Date post: | 16-Apr-2017 |
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Primary Focus:
Electricity Network Infrastructure
with a Clean Renewable Emphasis
RENEWABLE CHALLENGES WIND
SOLAR
WIND
HYDRO
BIOMASS
IDES-10 SIMULATION MODEL
WIND POWER RESULTS
WIND POWER RESULTS
30 year Lifecycle Cost Comparison of Wind Turbines of Various Sizes (1-9kW = 18m Tower & 10-12kW = 32m
Tower), with an Annual Average Wind Speed of: 6.63m/s, Assuming Surplus Generation (Grid Purchase - Wind-
power Exported) Sold at Different Fixed Prices
$200,000
$210,000
$220,000
$230,000
$240,000
$250,000
$260,000
$270,000
$280,000
$290,000
$300,000
123456789101112
Wind-turbine system size (kW)
Lifecycle cost over 30 years
Grid (Lifecycle)
No net-metering / exporting
Net-metered + 2.0c/kWh
Net-metered + 3.0c/kWh
Net-metered + 4.0c/kWh
Net-metered + 5.0c/kWh
PV MODEL PARAMETERSMONTH,M / YEAR,Y
SOLAR SETTING: MIN / AVG / MAX ?MINY
GRID PRICE OVER LIFETIME C/KWHSOLAR+GRID C/KWHSOLAR ONLY C/KWH
$0.1503$0.2443$0.3942
Annual Electricity ConsumptionLOAD PROFILES:22,202.32kWh/year
Maximum DemandHOUSE B8.57kW
DEMAND VARIABLE FACTORHOUSE C1(Multiple)
WHICH TYPE OF LOAD PROFILE ?HOUSE DBCD(Profile)
WHICH DEMAND REGION ? HOUSES B & C & Dch(Region) - ch only
WHICH WEATHER REGION ?REGIONS:KU(Region)
SOLAR SYSTEM SIZE (kW)CH=CHRISTCHURCH10kW
SOLAR SYSTEM LIFETIMEAU=AUCKLAND30Years
SOLAR SYSTEM COST FACTORKA=KAITAIA1(%/100)
SOLAR SYSTEM TOTAL COSTGI=GISBORNE$5,000$/kWNZ COST EST.$9,315
SOLAR SYSTEM EFFICIENCYNP=NEW PLYMOUTH0.12(%/100): e.g. 0.15 = 15%
GRID SUPPLY COST FACTORPN=PALMERSTON N1.00(%/100): e.g. 1.065 = 6.5% inc.
NET-METERING RETURN FACTORWE=WELLINGTON1(%/100):{0 to 1}
GRID SUPPLY INFLATION RATENE=NELSON1.00E-02(%/100): e.g. 0.02 = 2%, 1E-11 = 0%
Capital Interest Rate: 0, 5, 10 or 15%WP=WESTPORT7%
O&M Costs over lifetime: %capital costQU=QUEENSTOWN0.02(%/100): e.g. 0.02 = 2% capital cost
Capital Cost and Interest RepaymentDU=DUNEDIN20YearsBALANCE OF PAY
Payback Period (Fixed - calculated)IN=INVERCARGILLMORE THAN 40Years-$62,610
Return Over Lifetime (negative = loss)KU=KUMEROA-$62,609.73$-38.5%
TARIFF 1: DAY (07:00 - 22:30) - c/kWh10.2cents/kWh
TARIFF 2: NGT (23:00 - 06:30) - c/kWh8.8cents/kWh
TARIFF 3: FIXED - $/day0.745342466$/day
TARIFF 4: VARIABLE - cents/max KVA/day0cents/max KVA/day
TARIFF 5: EARLY PAY DISCOUNT0%
MICRO-HYDRO MODEL PARAMETERS MONTH,M / YEAR,Y
Hydro SETTING: MIN / AVG / MAX ?AVGY
GRID PRICE OVER LIFETIME C/KWHHydro+GRID C/KWHHydro ONLY C/KWH
$0.1288$0.1132$0.0733
Annual Electricity Consumption LOAD PROFILES:22,202.32kWh/year
Maximum Demand
HOUSE B
8.57kW
DEMAND VARIABLE FACTOR
HOUSE C
1(Multiple)AVERAGE FLOW RATE
WHICH TYPE OF LOAD PROFILE ?
HOUSE D
BCD(Profile)M3/S/YR0.068
WHICH DEMAND REGION ?
