{It CBMPARISON OF THE INVESTMENT AND IJIFERIIITIIIG COSTS FOR WATER ’ PRODUCTION BY AIR LIFT PUMPING . AND BY DEEP WELL TURBINE PUMPING THESIS FOR THE DEGREE 0F c. E; MarshaII Edwin Snider * 1933 , MN." '1", i‘fi‘ “ (IL-339; 6}. I w -' .'. 3 yet". .3, . " ' . :. "3." 1% $3,; .‘ {3‘ . 93' . . :"2é: CI". 'vwsc ‘ " . " '.v"~./n?.1’»'. 9.99. "345(- ~ . ~ ' .-....--5J" 9'- E§Tfl ‘ - g ' - - '3v ’ ' ' ”kw-.33; '91 _ . ’ I s 45‘ g , 0 'a :1 (if '5 ‘ :5 ".5 v. ,‘ ‘ ’ .. ‘ 2-. . _ . -.->'-" - . ' . 71;». 3 v, v d»- 9. v'; x .‘1 .. 5'6 ‘w-u‘wt, NI: ‘|;‘F I. $557 ‘ ._q, , . I .rxcr‘ ..,__,g 4 - ”It ‘0‘. _ W -|‘! ‘ . k.“ o"! -‘n“"’- ‘1.%7‘(1}F;1" .L - ".144 ,3;th , ‘. n I - ~ Lg. .. 4 9' . 'u' . ’. . g}... I . :3- . «3‘. i | ~' ,- swirl”; “I 49;: 9 m3} . )4) —_-.A v 5’4‘ 9 . . . . ‘ 7. (1)1!) 3 .11.-. M ‘ 9%?“92? "If." v: - ';_. It“. ”'_-'. .pz‘l. ~»_". .‘. {H {3"|-.L’-\h ' "- ‘9'. .I. u’ «9"§x§§‘;rIéi' guy-{:9 I “L I 3% 735.3; -' “3339331: ‘ I . .A u , 3 "C'- . .V I n ’ ,' I I ‘ J 3“,” 3". “ ' -a".'3§'~'1-‘Ri 1.95 ""3491 .-‘. ’9')” £93733“; “ ' ‘3 “avg; ; \ QITK-fin ' ‘ ‘33. «1994392? - ’ .1 y :4 "n. ¢;*Ib- n?- . ‘3‘. .. . 3 - gr*! “ fig".. @_ . .. ‘ l‘ - " .V ' ' s ,' w ' 'fi £ 9’ L 73'2' i 'f§."fi3?f AA": ‘6'. .I "‘4. '99?”%%(3 . 3&3”, My, '. .. 0‘}. ‘u’ .) ’$ [‘1 o 3-3" 2 _~ ' ¢‘ A i -r:." £| < & "> 3 J'lewgn .3) “cg-10.4: I, . 9'. .9 - a. 1, ~37 I NC .4 3 v 3.41;. 'H . s3” ' I' ‘1‘!’.'_' . . 93' 9 zit-'9“ ‘ 1 "‘LV ~. . \v‘ 4““ 2 4' "t 1. R Y I u ,n’ ;.l.[ w! .\' , 4.. ‘ . t z 1’! , 1.4:. 3:": I. ' :o -5 "_ , .v" t- (15'! Ii: '3‘ Ur“, 5’ 3" ' L v.‘ /""‘.'I'.:»”'.v~ ‘ .i- 3< )4 "I W} r?» ‘3'" L‘ L: - 9 I.» Ma- : 9 1*»? I -,-. I.‘ . 3‘ _'..'-. 'I 'u - l {I ' - ‘ ; ‘6‘?" " . *lJi; :‘Ab'iztlfth. “ l - --'. I . :1.- .3 I? ’ J 3 ' T 1'91 9 I; - ‘1L4' . . I q"- '2?" ‘ .J 9. “,7. ,- . A [)Jfir'r‘ 0‘ ‘ _ -y: {\ ') .~_<. - 'I L’: “19-” . .-‘ I . “a I .— Iv .0 -_ f]. ‘ .7. (‘. . . I .‘ 1",E . IN“ '3.) , _ _ . v 2_",-E' 3 t '4 " 375$” 973‘” j a. .. 21L" ' “‘0, P- I . A . .' T ,~ .. .._‘. .Jas" . I : ’5. . r rL . '9 a ._ _.IV?I‘-.AL“|' -"-’-tan-G_{-“ E W,» ‘ C Js‘i‘C'Jf .-'. . 5‘ :v. #\"“3- ' °sm“n-.‘. ., ~ '- x: 9- - l . ‘.-.r-"'.~ ‘. ' ' ‘ ‘j , .‘g. >v.-“ m T" 9 ’§.A.A“'"I:J in, ‘1. ' .l . . . ' 3‘ ‘_J H" “g Q‘.‘ A ' ‘ ‘-\"4¢'§;”I luv“ ' .f‘. _ ‘ l 7 .. Q‘3ytfl‘d‘t.l' 4:- . I .;,. .:.v ‘a o n . '4‘” 9:.\"- 9-3 3 . LI .‘ J 3 ”1'?" ‘~' “ V . v 12915.9 j". 1%??“n‘fl. \Y“.As P,‘ 3/ *1]. .3: "r 3 '4‘ I'. . {‘w ‘ 'Mkf'fi‘zx" "T .1'.-" .1ij ‘ $353.9- A COMPARISON OF THE INVESTMENT AND OPERATING COSTS FOR WATER PRODUCTION BY AIR LIFT PUMPING AND BY DEEP WELL TURBINE PUMPING Thesis forDegree Of Civil Engineer Marshall Edwin Snider 1933 THFC"? Before a municipality, or an industrial group, can install new or expand existing water production facilities, there are several factors which should be considered. Principal among these factors is the source of water supply and means of pumping the water. Lacking a suitable source of surface water supply, such as lakes or rivers, it becomes necessary to resort to a supply derived from either shallow gravel wells or deep rock wells. When deep rock wells are chosen as a source of supply, a further choice must be made with regard to the means of pumping the water from the wells. There are three principal methods of pumping wells:- 1. By suction lift plunger pumps. 2. By deep well turbine pumps. 