Energy Water Work Book

7/30/2019 Energy Water Work Book

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Key for Reading Spreadsheets

Water inputs for all energy sources (EXCEPT coal) are color coded as follows:Agriculture

Mining

Transportation

Processing

Cooling

Cleaning

Evaporative Losses (hydroelectric facilities only)

Other

References and sources are identified with their numbers using the following codeW= Withdrawal

C= Consumption

H= High figure

L= Low figure

At the top of each spreadsheet, the water requirements for each step in the generation prare listed. At the bottom of each spreadsheet, different technological options are combine

total estimates of water requirements are provided.


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:

ocessd and


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Water Requirements for Bioenergy Power Production

All Numbers in m3/MWh

BIOENERGY Withdrawal Consumption

m^3/MWh m^3/MWh

Item Low High Low High

Agriculture, Rapeseed 360 630 360 630

Agriculture, Sugarcane 133 558 133 558

Agriculture, Sugar Beet 256 677 256 677

Agriculture, Corn 263 1250 263 1250

Agriculture, Wheat 144 1260 144 1260

2.5198 2.5198 2.5198 2.5198

1.7999 1.7999 1.7999 1.7999

0.3600 0.3600 0.3600 0.3600

0.1080 3.2400

BIOGAS Withdrawal Consumption

m^3/MWh m^3/MWh


Simple Cycle 0.0836 0.0836 0.0836 0.0836

Combined cycle, wet cooli 0.8706 0.8706 0.6813 0.6813

Combined cycle, dry cooli 0.1514 0.1514 0 0

Combined cycle, once-thr 9.084 75.7 0.3785 0.3785

Steam turbine, once-thru 75.7 189.25 1.1355 1.1355

Steam turbine, wet coolin 1.1355 3.028 0.9084 2.4224Steam turbine, dry cooling 0.1514 0.1514 0 0

Steam turbine, pond cooli 1.1355 2.271 1.1355 1.8168

Biomass-based steamplant

Improved biomass-basedsteam plant

Gasification-based,combined cyclegeneration

Quench feed water forwet scrubbing of syngas

(exiting gasifier)


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Mining, combined cycle co 0 0 0 0

Transportation, combined 0 0 0 0

Other 0 0 0 0

Inlet fogging (additional o 0.4731 1 0.4731 1

Bioenergy Power Production Method

Dedicated Energy Crops

1 Dedicated energy crops - rapeseed - gasification -2 Dedicated energy crops - sugarcane - gasification -

3 Dedicated energy crops - Sugar beet - gasification -

4 Dedicated energy crops - Corn - gasification -

5 Dedicated energy crops - Wheat - gasification -6 Dedicated energy crops - rapeseed - gasification - syngas

7 Dedicated energy crops - sugarcane - gasification - syngas

8 Dedicated energy crops - Sugar beet - gasification - synga

9 Dedicated energy crops - Corn - gasification - syngas scrub

10 Dedicated energy crops - Wheat - gasification - syngas scr11 Dedicated energy crops - rapeseed - Biomass-based stea

12 Dedicated energy crops - sugarcane - Biomass-based stea

13 Dedicated energy crops - Sugar beet - Biomass-based ste14 Dedicated energy crops - Corn - Biomass-based steam pla

15 Dedicated energy crops - Wheat - Biomass-based steam pl16 Dedicated energy crops - rapeseed - Improved biomass-ba

17 Dedicated energy crops - sugarcane - Improved biomass-

18 Dedicated energy crops - Sugar beet - Improved biomass-

19 Dedicated energy crops - Corn - Improved biomass-based

20 Dedicated energy crops - Wheat - Improved biomass-base

Waste Products

21Agricultural/Forestry Waste - gasification -22Agricultural/Forestry Waste - gasification - syngas scrubbin

23Agricultural/Forestry Waste - Biomass-based steam plant24Agricultural/Forestry Waste - Improved biomass-based ste

Biogas (including landfill gas or WWTP gas - methane)

25 Biogas - Simple cycle

26 Biogas - Simple cycle with inlet fogging

27 Biogas - Combined cycle with wet cooling and inlet fogging

28 Biogas - Combined cycle with wet cooling


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29 Biogas - Combined cycle with dry cooling and inlet fogging

30 Biogas - Combined cycle with dry cooling

31 Biogas - Combined cycle, once-thru cooling

32 Biogas - Steam turbine, once-thru cooling

33 Biogas - Steam turbine, wet cooling

Biogas - Steam turbine, dry cooling

34 Biogas - Steam turbine, pond cooling35

36


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Notes/Assumptions Sources


Data is originally all in terms of "water useefficiency". We use the same numbers for ratesof withdrawal and consumption, assuming thatall applied water (for irrigation) is evapo-transpired. Original study assumes that, for thelower numbers (more efficient systems) wastebyproducts and harvest residues are used togenerate electricity.