HOUSES B & C & D
ch(Region) - ch only
WHICH WEATHER REGION ?REGIONS:KU1(Region)Hydro Size Adjustment
Hydro SYSTEM SIZE (kW)
CH=CHRISTCHURCH
1.001.00009.5353Factor0%
Hydro SYSTEM LIFETIME (YEARS)
AU=AUCKLAND
30MAX KW / YRPEAK POTENTIAL KW
Hydro SYSTEM COST FACTOR
KA=KAITAIA
100%
Hydro SYSTEM TOTAL COST
GI=GISBORNE
$10,000per kW$15,402Available Head of Water
Average Hydro SYSTEM EFFICIENCY
NP=NEW PLYMOUTH
50%Total Capital CostHead (m)13.5
GRID SUPPLY COST FACTOR
PN=PALMERSTON N
1(%/100): e.g. 1.065 = 6.5% increase in Grid Price
NET-METERING RETURN FACTOR
WE=WELLINGTON
1(%/100):{0 to 1} CHOOSE TURBINE
GRID SUPPLY INFLATION RATE
NE=NELSON
1.00E-02(%/100): e.g. 0.02 = 2%: 1E-11 = 0% inflation NZ
Capital Interest Rate: 0, 5, 10 or 15%
WP=WESTPORT
7%
100% FLOW.
TURBINE TYPE
O&M Costs over lifetime: %capital cost
QU=QUEENSTOWN
0.02(%/100): 0.02 = 2% capital cost87%K = KAPLAN
Capital Cost and Interest Repayment
DU=DUNEDIN
20Years57%F = FRANCIS
Payback Period (Fixed - calculated)
IN=INVERCARGILL
20.46YearsRTN ON INVEST87%PR = PROPELLOR
Return Over Lifetime (negative = loss)
KU1=KUMEROA BASIC
$10,402.83$54.02%81%PE = PELTON
TARIFF 1: DAY (07:00 - 22:30) - c/kWh
KU2=KUMEROA DETAILED
10.2cents/kWh78%T = TURGO
TARIFF 2: NGT (23:00 - 06:30) - c/kWh 8.8cents/kWh79%CF = CROSSFLOW
TARIFF 3: FIXED - $/day 0.745342466$/day92%O = OTHER
TARIFF 4: VARIABLE - cents/max KVA/day 0cents/max KVA/day50%NZ = KIWI MAKE
TARIFF 5: EARLY PAY DISCOUNT 0%EFF.
% kWh (Delivered)PVWINDM/HCHPLifecycle Cost
0.00%0000$0
21.70%0010$21,882
43.30%0020$39,387
60.80%0030$52,516
71.90%0040$61,269
80.00%0050$65,645
81.80%0060$78,359
82.30%0070$90,936
84.00%0150$99,296
85.20%0160$112,010
87.20%0250$120,573
88.10%0260$133,287
89.70%0350$138,804
96.00%0061$155,276
98.40%0062$166,291
99.40%0063$174,803
99.80%0064$182,486
100.00%0065$189,842
OPTIMUM DG SIMULATION RESULTS
OPTIMUM DG SIMULATION RESULTS
TOTAL LOAD
HEAT-ENGINE MODEL PARAMETERSHEAT-ENGINEHEAT-ENGINE 222,023
GRID PRICE OVER LIFETIME C/KWH & GRID C/KWHONLY C/KWHHEAT CONST.HEATING LOAD
$0.1169$0.1140$0.21500.3192,966
Annual Electricity ConsumptionLOAD PROFILES:DOM222,023.23kWh/yearMISC LOAD
Maximum Demand
HOUSE B
85.69kW129,058
DEMAND VARIABLE FACTOR
HOUSE C
10(Multiple)SYS $ / KWDIESEL(DIE)
WHICH TYPE OF LOAD PROFILE ?
HOUSE D
BCD(Profile)$1,100NATURAL GAS(GAS)
WHICH DEMAND REGION ?