3. By air lift pumps. Suction lift pumps are being rapidly supplanted by the other types and will not be considered in this paper. The six following combinations for the production and pumpage of well water are to be discussed. All of the plane are based on the same general conditions as detailed later. Plan 1 - 1; lift pump; ’- Purchased pgwer, This plan contemplates the production of water by means of air lift pumps, using air from synchronous motor driven compressors. As is usual in air lift installations, the water flows by gravity from the air separator at the well to a reservoir from which the high lift pumps take suction. All power used is to be purchased from a power utility at the prevailing rate. 2139 II - ‘1; 111; ngmpg - piegel engine pgweg. The only difference between Plan I and Plan II is that the air compressors and high lift pumps are driven by direct connected Diesel engines in Plan 11. £1§g_111,- 1: lift pggpg - §§eam pgwez, This plan varies from Plans 1 and II in that the compressors are steam engine driven and the high lift pumps are driven by steam turbines. A boiler plant is also included for the generation of steam. 21§B_II.- e We 1 u bin - uro ased Power In Plan IV, and likewise in Plans V and VI, the deep well turbine pumps are located in underground vaults and discharge directly to the distribution system. Plan IV uses purchased power for driving the pumps. Power is secured from the same source and at the same rate as in Plan I. An outdoor substation is used to step the voltage - 2 - down to Rho volts for pump motors. gig; I - Qeep Well Turbine Bumps - Qiesel engine power, under Plan V, Diesel engine driven generators located at a central station supply energy for driving the deep well pumps. Elan VI - Deep Well Turbine Bgmpg - Steam nge; Plan VI includes a boiler plant for the generation of steam to supply steam for steam engine driven generators which in turn supply energy to the deep well turbine pumps. It is not the purpose of this paper to express a definite final opinion as to the relative merits of the various ways of pumping water from wells, but rather to suggest a general opinion and suggest a method of compari- son which can be readily applied to any given set of conditions. For purposes of illustration of the method, a set of conditions is assumed and is used throughout the calculations. The assumed conditions follow: general Qonditigng Producing capacity of development - 8 million gallons per day. Static water level - 20 feet below grade Specific capacity - 3 gallons per foot of draw-down Load Factor - 65% Average daily production to mains — 5,200,000 gallons or 3.510 g.p.m. Demand charge: Energy charge: Power Factor. Correction: Discount: Power Rate Schedule 3 2.50 per kw. per month for the first 100 kw. of maximum demand (15 minutes). 8 1.50 per kw. per month for all over 100 kw. of maximum demand. l.15¢ per kw.-hr. for first 250 hours use of maximum demand per month. 0.95¢ per kw.-hr. for all over 250 hours use of maximum demand. The actual demand and measured energy are multiplied by the constant given be- low and the result is the billed demand and billed kilowatt hours: 100% Power Factor 0.9330 90% Power Factor 0.9610 80% Power Factor 1.0000 A discount of 5% is allowed for prompt payment. 