Berndes, 2002[W,C/H,L]





Assumes a 23% specified efficiency and a HHVat 20 Gj/Mg

USDOE/EPRI,

1997 and Berndes,2001 [W,C/H,L]

Assumes a 34% specified efficiency and a HHVof 20 GJ/Mg

USDOE/EPRI,1997 and Berndes,2001 [W,C/H,L]

Includes boiler feed water requirements butNOT wet scrubbing. Steam from the steamcycle is injected into the gasifier Asumes aspecified efficiency of 36% and a HHV of 20GJ/Mg.

USDOE/EPRI,1997 and Berndes,2002 [W,C/H,L]

For methanol. Hydrogen values are much

higher.

Katofsky, 1993 andBerndes, 2002

[W,C/H,L]

Assumes a 500 MW plant. Analysis assumesthat water requirements for landfill gas facilitiesare comparable to those for conventionalnatural gas facilities. All data are taken from

conventional natural gas facilities.

Maulbetsch 2006,EPRI, CATF et al.

2003


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Maulbetsch 2006

Withdrawal Water Requirement (m3/MWh)

Low High Low High

360.3 630.4 360.3 630.4133.4 558.4 133.4 558.4

256.4 677.4 256.4 677.4

263.4 1250.4 263.4 1250.4

144.4 1260.4 144.4 1260.4

360.4 633.6 360.3 630.4

133.5 561.6 133.4 558.4

256.5 680.6 256.4 677.4

263.5 1253.6 263.4 1250.4

144.5 1263.6 144.4 1260.4

362.5 632.5 362.5 632.5

135.5 560.5 135.5 560.5

258.5 679.5 258.5 679.5265.5 1252.5 265.5 1252.5

146.5 1262.5 146.5 1262.5

361.8 631.8 361.8 631.8

134.8 559.8 134.8 559.8

257.8 678.8 257.8 678.8

264.8 1251.8 264.8 1251.8

145.8 1261.8 145.8 1261.8

0.36 0.36 0.36 0.36

0.47 3.60 0.36 0.36

2.52 2.52 2.52 2.521.80 1.80 1.80 1.80

0.08 0.08 0.08 0.08

0.56 0.69 0.56 0.69

1.34 1.48 1.15 1.29

0.87 0.87 0.68 0.68

Unlike traditional natural gas, we assume noprocessing water needs (because landfill gasfacilities often produce additional water bydrying the captured gas). The processing waterneeded to produce energy from conventional

natural gas is used in the pumping process.We assume no transportation costs, as energyis typically produced on-site (with landfill gasgeneration).

Consumptive Water Requirement(m3/MWh)


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0.62 0.76 0.47 0.61

0.15 0.15 0.00 0.00

9.08 75.70 0.38 0.38

75.70 189.25 1.14 1.14

1.14 3.03 0.91 2.42

0.15 0.15 0.00 0.00

1.14 2.27 1.14 1.82


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Water Requirements for Coal Power Production


COAL Withdrawal Consumption

m^3/MWh m^3/MWh

Item Low High Low High Notes/Assumptions Sources

Surface Mining 0.01 0.49 0.01 0.05

Underground Mining 0.45 0.45 0.03 0.21

Coal Washing 0.01 0.02 0.00 0.00 80% of eastern and interior coal is washed [W] (Gleick 1994

Pulverized Slurry Line 0.03 0.90 0.03 0.90

Log Slurry Line 0.01 0.27 0.01 0.27 Saves up to 70% water of traditional slurry. [W] & [C] (Liu 20

IGCC (Gasification) 0.18 0.24 0.09 0.13 500 MW plant [W] & [C] (Klett 2

IGCC Makeup Water (ex. Cooling) 0.15 0.39 [W] & [C] (Klett 2

IGCC Process Losses 0.09 0.13 [W] & [C] (Klett 2

IGCC Flue Gas Water Losses 0.29 0.40 [W] & [C] (Klett 2IGCC Wet Cooling 2.30 2.79 2.30 2.79 [W] & [C] (Klett 2

IGCC Pond Cooling 0.74 1.48 0.74 1.18 [W] & [C] (Klett 2

PC Combustion 0.14 0.16 0.00 0.00 600MW pulverized coal plant.