HOUSES B+C+D
ch(Region) - ch onlyCNG(CNG)
% HEAT INCREASE / DECREASE FACTOR (KUMEROA) -19%KW / UNITLPG(LPG)
TOTAL SIZE (kW)1kW1PETROL(PET)
OP CAPACITY100%BIOFUEL(BIO)
CAPITAL COST FACTOR1(%/100)HYDROGEN(HYD)
FUEL COST: CENTS/KWH (BEFORE CONVERSION) 4.8cents/kWhBIOFUEL TYPE
FUEL COST FACTOR1(%/100)
% HEAT RECOVERY90%: set at 100% for HEAT-ENGINE
HEAT RECOVERY COST$0.01$/kWh: set at 0$/kWh for HEAT-ENGINE
GRID SUPPLY COST FACTOR1(%/100): e.g. 1.065 = 6.5% increase in Grid Price
NET-METERING RETURN FACTOR1(%/100):{0 to 1}
GRID SUPPLY INFLATION RATE1.00E-02(%/100): e.g. 0.02 = 2%: 1E-11 = 0% inflation
FUEL SUPPLY INFLATION RATE1.00E-11(%/100): e.g. 0.02 = 2%: 1E-11 = 0% inflation
HEAT RECOVERY INFLATION RATE1.00E-11(%/100): e.g. 0.02 = 2%: 1E-11 = 0% inflation
Capital Interest Rate: 0, 5, 10 or 15% 7%20YRS LOAN REPAID
Lifetime: (set @ 40,000hours)40,000hours31.31LIFETIME IN YRS
Payback Period (Fixed - calculated)5.76YearsROI
Return Over Lifetime (negative = loss)$19,799.95$2.5%
O&M % OF CAPITAL
TARIFF 1: DAY (07:00 - 22:30) - c/kWh 10.2cents/kWh10%
TARIFF 2: NGT (23:00 - 06:30) - c/kWh 8.8cents/kWhNo.of UnitsCapacity
TARIFF 3: FIXED - $/day 0.745342466$/day1100% [Total: A+B]
TARIFF 4: VARIABLE - c/max KVA/dy 0c/max KVA/dy1100% [A capacity]
TARIFF 5: EARLY PAY DISCOUNT 0%00% [B capacity]
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Percentage Contribution
towards the Load
M/H:
500kW
M/H:
200kW
M/H: 100kWM/H:
100kW,
STR:
300kWh
WTG:
100kW
DSM:
500kWh,
WTG:
100kW
DSM:
500kWh,
WTG:
100kW,
SHW: 100x4
DSM:
500kWh,
WTG:
200kW,
SHW: 100x4
DSM:
500kWh,
PV: 100kW
DSM:
500kWh,
PV: 100kW,
CHP: 50kW
Scenario
10 Different Energy Supply and Demand Management Scenarios - Contributions to the Load
10
12345
6
789
10
12345
6
789
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Percentage Contribution
towards the Load
M/H: 500kWM/H: 200kWM/H: 100kWM/H: 100kW,
STR:
300kWh
WTG: 100kWDSM:
500kWh,
WTG: 100kW
DSM:
500kWh,
WTG: 100kW,
SHW: 100x4
DSM:
500kWh,
WTG:
200kW,
SHW: 100x4
DSM:
500kWh, PV:
100kW
DSM:
500kWh, PV:
100kW, CHP:
50kW
Scenario
10 Different Energy Supply and Demand Management Scenarios - Contributions to the Load
10.Grid Electricity
9.Energy Storage
8.Cogen Heating
7.Cogen Electricity
6.PV Electricity
5.Wind Electricity
4.Micro-hydro Electricity
3.Space Heating Reduction
2.Solar Water Heating
1.Energy Load Transfer
IDES SCENARIOS FOR 100 HOMES
IDES SCENARIOS FOR 100 HOMES
M/H: M/H: M/H: M/H: WIND: WIND: WIND: WIND: PV: PV:
500KW 200KW 100KW 100KW100KW100KW100KW200KW 100KW 100KW
STORE: DSM: DSM: DSM: DSM: DSM:
300KWH 500KWH 500KWH500KWH500KWH500KWH
SHW: SHW: CHP:
100X4m2 100X4m250KW
COST OF EACH IDES SCENARIO
COST OF EACH IDES SCENARIO
$0
$1,000,000
$2,000,000
$3,000,000
$4,000,000
$5,000,000
$6,000,000
$7,000,000
Cost of Energy Contributions
M/H: 500kWM/H: 200kWM/H: 100kWM/H: 100kW,
STR:
300kWh
WTG: 100kWDSM:
500kWh,
WTG: 100kW
DSM:
500kWh,
WTG:
100kW,
SHW: 100x4
DSM:
500kWh,
WTG:
200kW,
SHW: 100x4
DSM:
500kWh, PV:
100kW
DSM:
500kWh, PV:
100kW,
CHP: 50kW
Scenario
10 Different Energy Supply and Demand Management Scenarios - Contributions to Cost
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Percentage Contribution
towards the Load
M/H: 500kWM/H: 200kWM/H: 100kWM/H: 100kW,
STR:
300kWh
WTG: 100kWDSM:
500kWh,
WTG: 100kW
DSM:
500kWh,
WTG: 100kW,
SHW: 100x4
DSM:
500kWh,
WTG:
200kW,
SHW: 100x4
DSM:
500kWh, PV:
100kW
DSM:
500kWh, PV:
100kW, CHP:
50kW
Scenario
10 Different Energy Supply and Demand Management Scenarios - Contributions to the Load
10.Grid Electricity
9.Energy Storage
8.Cogen Heating
7.Cogen Electricity
6.PV Electricity
5.Wind Electricity
4.Micro-hydro Electricity
3.Space Heating Reduction
2.Solar Water Heating
1.Energy Load Transfer
10
12345
6
789
10
12345
6
789
M/H: M/H: M/H: M/H: WIND: WIND: WIND: WIND: PV: PV:
500KW 200KW 100KW 100KW100KW100KW100KW200KW 100KW 100KW
STORE: DSM: DSM: DSM: DSM: DSM:
300KWH 500KWH 500KWH500KWH500KWH500KWH
SHW: SHW: CHP:
100X4m2 100X4m250KW
GRID-ONLY REFERENCE
SIMULATIONS OPTIMIZER RESULTS
SIMULATIONS OPTIMIZER RESULTS
25-year Lifecycle Costs for Delivering a Certain Percentage of the Total Domestic kWh Requirement
$0
$100,000
$200,000
$300,000
$400,000
$500,000
$600,000
$700,000
0%10%20%30%40%50%60%70%80%90%100%
Percentage of Total Domestic kWh Energy Requirement Delivered
25-year Lifecycle Cost
Improving Return on Investment
The ROI from a 25 -year fixed-term loan is not the
optimum available for the ten scenarios described.