00st of Fuel Oil - 6¢ per gallon Cost of Coal - $4.25 per ton in bunker. anditigns Qommon to glans I, II and 1;; Draw-down - 1&0 feet Production capacity of each well - 420 g.p.m. Fourteen 12" diameter wells will be required to supply the 8 m.g.d. demand; two additional wells are added to provide -u- rsserve capacity, making a total of sixteen. These wells are assumed to be cased for the first 60 feet, and to have a depth of #25 feet. Wells spaced 500 feet apart. Height of discharge above grade — 10 feet Average submergence - 255 feet Per Cent submergence - 60% Length of eduction pipe — #25 feet High lift pumping head - 150 feet gonditigns gcmmon to Plans IV. V gnd [1 Top of pump bowls - 200 feet below grade Total pumping head - 330 feet above pumping water level in well (160 foot draw-down) Production capacity of each well - #80 g.p.m. Twelve 1“" diameter wells will be required to supply the 8 m.g.d. demand; two additional wells are added to provide reserve capacity, making a total of 1% wells. Wells cased 60 feet, with a #25 foot total depth and spaced 550 feet. zgwe; Requirements - Plan 1 Air Lift - Purchased Power According to standard empirical formula:- Air Required = 12552_ R 335 08._55i&;i_ 3 = 0.85 cu.ft. free air per gal.of water Total air required is:- 3610 g.p.m. x 0.85 = 3068 cu.ft. air per minute Synchronous motor driven compressors will require -5— .1:- T-T'T"“‘.1 3 -._9 wink-gm” w h . 4 - it - ‘. 1 ‘- “O'y. v v ‘ flu! Am” “ Mil “n“ ‘9 . " .3”): “=2 o. - p 1'" 5 _n- TTWH-M.‘—.‘A-\ . -Oym .‘a‘n.O_IJ-b‘ .aun—mw..u- 0“. “Maw..- _ .§ . 4‘ ‘. ~ ‘ ‘ s a" .I' . _~“ .- e. ' * . v - .' s ' ‘ 20.25 horsepower input per 100 cubic feet of air compressed. 20.25 x 30.68 = 621 horsepower required to bring water from wells to the separating tank, from where it will flow by gravity to the reservoir (low lift). Assuming an overall efficiency of 70% for horizontal motor driven centrifugal high lift pumps, the power input will be:— 3610 g.p.m. L150 ft.head__x 8.3L: lb.per gal, .-. 195 hp. 33,000 ft. lb.per hp..x 70 eff. The total horsepower required will be the sum of the low and high lifts (621 4 195) or 816 hp. which is equivap lent to 610 kw. An average load of 610 kw. will require 445,605 kw.-hr. per month. A 550 hour use of the demand will result in a demand of 810 kw. Assuming a 100% power factor for the synchronous motors, the above quantities will be reduced as a bonus for high power factor by multiplying by 0.933. Application of the rates given above results in a power charge of $6H,309.65 per year for Plan I. zuel Requirements - Plan 11 Air Lift Pump - Diesel Engine Power The fuel required for the Diesel engines used to drive the air compressors and high lift pumps may be calculated in the following manner. _ 6 _ The conditions as to water produced and air required, are the same in both Plan I and II, viz., average daily production 5,200,000 gallons of water and 3,068 cubic feet of free air per minute. Diesel engine driven compressors will require 20.75 brake horsepower per 100 cubic feet of compressed air. 20.75 x 30.68 2 637 b.hp. required to bring water from the wells to the reservoir (low lift). Assuming the same pump efficiencies as in Plan I, 195 b.hp. will be required for high lift pumping. The total brake horsepower will be the sum of low and high lifts or 832 b.hp. The overall economy of a Diesel engine is assumed as 0.6 pounds of fuel per brake horsepower, and cost of fuel as 6 cents per gallon, resulting in an annual fuel cost of $33,900 as follows: §32 hp.x 21+ hrs.x 6 1 day L06 1b.x 1A8 x 6;: 3 $33,900 5 lbs. cost of 011 per cu.ft.) Ego; Requirements - Plan 111 Air Lift Pumps - StgamfPowg; The same conditions of water produced and air required are used as in Plans I and II. - 7 - Steam driven compressors will require 20% indicated horsepower per 100 cubic feet of compressed air. 20.5 x 30.68 = 629 i.hp. required to bring the water from the wells to the reservoirs (low lift). Assuming the same high lift pump horsepower as in Plan 11, 195 i.hp. will be required. The total