated as follows: 865,129 5289271 34,076,908 19
<br /> 1� Arkansas Peer Canal. . . . . . . . . . $1.09i030
<br /> Trai smis si on lines and substations. 62,280
<br /> 21 Pawerplants and penstocks 413,480 838,386 555,o14 32,980,417 21
<br /> 22 Allocation of joint facilities. 1.800 824,510 568,890 32,411,527 22
<br /> 23 . . . , 90 810 288
<br /> z4 Total. - ?95�710 83, 12 31,828,41 23
<br /> 5 1 5
<br /> 597,690 - 31 230 725 24_
<br /> 4:� Colo .9"_._____ __Requirements for provision for replacement fit 2-1/2 percent in 5J Years were estimated as follows: � � � -
<br /> Item of Property Amount 780.768 612.63230.618.0932
<br /> 2 F.P.C. Acct. Structures an improvements $ 765,452 627,948 29,990,145 2
<br /> 321 tore d imp ro era 1
<br /> 27 749,754 643,646 29,93469499 27
<br /> 322 Reservoirs, dams, waterways and penstocks 13,400
<br /> p 28 32}325 dater wheels 733,662 6599738 28,686,761 28
<br /> , generators & miscellaneous ace. 129,490 717,169 676 231 2800102530 29
<br /> t -fir 343 Switchyards and substations 60 040 ' .
<br /> O Y sa
<br /> 371 General plant 3,770 7000263 693 137 27.31? 393 3b
<br /> T_ ( 31 345--346 Transmission lines 8,950 2,935 710, 65 26,6069928 31
<br /> 32 Allocation of point facilities 640 b65,173 728,227 25,878,702 32
<br /> 7461,432 25,1329269 33 <
<br /> r �
<br /> 33 � Col The to estimated� electric � 62810 �30T b �� 2 .�r �,�..�.. . . , .� .. :�, .� 34
<br /> 34 5 . 14 a total s ima.ted Z ctric plant investment is determined as follows: , _7 5,093 4,367,176
<br /> 35 Investments Amounts 609,179 84 22I 23 $2 .. x 35
<br /> „�. ,.
<br /> f
<br /> Hunter Creek-Aspen Canal. . . . . . . . . . . . . . $ ;�0 589,574 803,826 22,779,12936
<br /> P Aspen . . . . . . . . . . . 8,325,000 %9,4.78 .823,922 21,955,207,.
<br /> 37 Replacement Reservoir - A en _ 3T8
<br /> 38 Fryingpan Collection System . . . . . . . . . . . . . 31,597,000 548,880 844,520 ' 21DZ10;6$7 _' 3
<br /> I-
<br /> 39 Fryingpan-Arkansas Tunnel . . . . . . . . 10,379,000 527,767 8b5,633 2b,245,054 9
<br /> j 3
<br /> j�Q Sugar Loaf Reservoir. . . 7,447,000 06 126 887 274 19.357.780 40
<br /> 1 Snowden Diversion Canal 7869000 3,9 909, 18,448,325
<br /> Twin Lakes Reservoir. . . . . . . . . . . . . . . 10,503,000 .:
<br /> 42 461 208 932 192 17 516 133 42
<br /> Arkansas Peer Canals: ' 0 ' - 16' 0'6 6 43
<br /> `
<br /> 1,729,000 414,016 979,384 15'�81'2 2 -
<br /> Elbert Canal. . . . . . . . . . . . . , 979,497 , ,
<br /> Twin Lakes-Otero Canal. 19595,o00 389,531 19003,869 z4,577,383 45
<br /> b p 2,1512000
<br /> Otero-`�la aco Canal. .
<br /> Napaco-Princeton Canal. 2,693,000 364,435 1,028,965 13,548,418
<br /> 47 Princeton-Pancho Canal. . . . . . . . . . . . . 2,085,E 338,710 1,054,690 129493,728 47 ;`
<br /> 48 pancho-Salida Canal . 2:4650000 312,343 1,081,057 1 ,4 ,671 48
<br /> Sdida Afterbay. 318,000 285,317 i,IO8,083 1Q,39,588 49
<br /> 0
<br /> Pueblo Reservoir. . . . . . . . 44 648 000
<br /> s � 50
<br /> 1 Powerplants and penstocks . . . . . . . . . . . . . . . 19,786,000 229,220 1,164,180 $,004,b23 . 2191799000 1
<br /> 52 Transmission system . . . . . . .. 7,312,000 200,116 1,1931284 6,811,339 14,561,000 52
<br /> 53 Municipal water facilities. . . . . . . . . . . . . 22,124,Oo0 170,283 1,223,117 E#5861222 8,,136,000 53
<br /> General property. . . , . . . . . . . . . . . . . . . . . . 1 204 000 139,706, 1,253,694 ,334,528 3,976,000 54
<br /> Total. o . l 7 32 000
<br /> 7 8 6 10 I, 28 0 i 33 b
<br /> 5 3 7 04 4 1 000
<br /> 56 Investment fully reimbursable from po,,'er revenues 42,043,000 76,237 1,317,163 1',732,328 3V976y0O0 56
<br /> 43,308 1,350,092 302. 3,9762000 -0- 57
<br /> 59 9,556 382,236 -0- 3,9769000 10001,608 58 ,
<br /> 370.0 97.2 1►6702' 924 006 340 200 2,264 200 586 590 2v4 210 870 800 L2-S3 400 -0-- -0- 429043,000 4 -0- f` 3.976.000 1 393 400 . 59
<br /> lk,251-7 5,63505 2b 887o2 $110,508;,840;, >:724,250 �6130,233,090 $33,590,660 a16- 250;920 49,841,580 l80,391,510 $35,953,502 42,043,000 S42,043,000 -=o- -0- $2,395,008
<br /> ANALYSIS OF 59-YEAR RATE DETERMINATION STUDY �_ :__� __ _ ELECTRICAL GENERATION AND SALES AFT%R DEVE Miff PERIOD j
<br /> Average Production Costs a Average Annual Generation millions, Average Annual Saleable Energy
<br /> Annual Saleable energy Firm energy Secondary or Non-Firm Power Plant of Kilowatthours millions of Kilowatthours
<br /> energyTotal Firm Secondary;:or Total Firm Secondary or J
<br /> 71
<br /> Components of Production (4552700,coo, xRH (360 200,000 K" 95 o0 000 K H Non-Firm Non-Firm
<br /> Costs Tots annual Annual Annual Elbert 3900 26-3 1207' 36.1 24a3 11.8 i ` F
<br /> costs Per KWH cost Per Kit coat Per KWH Granites 660$ 48.8 1800 blob 45.1 16.7
<br /> Operating Costs Wapaco 125.9 100.4 25.5' 116.5 92.9 23.6
<br /> Col. 8 Operation & Maintenance $ 569,333 $ .00125 Princeton 68.5 5502 13�3 63�4 5101 1203
<br /> Col. 9 Provision for Replace. 275,439 ,0006o Johnson 69.4 55.0 14.h 64.2 50.9 13.3
<br /> Salida 102.4 81.3 21.1' 94.7 75.2 19.5
<br /> Fixed Costs - '
<br /> Col. 13 Payment to Principal 712,593, .00156 Pueblo 33a0 3300 OoQ 3005 3405 Oa0
<br /> Col. 12 Payment to Interest 6099381 .00134
<br /> Surplus
<br /> Total 5o5.0 400.0 105.0 4b7o2 370.0 97.2
<br /> P
<br /> Col. 17 Earned Surplus 40 593 .00009
<br /> Total $21207,339 S .00484 $1,873,o31 .0052 $334,309 S .0035
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