Fixed-term loans force repayment of borrowings
over longer periods than the minimum possible for
different scenarios.
This forces the borrower to pay extra interest and
reduces potential earnings (ROI) .
Revolving loans are the key to managing the
financial risks associated with energy supply from
distributed renewable generation .
-20%
-10%
0%
10%
20%
30%
40%
50%
60%
70%
Return on Investment (ROI) %
Scenario 1Scenario 2Scenario 3Scenario 4Scenario 5Scenario 6Scenario 7Scenario 8Scenario 9Scenario
10
Scenario Number
Comparison of the ROI for each Scenario using: (a) 25-year Fixed-Term Loan and (b) Flexible
Revolving Loan, with a 7% Capital Interest Rate and a 2% / Year Grid Price Increase
Fixed-Term
Revolving Loan
FIXED
FIXED
-
-
TERM VS. REVOLVING LOAN ROI
TERM VS. REVOLVING LOAN ROI
Revolving Loan Key Features
The Combines the transactional freedom of a
business operational account with a business loan.
Revenues generated by the business can be
deposited directly into this account, while
operational expenses can be withdrawn directly (at
the same time) up to a preset safety limit.
Provides flexibility with repaying and redrawing the
original business loan up to the safety limit, giving
the ability to reduce the loan faster.
Financial risks associated with daily fluctuations in
renewable energy supply and customer demand can
be easily managed by recalculating outstanding
interest payments on a daily basis.
REVOLVING LOAN BENEFITS
REVOLVING LOAN BENEFITS
0
5
10
15
20
25
Loan Repayment Period (Years)
Scenario 1Scenario 2Scenario 3Scenario 4Scenario 5Scenario 6Scenario 7Scenario 8Scenario 9
Scenario Number
Comparison of the Loan Repayment Period for each Scenario using: (a) 25-year Fixed-Term
Loan and (b) Flexible Revolving Loan, with a 7% Capital Interest Rate and a 2% / Year Grid
Price Increase
Fixed-Term
Revolving Loan
HYBRID GRID
HYBRID GRID
-
-
INTEGRATED MODELS
INTEGRATED MODELS
COST COMPONENT SYSTEM CAPACITY $AU COST FACTOR
TOTAL COST ON-SITE POWER N/A
NET LIFETIME GAIN (POWER ONLY) ON-SITE POWER 0.80
NET LIFETIME GAIN (CHP+WASTE UTILIZED) ON-SITE POWER N/A
NET LIFETIME GAIN (CHP) ON-SITE POWER 0.80
Value of wasted H2 produced if sold ON-SITE POWER 0.80
Value of wasted surplus wind power if sold ON-SITE POWER 0.80
Wind Turbine - BUY & INSTALL (KW) 231.4 0.80
Wind Turbine - O&M ON-SITE POWER 0.80
Wind Turbine Power Conditioner Capital Cost (KW) 219.5 0.80
Wind Turbine Power Conditioner O&M Cost (KW) ON-SITE POWER 0.80
H2 Production - Wind Power Cost ON-SITE POWER 0.80
Electrolyser H2 Production - BUY & INSTALL 1300.0 0.80
Electrolyser H2 Production - O&M ON-SITE POWER 0.80
H2 Compression & Storage (H2 CAP. - KWH) 1812.3 0.80