indicated horsepower will be the sum of the low and high lifts or 824 i.hp. The overall economy of a steam plant operating condens- ing is taken as 20 pounds of steam per indicated horsepower. With an overall evaporation of 8 pounds of steam per pound of coal, and a cost of coal of 34.25 per ton in bunkers, the annual fuel cost is 838,u00, as follows:- §2H i.hp.; 2u'hrs,x 365fi da.x 20$ econ.x fi#.25 per top,= $38,#00 ff evap. x 2000!! Epwgr Reguirepentg - Elan IV Deep Well Turbine Pumps - Purchaged figwgp The power requirements for Plan IV may be determined as follows:- Assuming the same production demands as for the air lift systems, a static level of 20 feet and pumps operating with 160 feet of draw-down and and 150 feet discharge pressure, -8- the water horsepower to be developed equals: 3610 g,p.m, x 339 ft.head x 8.3%:lbs.per gallon = 301 w.hp. 33,000 ft. lb. per hp. Assuming an overall pump efficiency of 60 per cent, 502 hp. input is required for the motors, or 375 kw. With a 2% loss in electric secondary demand and a 3% transforma— tion loss from n,#00 volts to ”#0 volts, this becomes 393 kw. measured energy required. Using the same rate schedule for purchased power as in Plan I the annual electric energy charges are 8k2,553, as follows: An average load of 393 kw. will require 3,u50,000 kw.-hr. per year or 287,500 kw.-hr. per month. A 550 hour use of the demand (as in Plan I) will result in a demand of 523 kw. Assuming a 90% power factor for the induction motors, the demand and energy are multiplied by 0.9610 resulting in a demand of 503 kw. and 276,500 kw.~hr. for energy. Demand charge:- 100 kw. e 32.50 = 8 250.00 #03 kw. a $1.50 a 60n.5o Engergy charge:- 250 x 503 x 1.15¢ =1,uu6.12 150,750 x 0.95¢ = 1,n;2.1; Total Gross charges 3,732.75 ‘9— Total Gross charges $3,732.75 Less 5% 186 6# Monthly Power Cost $3,546.11 Annual Power Cost $M2,553.32 {gel Requirements - Elan V Qegp Well Turbine Pumps - Diesel Engine ngg; Under this plan the energy required at the switch- board is the same as in Plan IV or 382 kw. which is equivalent to 570 brake horsepower of Diesel engine capacity (90% conversion efficiency). Using the same economy and oil costs as in Plan 11, the annual fuel costs are $23,250. 510 5 2” 1 365,25 1 0,6 x 1,48 x ,96 = $23,250 5 Fuel Requirementg - Plan V; Deep ngl Turbine Pumps - Steam Power The switchboard energy requirements of Plan VI are the same as for Plans IV and V, 382 kw. or 570 hp. Using the same economies and costs as in Plan 111, 20 lb. per i.hp. overall economy, 8 lb. evaporation and coal at $h.25 in the bunkers, an annual fuel cost of $26,800. 519 g 2“ 1 365,25 x 20 x n.25 : $26,800 1 2000 -10.. The labor and maintenance charges to be applied to each of the various plans are subject to a consider— able variation, but the following estimates are believed to be reasonable and serve to demonstrate this method of comparison. Plan I Air Lift Purchased Power 11 Air Lift Diesel Power 111 Air Lift Steam Power IV Deep Well Turbines Purchased Power V Deep Well Turbines Diesel Power VI Deep Well Turbines Steam Power Annual Labor Cost $ 8,400 8,N00 12,900 moo 3,1100 12,900 ..11 - 3 Annual Maintenance Cost 3,ooo 4,000 5,000 u,ooo 4,000 5,000 Fixed charges for all plans are taken at the same rate, 15%, as any attempt to differentiate between plans as to percentage of fixed charges would involve contro- versial discussion which would be very difficult of proper solution. Estimated costs of the initial investment are necessary to the determination of the most economical system of producing