PC Makeup Water (ex. Cooling) 0.01 0.02

PC Process Losses 0.03 0.03

PC Flue Gas Water Losses 0.36 0.41

PC Flue Gas Desulfurization 0.24 0.40 0.24 0.40

PC Wet Cooling 3.71 4.16 3.71 3.71 Numbers are thermoelectic averages

PC Once-Through Cooling 75.70 189.25 1.14 1.14PC Pond Cooling 1.14 2.27 1.14 1.82 Numbers from EPRI are thermoelectric averages [C]&[W] (EPRI 2

PC Hybrid Wet-Dry Cooling 0.38 3.63 0.36 3.33 [C] (EPRI 2002)

PC Direct Dry Cooling 0.09 0.23 0.09 0.21 (Queensland Go

PC Indirect Dry Cooling 0.09 0.23 0.09 0.21 N/A

Choose consumption higher value if revegetating6150 kWh/ton of coal mined

[CH] (Gleick 199[CL] Set to Matc[WL]Calculation1994) and NMA [WH] Coal Text

[C](Gleick 1994)[WL]Calculation1994) and NMA [WH] Coal Text

[CH](Gleick 1992006)[WL]Coal Textbo[WH]Set to matc[CL]Set to match

[W] (Ziemkiewicz[C]Hypothesis b

[CH] (Feeley et a[CL] (EPRI 2002[WH] (Feeley et [WL] (EPRI 2002

Uses 35% less water when paired with an IGCC

plant

[W] (Ziemkiewicz

[C]Hypothesis b

Results in about 50% less water consumption thana conventional closed-loop wet cooling systemConsumption is 20-80% of recirculating wetcoolingUses 35% less water when paired with an IGCCplant

Dry cooling cuts consumption by 95% (Comparedto wet cooling)Uses 35% less water when paired with an IGCCplant

Uses 35% less water when paired with an IGCC

plant


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Water Requirements for Geothermal Power Production


GEOTHERMAL Withdrawal Consumption

m^3/MWh m^3/MWh


0 3.49 0 3.49

0 3.49 0 3.49

Cooling, once through

0 54 0 0.246

Cooling, wet recirculating (cooling towers)0 17.03 0 17.03

Cooling, dry

0 0 0 0

Cooling, Imperial Valley 7.7 14.1 7.7 14.1

Cooling, other locations in California 0 0.019 0 0.019

Geothermal Power Production Method

Low High Low High

Steam dominated, once through cooling 0 57.49 0 3.736

Steam dominated, dry cooling 0 3.49 0 3.49

Water dominated, once through cooling 0 57.49 0 3.736

Water dominated, dry cooling 0 3.49 0 3.49

Steam dominated, wet recirculating cooling 0 20.52 0 20.52

Water dominated, wet recirculating cooling 0 20.52 0 20.52

Injection from external sources, waterdominated system

Injection from external sources, steamdominated system

FOR CALIFORNIA CASE STUDY, MORESPECIFIC NUMBERS:

WithdrawalWater

Requirement

(m3/MWh)

ConsumptiveWater

Requirement

(m3/MWh)


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Special notes:

We are no longer considering geothermal fluid or steam in this spreadsheet.


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High number reflects the only externalinjection program of its kind, in the Geysers

[W, C]Sass and Priest 2002, Dept ofOil, Gas, and Geothermal Resources2005

High number reflects the only externalinjection program of its kind, in the Geysers

[W, C]Sass and Priest 2002, Dept ofOil, Gas, and Geothermal Resources2005

WL, CL from Bagnore, Italy; WH fromNesjavellir, Iceland. CH from Salton SeaUnit 6. The Iceland plant disposes ofwastewater into groundwater flowing to a

lake; maybe that explains the high. Ibelieve it's like a once-through coolingsystem. Gleick says up to 15 m3/MWh ifyou need external water. The Geysersrequires no external water for cooling(Gleick 1994).