Wind load cost discount ON-SITE POWER 0.80
Fuel Cell (KW(ELECTRICITY)) - Capital Cost 200.0 0.80
Fuel Cell (KW(ELECTRICITY)) - O&M Cost ON-SITE POWER 0.80
Fuel Cell (KW(ELECTRICITY)) - Stack Replacement Cost ON-SITE POWER 0.80
Fuel Cell heat production (KW(HEAT)) 159.1 0.80
Fuel Cell Power Conditioner Capital Cost (KW) 189.8 0.80
Fuel Cell Power Conditioner O&M Cost (KW) ON-SITE POWER 0.80
Grid Purchase - line fixed cost ON-SITE POWER 0.80
Grid Purchase - line capacity cost (KW) 489.7 0.80
Grid Purchase - energy cost ON-SITE POWER 0.80
Dispersed Wind power delivery cost ON-SITE POWER 0.80
LIFECYCLE COST ($) % COST
-$12,593,822.90 -100.0%
-$3,036,486.39 -24.11%
-$3,036,486.39 -24.11%
-$3,036,486.39 -24.11%
$0.00 0.00%
$0.00 0.00%
-$381,947.41 -3.03%
-$42,438.60 -0.34%
-$57,287.22 -0.45%
-$26,203.30 -0.21%
$0.00 0.00%
-$1,931,879.82 -15.34%
-$723,612.87 -5.75%
-$161,321.00 -1.28%
$0.00 0.00%
-$1,320,000.00 -10.48%
-$614,609.13 -4.88%
-$880,000.00 -6.99%
$0.00 0.00%
-$51,955.31 -0.41%
-$24,191.07 -0.19%
$0.00 0.00%
$0.00 0.00%
-$6,378,377.18 -50.65%
$0.00 0.00%
(1) DEMAND FACTOR (MULTIPLIER) CAPITAL INTEREST (%) IMPORTANT:
1.00000 7.0% FUEL CELL
(2) DEMAND OFF-SET (IN KWHRS) TURBINE SIZE (kW) STACK REPLACED
-200.00 230.0 EVERY 5,000 HRS
SELECTED FUEL CELL H2 CAP. (KW) NO. OF TURBINES OF OPERATION
400.0 1 ONLY
FUEL CELL POWER CAP. FACTOR (AVG CAP. / MAX CAP.) TOWER HEIGHT (METRES)
2.9% 50 NOTE:
MAX. FUEL CELL H2 CAP. (KW) - REGRD SUPPLY SHORTFALL WIND SPEED MODIFIER (%) CAPACITY
401.8 0.0% SETTINGS FOR
SELECTED ELECTROLYSER POWER CAP. (KW) WIND SPEED (M/S) - CHECK HEIGHT BELOW FC, ELECTRO.,
1,300.0 7.35 H2 STORE MUST
ELECTROLYSER H2 CAP. FACTOR (AVG CAP. / MAX CAP.) WIND SPEED HEIGHT MEASUREMENT (METRES) NOT EXCEED MAX
5.5% 30.0 FC HRS / YEAR
MAX. ELECTROLYSER POWER CAP. (KW) AVG GRID / DIESEL ETC. PRICE (c/kWh) 525
211.1 25.00
SELECTED H2 ENERGY STORED (KWh) FIXED WIND SALES PRICE (c/kWh)
10,000.00 25.00
H2 ENERGY STORAGE CAP. FACTOR (AVG CAP. / MAX CAP.) TRANS. REBATE R.E.COST / KWH
3.4% 0.0% -$0.455
MAX. H2 ENERGY STORED (KWh) MAX DEMAND (kW)
1,812.3 479.94 LOAD FACTOR
H2 STORE & COMPRESS ($/kWh) MIN DEMAND (kW) 47%
$0.106 7.21
MAXIMUM GRID POWER (KW) ANNUAL DEMAND (kWh) % FROM R.E.s
472.7 1,966,743 34.7%
TOTAL GRID POWER REQUIRED / YEAR (KWH) TOTAL RE SUPPLY DELIVERED (KWH) % R.E. FROM H2
1,312,565 654,178 6.9%
TOTAL ANNUAL H2 PRODUCED (KWH) TOTAL ANNUAL H2 USED (KWH) % H2 UTILISED
95,288.8 95,288.8 100.0%
ANNUAL GRID INFLATION (%) LIFECYCLE COST W/O GRID
2.0% -$6,215,446
FUEL CELL POWER ($/kWh) GRID SAVED (LIFE)
$3,973,699
FUEL CELL HEAT SALES PRICE ($/kWh)
$0.00
FUEL CELL HEAT RECOVERY ($/kWh) CAP. COST W/O GRID (LIFE)
$0.00 -$4,784,391