water. No explanation of these estimates is necessary. The estimates submitted are indicative of firstclass practice in each of the items. The prices used have been accumulated over a period of several years and represent fair market values. Manu- facturers and contractors who have contributed estimates used herein include the following: William H. Cater Pomona Pump 00. Indiana Air Pump Co. Fairbanks-Horse lickes Boiler Co. Chicago Pneumatic Tool Co. Allis Chalmers Mfg. Co. C. H. Wheeler Mfg. Co. - 12 - ‘16 - ‘16 - ‘16 - 116 — Elan I, II gr III Estimated Cost — Well Field Installatign Air Lift Pumping System (8 Million gallons per day capacity) 12' Wells - u25 ft. deep — a no,5oo Air Lift Pumps - 2,noo Piping installations - Eduction pipe and air line - 6,u00 Air separator tanks and towers - 3,200 Air lines from compressing station to wells - 10,000 Discharge Piping — Wells to reservoir ~ 30,000 Real Estate - 20,000 Overhead and Miscellaneous 10%.. 11,250 Engineering and Supervision 5%- 6,060_ Interest during Construction 1%% — 2,015 Total cost of Well Field Development - $131,885 - 13 - Elan iv, v gr v; Estimated Cost - Well Figld Installatign Deep Well Turbine Pump System (8 Million gallons per day capacity) 14,— 14“ Wells - 425 ft. deep — 9 42,000 14»- Deep Well Turbine Pumps — 46,200 141- Pump vaults - 4,900 14,— Meter Installations - 5,600 14-- Piping Installations- 2,800 Electric Distribution Lines — 2,700 Discharge piping from wells to point of transmission - 30,000 Real Estate - 20,000 Overhead and Miscellaneous 10% - 15,420 Engineering and Supervision 5%.. 8,480 Interest during Construction l£% - 2.670 Total cost of Well Field Development - $180,770 - 14‘- 2122.1 Egthated Cost - Statign Installation Motor Driven Compressors 3 - 1800 cu.ft. synchronous motor air compressor - Building and Foundations - Reservoir - one million gallon capacity - Piping and meters — Auxilliaries — Switchboard - Wiring ~ Overhead Crane - 3 - 3000 g.p.m. synchronous motor driven centrifugal high lift pump - Chlorinator - low pressure - Air receiver tanks - Real Estate - Overhead and Miscellaneous 10% - Engineering and Supervision 5% - Interest during Construction 1%% - Total Station Cost - - l5 - 0 45,000 37,300 20,000 5,000 1,000 4,000 4,000 1,500 l2,000 1,200 700 5,000 13,720 7.550 $160,850 {leg 11 Estimated Cost - Statign Installation Diesel Driven Compressors 3 - 1800 cu. ft. Diesel engine driven air compressors - Building and Foundations - Reservoir - one million gallon capacity — Piping and meters - Auxiliaries - Wiring - Overhead Crane - 3 - 3000 g.p.m. Diesel driven centrifugal high lift pumps - Chlorinator — low pressure Air Receivers - Cooling water supply - Fuel Oil Tanks - Railroad siding - Real Estate - Overhead and Miscellaneous - 10% - Engineering and Supervision - 5%:- Interest during Construction - 15% - Total Station Cost - - 16 - S 85.500 53,000 20,000 15,500 6,500 2,000 1,500 22,000 1,200 700 6,000 6,500 2,000 5,000 22,740 12,510 $266,590 Elan III Estimated Cost — Station Installation Steam Driven Compressors 3 - 1800 cu.ft. Steam Engine driven air compressors - Building and Foundations - Reservoir - one million gallon capacity - Piping and meters - Auxiliaries - Wiring - Overhead Crane - 3 - 3000 g.p.m. turbine driven high lift pumps - Chlorinator - Air Receiver Tanks - Cooling water supply - Boilers and settings - Stokers - Chimney and Breeching - Forced Draft fans and ducts - Coal and Ash Handling equipment - Oil Filters and tanks - Condensers - Railroad siding - - 17 - $ ”7.000 81,900 20,000 20,000 