[WH]Hagedoorn 2006, [CH] Adams etal. 2005[WL]/[CL]Hagedoorn 2006

[WL]/[CL]Adams et al. 2005, [WH]/[CH]Charles et al. 2006

Kagel mentions no numbers here; I amassuming the water required is negligible. Iffossil plants withdraw such little water fordry cooling, I am assuming that small

amount can be easily met with geothermalfluid (which we aren't counting).

[WH]/[CH]Kagel et al. 2005, USDOE2006

[WL]/[CL]Kagel et al. 2005, USDOE2006


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Water Requirements for Hydroelectric Power Production


Hydroelectric Withdrawal Consumption

m^3/MWh m^3/MWh

Item Low High Low High Notes/Ass Sources

Evaporative Losses, 25 MW plant 162 162.0 0.036 2.520 Gleick 199

Hydroelectric Power Production Method

Low High

1 Reservoir and Dam, < 25 MW capacity - Dam Height < Gross Static Head 208.8 208.8

2 Reservoir and Dam, < 25 MW capacity - Dam Height > Gross Static Head 208.8 208.8

3 Reservoir and Dam, > 25 MW capacity - Dam Height < Gross Static Head 162.0 162.0

4 Reservoir and Dam, > 25 MW capacity - Dam Height > Gross Static Head 162.0 162.0

5 "Run of River" Facility 0 0

6 Facilities in aqueducts 0 0

7

statisticsfor that

sizefacility.

Withdrawal WaterRequirement(m3/MWh)


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2 [W,C/H,L]

2 [W,C/H,L]

Low High

0.18 82.7

1.94 209

0.036 122

3.6 162

0 0

0 0

Consumptive WaterRequirement(m3/MWh)

Assumes that"run of river"facilities do notimpound water,increasing ratesof evaporation

Assumes thatthese facilities donot increase

rates ofevaporationabove existingrates.


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Water Requirements for Natural Gas Power Production


NATURAL GAS Withdrawal Consumption

m^3/MWh m^3/MWh


Simple Cycle 0.084 0.084 0.084 0.084Combined cycle, wet cooling 0.871 0.871 0.681 0.681

Combined cycle, dry cooling 0.151 0.151 0.000 0.000

Combined cycle, once-thru cooling9.084 75.700 0.379 0.379

Steam turbine, once-thru cooling 75.700 189.251 1.136 1.136

Steam turbine, wet cooling 1.136 3.028 0.908 2.422

Steam turbine, dry cooling 0.151 0.151 0.000 0.000

Steam turbine, pond cooling 1.136 2.271 1.136 1.817

Inlet fogging (additional option) 0.473 0.606 0.473 0.606

0.036 0.036 0.036 0.036

0.060 0.060 0.060 0.060

0.018 0.018 0.018 0.018

0.030 0.030 0.030 0.030

Other (hotel load)

0.000 0.360 0.000 0.360

Natural Gas Power Production Method

Low High Low High

Simple cycle, no inlet fogging 0.116 0.116 0.116 0.116

Simple cycle, inlet fogging 0.589 0.722 0.589 0.722

1.376 1.509 1.187 1.319

0.903 0.903 0.714 0.714

0.657 0.789 0.506 0.638

0.184 0.184 0.032 0.032

Combined cycle, once-thru cooling9.116 75.733 0.411 0.411


Mining, combined cycle conversiontechnology

Mining, Simple cycle conversiontechnology

Transportation, combined cycleconversion technology

Transportation, simple cycleconversion technology


ConsumptiveWater

Requirement(m3/MWh)

Combined cycle, wet cooling, inletfogging

Combined cycle, wet cooling, noinlet fogging

Combined cycle, dry cooling, inletfogging

Combined cycle, dry cooling, noinlet fogging


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Assumptions Source

Assumes a 500 MW plant

Maulbetsch 2006

Maulbetsch 2006,EPRI, CATF et al.

2003

Assumes a conversion efficiency of60% for combined cycle plants

Assumes a conversion efficiency of36% (from thermal to electricJoules), source - Gleick (1994)

Assumes a conversion efficiency of60% for combined cycle plants

Assumes a conversion efficiency of36% (from thermal to electricJoules), source - Gleick (1994)

Gleick says 0.36, but I use 0 in otherplaces to avoid mismatching

sources.