H2 PRODUCED OVER LIFETIME (KWH)
1,905,776
W/O GRID POWER PURCHASE:
H2 WASTED OVER LIFETIME (KWH(H2) / LIFE) % CAP. / LIFECYCLE COSTS
0 77%
VALUE OF H2 WASTED ($/kWh) ECONOMIES OF SCALE
$0.00 DISCOUNT FACTOR FOR:
ANNUAL H2 PRICE INFLATION (%) FUEL CELL SYSTEM
-10.00% 1.00
LIFETIME VALUE OF H2 WASTED (NZ$) FUEL CELL STACKS
$0.00 1.00
SYSTEM LIFE-TIME (YEARS) REF. ECONOMIES OF SCALING
20 FACTOR FOR BOTH THE
SURPLUS WIND POWER WASTED (KWH / LIFE) FC SYSTEM AND STACKS
0.00 0.69
SURPLUS WASTED WIND PRICE (c/kWh)
0.00 STACK BUY DELAY
VALUE OF SURPLUS WIND POWER WASTED DISCOUNT FACTOR
$0.00 0.50
VALUE OF GRID POWER SUPPLIED BY RE / YR TIME FRAME:
$163,544 12
TOTAL ANNUAL H2 STORED (KWH) MONTHS FROM NOW
95,288.8 (FROM APR 2001)
COST COMPONENT SYSTEM CAPACITY $AU COST FACTOR
TOTAL COST ON-SITE POWER N/A
NET LIFETIME GAIN (POWER ONLY) ON-SITE POWER 0.80
NET LIFETIME GAIN (CHP+WASTE UTILIZED) ON-SITE POWER N/A
NET LIFETIME GAIN (CHP) ON-SITE POWER 0.80
Value of wasted H2 produced if sold ON-SITE POWER 0.80
Value of wasted surplus wind power if sold ON-SITE POWER 0.80
Wind Turbine - BUY & INSTALL (KW) 231.4 0.80
Wind Turbine - O&M ON-SITE POWER 0.80
Wind Turbine Power Conditioner Capital Cost (KW) 219.5 0.80
Wind Turbine Power Conditioner O&M Cost (KW) ON-SITE POWER 0.80
H2 Production - Wind Power Cost ON-SITE POWER 0.80
Electrolyser H2 Production - BUY & INSTALL 1300.0 0.80
Electrolyser H2 Production - O&M ON-SITE POWER 0.80
H2 Compression & Storage (H2 CAP. - KWH) 1812.3 0.80
Wind load cost discount ON-SITE POWER 0.80
Fuel Cell (KW(ELECTRICITY)) - Capital Cost 200.0 0.80
Fuel Cell (KW(ELECTRICITY)) - O&M Cost ON-SITE POWER 0.80
Fuel Cell (KW(ELECTRICITY)) - Stack Replacement Cost ON-SITE POWER 0.80
Fuel Cell heat production (KW(HEAT)) 159.1 0.80
Fuel Cell Power Conditioner Capital Cost (KW) 189.8 0.80
Fuel Cell Power Conditioner O&M Cost (KW) ON-SITE POWER 0.80
Grid Purchase - line fixed cost ON-SITE POWER 0.80
Grid Purchase - line capacity cost (KW) 489.7 0.80
Grid Purchase - energy cost ON-SITE POWER 0.80
Dispersed Wind power delivery cost ON-SITE POWER 0.80
LIFECYCLE COST ($) % COST
-$12,593,822.90 -100.0%
-$3,036,486.39 -24.11%
-$3,036,486.39 -24.11%
-$3,036,486.39 -24.11%
$0.00 0.00%
$0.00 0.00%
-$381,947.41 -3.03%
-$42,438.60 -0.34%
-$57,287.22 -0.45%
-$26,203.30 -0.21%
$0.00 0.00%
-$1,931,879.82 -15.34%
-$723,612.87 -5.75%
-$161,321.00 -1.28%
$0.00 0.00%
-$1,320,000.00 -10.48%
-$614,609.13 -4.88%
-$880,000.00 -6.99%
$0.00 0.00%
-$51,955.31 -0.41%
-$24,191.07 -0.19%
$0.00 0.00%
$0.00 0.00%
-$6,378,377.18 -50.65%
$0.00 0.00%
COST COMPONENT SYSTEM CAPACITY $AU COST FACTOR
TOTAL COST ON-SITE POWER N/A
NET LIFETIME GAIN (POWER ONLY) ON-SITE POWER 0.80