4,000 3,000 1,500 14,000 1,200 700 4,000 21,000 8,500 7.500 3,000 9,000 1,000 13,000 2,000 Real Estate - 8 8,000 Overhead and Miscellaneous - 10% - 27,030 Engineering and Supervision - 5% - 14,865 Interest during Construction — 15%1- 4,680 Total Station Cost - $316,875 -18... Elan 1V Egtigated Cost - Outdoor gubstation Ingtallatign Deep Well Turbine Pumps driven Purchased Power 3 - 200 Kv-a. Transformers - $ 3.500 Foundations and Enclosure - 1,000 Wiring — 1,300 Chlorinator (high pressure) - 1,800 Real Estate - 500 Overhead and Miscellaneous - 10% - 810 Engineering and Supervision - 5%«— 450 Interest during Construction - 15% - 159 Total Sub-Station Cost 8 9,500 - 19 _ Riga V Estmmated 09st — Station Installation Diesel Engine Driven Generators 3 — 400 b.hp. Diesel Engines direct connected to 375 kv-a. generators - 3 87,000 Building and Foundations - 42,500 Piping and meters - 13,000 Auxiliaries - 6,500 Switchboards - 4,000 Wiring - 4,000 Overhead Crane — 1,500 Chlorinator (high pressure) - 1,800 Cooling water supply - 6,000 Fuel Oil storage - 5,000 Railroad siding - 2,000 Real Estate - 5,000 Overhead and Miscellaneous 10% - 17,830 Engineering and Supervision 5% - 9,810 Interest during Construction 15% - __3_,9_99 Total Station Cost ‘ $209,030 Elan VI Estimated Cgst - Station Installation Steam Engine Driven Generators 3 - 400 i.hp. Vertical Uniflow Engines direct connected to 375 kv—a. generators - 3 48,000 Building and Foundations - 69,500 Piping and.meters — 20,000 Auxiliaries - 4,500 Switchboard - 5,000 Wiring - 4,000 Crane - 1,500 Chlorinator (high pressure) - 1,800 Cooling water supply - 4,000 Boilers and settings - 16,000 Stokers - 7,000 Chimney and Breeching — 6,500 Forced draft fans and duct - 7,500 Coal and Ash handling equipment - 9,000 011 Filters and Tanks - 1,000 Condensers - 7,000 Railroad siding - 2,000 Real Estate - 8,000 -2],— Overhead and Miscellaneous 10’ - 3 21,730 Engineering and Supervision 5%- 11,950 Interest during Construction 15%.- ‘___3‘1§5 Total Station Cost $254,745 -22- Using the foregoing estimates as a basis, a reason- ably close estimate of the total cost of operation under each plan may be prepared. These total costs of operation are readily reduced to unit costs by considering the total annual production. A tabulation of the cost of Operation for each of the six plans being considered has been made and is now sub- mitted in the following six estimates. The fixed charges shown in each case are the sum of these items on the corresponding station and well field installations. -23- 2199 I nua o t of erat n ;ir Lift Sygtem Uging ngchaged Bower Power - 8 64,310 Labor — 8,400 Lubricants - 300 Supplies - 300 Maintenance - 3,999 Total Production Expense - 8 76,310 Fixed Charges 0 15%‘- 43,919 Total Annual Cost of Operation - $120,220 Unit Cost Per Million Gallons Produced Production Expense - 3 40.14 Fixed Charges - 23,19 Total - 3 63.24 -211- 1 , Apnpal Cgsg 9f 95ergtign Air Lift gygtem — Diesel Engine Driven Compresgors Fuel - ‘ 339900 Labor - 8,400 Lubricants - 2,600 Supplies - 1,200 Cooling water - 1,400 Maintenance — 4,999 Total Production Expense - ‘ 8 51,500 Fixed Charges 0 15% - m Total Annual Cost of Operation - $111,270 Unit Cost Per Million Gallons Produced Production Expense - 8 27.09 Fixed Charges - __3;‘&4 Total - 9 53-53 .025...) 