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Water Requirements for Nuclear Power Production


NUCLEARWithdrawal Consumption

m^3/MWh m^3/MWh


Surface Uranium Mining 0.2323 0.2323 0 0 only for surface mining [W] & [C]: Gleick 1993

Underground Uranium Mining 0.0023 0.0023 0 0 only for underground mining [W] & [C]: Gleick 1993

Processing 0.7548 0.9058 0.4522 0.5365 [W] & [C]: Gleick 1993

BWR

once-thru cooling94.6253 ### 0.3785 5.0350

3.0280 5.6775 1.5140 5.6775

2.7252 4.1635 2.7252 2.7252 [W] & [C]: EPRI 2002

PWR

once-thru cooling94.6253 227.101 0.3785 1.5140

3.02801 5.67752 1.5140 5.6775

2.7252 4.16351 2.7252 3.2330

,conversion, enrichment, fuelfabrication, fuelreprocessing

for BWR assuming once-through cooling

[W]: EPRI 2002; [C/L]: Hoff2004; [C/H] Pace UniversitEnvironmental Law Center

natural draft wetcooling tower

[W/L]:EPRI 2002; [W/H]:Ho2004; [C/H]:EPRI 2002; [Cet al. 2004

closed cycle coolingpond, lake, orreservoir

[W] EPRI 2002; [C/L]: Hoff2004; [C/H]: EPRI 2002

natural draft wetcooling tower

[W/L]:EPRI 2002; [W/H]:Ho2004; [C/H]:EPRI 2002; [Cet al. 2004

closed cycle coolingpond, lake, orreservoir

[W] EPRI 2002; [C/L]: EPRPace University EnvironmeCenter 1990


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Water Requirements for Oil Power Production


OILWithdrawal Consumption

m^3/MWh m^3/MWh


0.028 0.045 0.028 0.045

Oil Shale Mining - Indirect AGR 0.035 0.047 0.035 0.047

Oil Shale Mining - Modified In-situ (MIS)/AGR 0.013 0.014 0.013 0.014

Oil Shale Mining - Modified In-situ (MIS) 0.020 0.020 0.020 0.020

0.088 0.111 0.088 0.111

Oil Shale Processing - Indirect AGR 0.137 0.201 0.137 0.201

Oil Shale Processing - Modified In-situ (MIS)/AGR 0.121 0.145 0.121 0.145

Oil Shale Processing - Modified In-situ (MIS) 0.100 0.100 0.100 0.100

0.077 0.121 0.077 0.121

Oil Shale (Other) - Indirect AGR 0.181 0.276 0.181 0.276

Oil Shale (Other) - Modified In-situ (MIS)/AGR 0.072 0.094 0.072 0.094

Oil Shale (Other) - Modified In-situ (MIS) 0.077 0.077 0.077 0.077

Combined cycle, once-thru cooling 9.084 75.700 0.379 0.379

Combined cycle, wet cooling 0.871 0.871 0.681 0.681






Drilling 0.01 32.04 0.01 32.04

Refining 0.09 0.43 0.09 0.43

Other (hotel load) 0.25 0.25 0.25 0.25

Oil Power Production Method

Low High Low High

Combined cycle, once-thru cooling 9.437 108.424 0.731 33.103

Combined cycle, wet cooling 1.223 33.595 1.034 33.405






9.278 75.978 0.572 0.656

Oil Shale Mining - Direct Aboveground Retorting(AGR)

Oil Shale Processing - Direct AbovegroundRetorting (AGR)

Oil Shale (Other) - Direct Aboveground Retorting(AGR)


ConsumptiveWater Requirement

(m3/MWh)