NET LIFETIME GAIN (CHP+WASTE UTILIZED) ON-SITE POWER N/A
NET LIFETIME GAIN (CHP) ON-SITE POWER 0.80
Value of wasted H2 produced if sold ON-SITE POWER 0.80
Value of wasted surplus wind power if sold ON-SITE POWER 0.80
Wind Turbine - BUY & INSTALL (KW) 231.4 0.80
Wind Turbine - O&M ON-SITE POWER 0.80
Wind Turbine Power Conditioner Capital Cost (KW) 219.5 0.80
Wind Turbine Power Conditioner O&M Cost (KW) ON-SITE POWER 0.80
H2 Production - Wind Power Cost ON-SITE POWER 0.80
Electrolyser H2 Production - BUY & INSTALL 1300.0 0.80
Electrolyser H2 Production - O&M ON-SITE POWER 0.80
H2 Compression & Storage (H2 CAP. - KWH) 1812.3 0.80
Wind load cost discount ON-SITE POWER 0.80
Fuel Cell (KW(ELECTRICITY)) - Capital Cost 200.0 0.80
Fuel Cell (KW(ELECTRICITY)) - O&M Cost ON-SITE POWER 0.80
Fuel Cell (KW(ELECTRICITY)) - Stack Replacement Cost ON-SITE POWER 0.80
Fuel Cell heat production (KW(HEAT)) 159.1 0.80
Fuel Cell Power Conditioner Capital Cost (KW) 189.8 0.80
Fuel Cell Power Conditioner O&M Cost (KW) ON-SITE POWER 0.80
Grid Purchase - line fixed cost ON-SITE POWER 0.80
Grid Purchase - line capacity cost (KW) 489.7 0.80
Grid Purchase - energy cost ON-SITE POWER 0.80
Dispersed Wind power delivery cost ON-SITE POWER 0.80
LIFECYCLE COST ($) % COST
-$12,593,822.90 -100.0%
-$3,036,486.39 -24.11%
-$3,036,486.39 -24.11%
-$3,036,486.39 -24.11%
$0.00 0.00%
$0.00 0.00%
-$381,947.41 -3.03%
-$42,438.60 -0.34%
-$57,287.22 -0.45%
-$26,203.30 -0.21%
$0.00 0.00%
-$1,931,879.82 -15.34%
-$723,612.87 -5.75%
-$161,321.00 -1.28%
$0.00 0.00%
-$1,320,000.00 -10.48%
-$614,609.13 -4.88%
-$880,000.00 -6.99%
$0.00 0.00%
-$51,955.31 -0.41%
-$24,191.07 -0.19%
$0.00 0.00%
$0.00 0.00%
-$6,378,377.18 -50.65%
$0.00 0.00%
(1) DEMAND FACTOR (MULTIPLIER) CAPITAL INTEREST (%) IMPORTANT:
1.00000 7.0% FUEL CELL
(2) DEMAND OFF-SET (IN KWHRS) TURBINE SIZE (kW) STACK REPLACED
-200.00 230.0 EVERY 5,000 HRS
SELECTED FUEL CELL H2 CAP. (KW) NO. OF TURBINES OF OPERATION
400.0 1 ONLY
FUEL CELL POWER CAP. FACTOR (AVG CAP. / MAX CAP.) TOWER HEIGHT (METRES)
2.9% 50 NOTE:
MAX. FUEL CELL H2 CAP. (KW) - REGRD SUPPLY SHORTFALL WIND SPEED MODIFIER (%) CAPACITY
401.8 0.0% SETTINGS FOR
SELECTED ELECTROLYSER POWER CAP. (KW) WIND SPEED (M/S) - CHECK HEIGHT BELOW FC, ELECTRO.,
1,300.0 7.35 H2 STORE MUST
ELECTROLYSER H2 CAP. FACTOR (AVG CAP. / MAX CAP.) WIND SPEED HEIGHT MEASUREMENT (METRES) NOT EXCEED MAX
5.5% 30.0 FC HRS / YEAR
MAX. ELECTROLYSER POWER CAP. (KW) AVG GRID / DIESEL ETC. PRICE (c/kWh) 525
211.1 25.00
SELECTED H2 ENERGY STORED (KWh) FIXED WIND SALES PRICE (c/kWh)
10,000.00 25.00
H2 ENERGY STORAGE CAP. FACTOR (AVG CAP. / MAX CAP.) TRANS. REBATE R.E.COST / KWH
3.4% 0.0% -$0.455