2112.111 Annual Cost of 9peratign A r ft stem - Steam Driven om res or Fuel - 3 38,400 Labor - 12,900 Lubricants - 600 Supplies - 500 Maintenance - 5,990 Total Production Expense - 8 57,400 Fixed Charges 0 15% - 61,314 Total Annual Cost of Operation - $124,714 Unit Cost Per Million Gallons Produced Production Expense - 8 30.19 Fixed Charges - 35,49 Total - 8 65.65 _ 26 _ Fig.1! Annual Cost of 92erat19n 9eep We11 Turbine Pumpg - Purchased Pgwer Power - 1 42.553 Labor - 4,800 Lubricants - 300 Supplies - 600 Maintenance - 4,999 Total Production Expense - 9 52,253 Fixed Charges 0 15% - 28,540 Total Annual Cost of Operation - 8 80,793 Unit Cost Per Million Gallons Produced Production Expense - 8 27.49 Fixed Charges - . 45.1.91 Total - 8 42.50 n27... Plan I Annual Cost of 92ergtigg ee We Turbine - iesel riven enerators Fuel - 8 23,250 Labor - 8,400 Lubricants - 2,000 Supplies - 800 Cooling Water - 1,400 Maintenance —. ___4_,p_99 Total Production Expense — 8 39,850 Fixed Charges 0 15% - _5_8_,_4;19 Total Annual Cost of Operation - 8 98,320 unit Cost Per Million Gallons Produced Production Expense - 8 20.96 Fixed Charges - __19115 Total - 8 51.72 _ 25 - 2199 V1 Apnual 0093 of Operation 9egp Well Turbine Bumps - Steam Driven Generators Fuel - 3 26,300 Labor - 12,900 Lubricants - 900 Supplies - 700 Maintenance — 5,990 Total Production Expense - 8 46,300 Fixed Charges 0 15% - 65,321 Total Annual Cost of Operation - 8111,627 Uhit Cost Per Million Gallons Produced Production Expense - 8 24.35 Fixed Charges - __15111 Total - $ 53-72 -29.... For purposes of easy comparison the resultant data obtained in the last six tabulations is shown below: Unit Costs Per Million Gallons Produced Plan. I - Air Lift Purchased Power II - Air Lift Diesel Power III ~Air Lift Steam Power IV - Deep Well Turbines Purchased Power V - Deep Well Turbines Diesel Power VI - Deep Well Turbines Steam Power Production Egpense 8 40.14 27.09 30.19 27.49 20.96 24.35 Fixed Chargeg 8 23.10 31.44 35.46 15.01 30.76 34-}? Total Expenge 8 63.24 55- 53 65.65 42.50 51.72 58.72 Explanation of the above tabulation will show that the cost of producing water by means of deep well turbine pumps driven by purchased power is decidedly lower than in any of the other five methods discussed. - 3o _ A definite statement concerning the relative economies of the various plans can only be made after a detailed study has been prepared of the case in question. This is true because of the wide variation possible in each of the factors effecting the problem. A favorable market in which machinery might be purchased would have a correspondingly favorable effect on the fixed charges, but it is very doubtful if this effect would be suffici- ent to overcome the decided advantage indicated for Plan IV (Deep Well Turbines and Purchased Power). The relative cost of fuel or electric energy will also have a decided effect on “Total Production Costs“, but it is probable that the cost of coal, fuel oil or electric energy will fluctuate similarily and the net result will be approximately as indicated. In view of the above, the general statement may therefore be made that water may be most economically produced, and pumped to the water distribution system, by means of deep well turbine pumps driven by purchased power. - 31 _ 'i-I'...'.F '-—-——-—«| f:'.“’._._ r..-y—f , ENG»: soou- ss'xso' .5 ’ ' ’ 1'2““ I j ' —q A ‘ w”: [ii-'1‘.) 1 f? i FT“. 13 9' I -. R: “a ;. I‘1‘ /| .3: ‘-j ”I?“ by“ 4_:J 3'2000 CU. FT. MOTOR URI " AIR COMPRESSOR VEN " 9H1”: 1"“? In 2‘3 :+- z; (E E ,1, 3} .1 ,9 ‘ _ I J EH 1 :' _. 11 3 ;. a. 4H0!) 4M6!) ‘MOTm WVEN HIGH LIFT PUMPS ‘I G ,1 ' ‘1 :' ,8. 1: El E [is 12 ‘3 once ,1 4 317cm" R327” J1 a, J, 8*” I fiW'f; “f r... .1 .L. ,_ . (vie—14;,mwA—«4 alt/f... reassess I ‘ P LA N N9 I LAYOUT OF PURCHASED POWER DRIVEN AIR COMPRESSORS 8. HIGH LIFT PUMPS ; ENGIIC soon WUUUU ..