Oil Shale - Direct Aboveground Retorting -Combined cycle, once-thru cooling


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1.064 1.148 0.875 0.959

0.345 0.429 0.194 0.278

75.894 189.528 1.329 1.413

1.329 3.306 1.102 2.700

1.329 2.549 1.329 2.095

9.438 76.224 0.732 0.902

1.224 1.394 1.035 1.205

0.505 0.675 0.353 0.524

76.054 189.774 1.489 1.659

1.489 3.552 1.262 2.946

1.489 2.795 1.489 2.340

9.291 75.953 0.585 0.631

1.077 1.123 0.888 0.934

0.358 0.404 0.206 0.252

75.907 189.503 1.342 1.388

1.342 3.280 1.115 2.675

1.342 2.523 1.342 2.069

9.280 75.897 0.575 0.575

1.067 1.067 0.878 0.878

0.348 0.348 0.196 0.196

75.897 189.447 1.332 1.332

1.332 3.224 1.105 2.619

1.332 2.467 1.332 2.013

Oil Shale - Direct Aboveground Retorting -Combined cycle, wet cooling

Oil Shale - Direct Aboveground Retorting -Combined cycle - Dry cooling

- -- -

Oil Shale - Direct Aboveground Retorting - Steam

turbine - wet coolingOil Shale - Direct Aboveground Retorting - Steamturbine - pond cooling

Oil Shale - Indirect Aboveground Retorting -Combined cycle, once-thru cooling

Oil Shale - Indirect Aboveground Retorting -Combined cycle, wet cooling

Oil Shale - Indirect Aboveground Retorting -Combined cycle - Dry cooling

a e - n rec ovegroun e or ng - eamturbine - Once-throu h coolinOil Shale - Indirect Aboveground Retorting - Steamturbine - wet cooling

Oil Shale - Indirect Aboveground Retorting - Steamturbine - pond cooling

Oil Shale - Modified In-Situ/AGR - Combined cycle,once-thru cooling

Oil Shale - Modified In-Situ/AGR - Combined cycle,wet cooling

Oil Shale - Modified In-Situ/AGR - Combined cycle -Dry cooling

Oil Shale - Modified In-Situ/AGR - Steam turbine -Once-through cooling

Oil Shale - Modified In-Situ/AGR - Steam turbine -wet cooling

Oil Shale - Modified In-Situ/AGR - Steam turbine -pond cooling

Oil Shale - Modified In-Situ - Combined cycle, once-thru cooling

Oil Shale - Modified In-Situ - Combined cycle, wetcooling

Oil Shale - Modified In-Situ - Combined cycle - Drycooling

Oil Shale - Modified In-Situ - Steam turbine - Once-through cooling

Oil Shale - Modified In-Situ - Steam turbine - wetcooling

Oil Shale - Modified In-Situ - Steam turbine - pondcooling


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Gleick 1994

Gleick 1994

Gleick 1994

average

58.931

17.409

16.690

149.014

18.620

16.690

18.242

42.628

All calculations assume one barrel ofcrude oil (42 gallons) has an energycapacity of 1700 kWh. Assumes a50,000 bbl/day facility. The citedreference describes all water used as"consumed water" and does notdistinguish from "withdrawn water". Thequality of the water may, indeed, meanthat it is effectively consumed; however,there may be some opportunity forreclaiming water. We do not tackle thatquestion. "Other" uses include water for

disposal and revegetation, dust controlduring extraction, plant utilities, and on-site power needs.

EmergingIssues for

FossilEnergy andWater, 2006

[W,C/H,L]

Analysis assumes that oil cooling is thesame as natural gas cooling.

EPRI, CATFet al. 2003


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1.106

0.387

132.711

2.317

1.939

42.831

1.309

0.590

132.914

2.520

2.142

42.622

1.100

0.381

132.705

2.311

1.933

42.589

1.067

0.348

132.672

2.278

1.900


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Water Requirements for Solar Power Production


SOLARWithdrawal Consumption

m^3/MWh m^3/MWh


Parabolic Trough Plant - wet cooling 2.80 2.87 2.80 2.87

Parabolic Dish-Engine - dry cooling 0 0 0 0 No cooling required. Stoddard, et al.2006 [W,C/H,LPower Tower - wet cooling 2.40 2.80 2.40 2.80

PV - Distributed (Rooftop) Systems 0 0 0 0 No cooling required.

PV - Large Centralized Plants 0 0 0 0 No cooling required.

PV - Concentrating PV Systems 0 0 0 0 No cooling required.

Parabolic Trough Plant washing 0.14 0.27 0.14 0.27

Parabolic Dish-Engine washing 0 0 0 0 Stoddard, et al.2006 [W,C/H,

Power Tower washing 0 0.14 0 0.14

PV - Distributed (Rooftop) Systems w

0 0.11 0 0.11

PV - Large Centralized Plant washing

0 0.11 0 0.11 AWEA Website 2006

PV - Concentrating PV Systems washi 0 0 0 0 Stoddard, et al.2006

Solar Power Production Method

Withdrawn is equivilant to consumedwhen withdrawn numbers are notavailable.