== g; 43 1: so .f - ' 5 '— In“ H j “(is ///——e S‘ZOOOCUFT. meme: GALLON mesa. ENGIDE DRIVEN HIGH LFT ms\ AIR INTAKE DUCT LUBRICATING OIL FIIJ’ER TANK PLAN N9 2 LAYOUT OF DIESEL ENGINE DRIVEN COMPRESSING AND HIGH LIFT PUMPING PLANT M INATION FEED WATER $48K? TORAGE TANK ON PLATFORM I4' HIGH ‘CI-IIMNEY- eio‘XIaO' 43.351.»- - ~(‘2ltu - ‘I’fliu -I..' , ‘73.»? r. 5' aka,” j}- W':& \ J; \ J; M ‘ ' :6 e ' . f; .1112. : '2 qTOILET f: r ‘ II] MOTOR DRIVEN) -—~ -- g , ,/,' I PUMP "-411; 7‘ 1.1 J (,1 J was": DRIVEN FEED 2 ’ ” ’ HATCHWAY . . . PU“? a I I" .. ' . ,/ ( w. _ ,x 1*: .J) " r - . 1’, < T I 5 J Jr: 03 , . . __ J , s-zoooc Tmssoss r n W . ’ 7 ,: STEAM DRIVEN r * ‘L F ‘ ' ' 2 l ' j e- l}— I U ,- -_’;i 1’ ‘MO “A ' I .I 1 *r‘ H . 1 ’ I " II. . I1 , 1'. ‘, A. I ‘3 111'. E ; ' r ' ‘ I Y - - 1 II . 7—1 *5 T f ‘4 1 n- I II " 115411 7' : o ’ I ,u' H .- 14‘ 2d 3 ' ‘1 7 3 1:; 111”» 1 J I T -- L.- - 1(7 H I ,1 J ‘ J ‘ / sous ROOM- 44 x54' ' 3'4 I ‘ 1‘ 1,33% ' :"3'5— 3,33%— 3-3000 GALLON TURBINE DRIVEN PLAN GHLFT PUMPS 1' A53” I |/IF I ~ I .. e. "is r a . . I I, J-Tf-YJIQF—EQ" r " Y 1 n: STfiqGE t.— ..A IN _. Lawson? 1' some 1: "J'v—fl! I— 8 H § 11 3 u, . TI 1‘ | l 1" z" i s : a. - r. .j I 1 9 ' :5 , . :3 1 f“"""”.' \J J (/1 \‘f r <. _, . 3‘ v') I ~ ,. - "I. —-*~ , {a - are. ' 1 (" ' -. I“. :I 111- ~ . '4 “‘42. 8”.) I. '7': ELEVATION PLAN N9 3 LAYOUT OF STEAM DRIVEN AIR COMPRESSORS 8. HIGH LIFT PUMPS magn— UZEmD... JJu>> ammo m0... mugom omméumbm OZ.Im_ZmDn_ m0... ZOEK—h mmImOumz /@ ~ I (4 —% I I_ — , I l9. Oil Dump 3’ ‘ 12‘ ‘ - \ / 1* _ I I .97.. \ /// / —' I 20 Lilo/oer Oil 5leeve "3’0, 10 // /_ i ‘ 1/ I 2/ Oil Pump J/eeve ®\ . 3..., T , I , // ; '3‘ __ '57; l‘ , ' » I 22 Air Def/color 33 —— ' ‘ ,- ' _ =3 I 4‘ 141’ « I; ‘ . 23. Polar Hollow Jlml’l. 34 ———..:.___ "l I ’ E' Q N A 6‘ 1:, ”7 ,-_ ‘ 24. Polar. __ H___ .1',‘ :5”, . I ' _m f 4:3. I I II' u: "f I l I 'I/II/I l/I , ‘ { \ Z 25. Polar Key ‘ / \ 22 I _ U" _ G; I: ! \ [ 26. Seal/r7} Ping. at}; I . \ \ I ,- ‘ ” ' I I j ' 27. Lower 0H Sleeve I m x \ ® I A/ I “II M \ \._\ ‘ 28. JIeeve Bear/r17 Bush/"19 ' ' ‘ -7 \ L w \ I 29. Lower- Oil Cup. \fl/ \ JO Waler‘ Jlinger. \p ‘ 7 \ \@ 3l. Rack/n7 d/ana/ ' g \\ ‘ .32 Packing Grease Cup é ‘ .33 Pr/m/ny Wafer ln/el Connecl/on f Lil .. 34. Drain Pipe Conneclion. .35 upper Dock/n? 36. Packing box. .37 Packing Gland Bearing. .39. Discharge Column 75p Pipe- 40. Drive J'hal‘l coup/my. 4 / - Bea ring J/ee ve - Nonferrooi ve - Pep/aceab le . 42’ Pomona Polenled Revolvab/e u b be r Slee ve 43 Discharge Column Bré. fiela/ncr. 44 Discharye Column Baa. Pela/ner‘ Cap. 45. Discharye Column Coup/inf 47 I, ‘ I 46. Discharge Column Bo/fom Pipe ,1 ‘ ‘l: 47 Pump JIM/V Coup/inf. 4} "i 46. 50nd le'nyer‘. 45 l i ‘ 49. Discharge Bowl 50. WalerLubr/cafea’ Discharye Bowl Bearing _ 5/. Impeller Lock Nul 52. fmpe/ler'. 53. Impeller Bush/"n3 54. Inlermedla le Bowl- 55 WalerLubr-icalea’ Inlermed/ale 52 Bow/ Bearing. 56. Juclion Bowl. 57. Waler Lubr/ca lea’ Sue lion Bowl Bear/n9. 55. Pump Jhafl’. Cap. 53 59. duclion Jlra/ner'. 55 52 42-43-44, Pomona Wafer- Lubn’cafed 55 line Jhal'l Guide dear/’19 Palenlea’ Ocl, 20, /925. 5 2 49-5l-52-53J4-56 , Fbmond Wafer. l. ubrlcalea’ Turbine Pump Assembly. 5 7 Po len/edd'ept 22, I955: 55 — Oliver Palenfo Pending. — SECTIONAL ILLUSTRATION OF TYPE 'HJ” POM DNA 5 / \ f — ELECTRIC UNIDPI VE — DEEP WELL TURBINE PUMP Mm: LUBRICATED BELOW 7):: HEAD o ) ‘ ‘ ‘ . . POI/101141 1 [Uh/2 (.0., Pomona, California lllllllllllIl! | HI lllllllNlHllllll lllllllllllfllfllllllll 3 1293 0317