Stoddard, et al.2006 [W,C/LThe Last Straw [W,C/H]

Stoddard et al. 2006 [W,C/H

The Last Straw; Stoddard et a[W,C/H,L]

High number found by subtracting thecooling water amt from the coolingand process water amt listed for thistechnology in the Last Straw

Stoddard, et al.2006 [W,C/LDirect Communication, MikeRoverson, Kramer Junction[W,C/L], Last Straw [W,C/H

Assumed to be roughly equal towashing needs of a Parabolic Troughplant as both have large mirror fields.

Number for PV washing requirmentsused for both large plants anddistributed gen (rooftop).

The Last Straw; AWEA Webs2006

Number for PV washing requirmentsused for both large plants anddistributed gen (rooftop).


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Low High Low High

CSP - Parabolic Trough System 2.94 3.14 2.94 3.14

CSP - Parabolic Dish-Engine System 0 0 0 0

CSP - Power Tower Plant 2.540 2.800 2.540 2.800

PV - Distributed (Rooftop) Systems 0.0038 0.114 0.004 0.114

PV - Large Centralized Plant 0.000 0.114 0.000 0.114

PV - Concentrating PV Systems 0 0 0 0


ConsumptiveWater

Requirement(m3/MWh)


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Water Requirements for Wind Power Production


WIND Withdrawal Consumption

m^3/MWh m^3/MWh


Cleaning medium sized wind farms 0 0.00379 0 0.00379

Cleaning large sized wind farms 0 0.00247 0 0.00247

Wind Power Production Method

Low High Low High

Medium sized wind farm 0.0000 0.0038 0.0000 0.0038

Large sized wind farm 0.0000 0.0025 0.0000 0.0025

If the wind turbines are never cleaned,then the withdrawal and consumptionequals zero

[W/L]: van Dam; [W/H]: AWEA2006; [C/L]: van Dam; [C/H]: AW2006

If the wind turbines are never cleaned,then the withdrawal and consumptionequals zeroWind farms can operate at 30% ofnameplate capacityIf washed, turbines are washed 3times/yearEach turbine uses 40 gallons perwashing

[W/L]: van Dam; [W/H]: J. Harris2006; [C/L]: van Dam; [C/H]: J.Harris 2006

WithdrawalWater

Requirement

(m3/MWh)

ConsumptiveWater

Requirement

(m3/MWh)


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Conversion of Units

Instructions: insert the value you have in the left box, and the coversion will be done automatically to r

Volume/energy unit Quick refe

130 gal/kWh = 492.0514762 m^3/MWh 1Energy

65 gal/MWh = 2.46E-01 m^3/MWh 1

1.00E+12

54 liters/kWh = 54 m^3/MWh 1

1.00E+18

1.16129 ft^3/MWs = 118.3983337 m^3/MWh 1 barrel cru

1 barrel cru

1302083 gal/MWd = 205.3500084 m^3/MWh 1

Volume

195 Mg/GJ = 7.02E+02 m^3/MWh 1

12.62E-06 ac-ft/kWh = 3.23E+00 m^3/MWh 1

1234

2.5E-011 m^3/J 9.00E-02 m^3/MWh 1

1

70 acre-ft/MWe = 8.64E+01 m^3/kW 1

45 km^3/10^18 J = 1.62E+02 m^3/MWh

64.516 m^3/10^12 J = 0.2323 m^3/MWh

4.32E-06 m^3/kWh = 1.20E-12 m^3/J

2000 kWh/megagallo = 0.52834 kWh/m^3

652 kWh/af 0.5285764 kWh/m^3


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ight box

rence/conversion

MW = 1000 kW

kWh = 3.60E+06 Joules

J = 2.78E+05 kWh

GJ = 277.8 kWh

J = 2.78E+11 kWh

de oil = 5.80E+06 Btu

de oil = 1.70E+03 kWh

J = 2.78E-07 kWh

m^3 = 1000 liters

m^3 = 264.2 gallons (U.S.)m^3 = 35.31 ft^3

m^3 = 1 acre-foot

km^3 = 1000000000 m^3

Mg (Million = 1 m^3

megagallon = 378.541178 m^3

Documents

Energy Water Work Book