MAX. H2 ENERGY STORED (KWh) MAX DEMAND (kW)
1,812.3 479.94 LOAD FACTOR
H2 STORE & COMPRESS ($/kWh) MIN DEMAND (kW) 47%
$0.106 7.21
MAXIMUM GRID POWER (KW) ANNUAL DEMAND (kWh) % FROM R.E.s
472.7 1,966,743 34.7%
TOTAL GRID POWER REQUIRED / YEAR (KWH) TOTAL RE SUPPLY DELIVERED (KWH) % R.E. FROM H2
1,312,565 654,178 6.9%
TOTAL ANNUAL H2 PRODUCED (KWH) TOTAL ANNUAL H2 USED (KWH) % H2 UTILISED
95,288.8 95,288.8 100.0%
ANNUAL GRID INFLATION (%) LIFECYCLE COST W/O GRID
2.0% -$6,215,446
FUEL CELL POWER ($/kWh) GRID SAVED (LIFE)
$3,973,699
FUEL CELL HEAT SALES PRICE ($/kWh)
$0.00
FUEL CELL HEAT RECOVERY ($/kWh) CAP. COST W/O GRID (LIFE)
$0.00 -$4,784,391
H2 PRODUCED OVER LIFETIME (KWH)
1,905,776
W/O GRID POWER PURCHASE:
H2 WASTED OVER LIFETIME (KWH(H2) / LIFE) % CAP. / LIFECYCLE COSTS
0 77%
VALUE OF H2 WASTED ($/kWh) ECONOMIES OF SCALE
$0.00 DISCOUNT FACTOR FOR:
ANNUAL H2 PRICE INFLATION (%) FUEL CELL SYSTEM
-10.00% 1.00
LIFETIME VALUE OF H2 WASTED (NZ$) FUEL CELL STACKS
$0.00 1.00
SYSTEM LIFE-TIME (YEARS) REF. ECONOMIES OF SCALING
20 FACTOR FOR BOTH THE
SURPLUS WIND POWER WASTED (KWH / LIFE) FC SYSTEM AND STACKS
0.00 0.69
SURPLUS WASTED WIND PRICE (c/kWh)
0.00 STACK BUY DELAY
VALUE OF SURPLUS WIND POWER WASTED DISCOUNT FACTOR
$0.00 0.50
VALUE OF GRID POWER SUPPLIED BY RE / YR TIME FRAME:
$163,544 12
TOTAL ANNUAL H2 STORED (KWH) MONTHS FROM NOW
95,288.8 (FROM APR 2001)
(1) DEMAND FACTOR (MULTIPLIER) CAPITAL INTEREST (%) IMPORTANT:
1.00000 7.0% FUEL CELL
(2) DEMAND OFF-SET (IN KWHRS) TURBINE SIZE (kW) STACK REPLACED
-200.00 230.0 EVERY 5,000 HRS
SELECTED FUEL CELL H2 CAP. (KW) NO. OF TURBINES OF OPERATION
400.0 1 ONLY
FUEL CELL POWER CAP. FACTOR (AVG CAP. / MAX CAP.) TOWER HEIGHT (METRES)
2.9% 50 NOTE:
MAX. FUEL CELL H2 CAP. (KW) - REGRD SUPPLY SHORTFALL WIND SPEED MODIFIER (%) CAPACITY
401.8 0.0% SETTINGS FOR
SELECTED ELECTROLYSER POWER CAP. (KW) WIND SPEED (M/S) - CHECK HEIGHT BELOW FC, ELECTRO.,
1,300.0 7.35 H2 STORE MUST
ELECTROLYSER H2 CAP. FACTOR (AVG CAP. / MAX CAP.) WIND SPEED HEIGHT MEASUREMENT (METRES) NOT EXCEED MAX
5.5% 30.0 FC HRS / YEAR
MAX. ELECTROLYSER POWER CAP. (KW) AVG GRID / DIESEL ETC. PRICE (c/kWh) 525
211.1 25.00
SELECTED H2 ENERGY STORED (KWh) FIXED WIND SALES PRICE (c/kWh)
10,000.00 25.00
H2 ENERGY STORAGE CAP. FACTOR (AVG CAP. / MAX CAP.) TRANS. REBATE R.E.COST / KWH
3.4% 0.0% -$0.455
MAX. H2 ENERGY STORED (KWh) MAX DEMAND (kW)
1,812.3 479.94 LOAD FACTOR
H2 STORE & COMPRESS ($/kWh) MIN DEMAND (kW) 47%
$0.106 7.21
MAXIMUM GRID POWER (KW) ANNUAL DEMAND (kWh) % FROM R.E.s
472.7 1,966,743 34.7%
TOTAL GRID POWER REQUIRED / YEAR (KWH) TOTAL RE SUPPLY DELIVERED (KWH) % R.E. FROM H2
1,312,565 654,178 6.9%
TOTAL ANNUAL H2 PRODUCED (KWH) TOTAL ANNUAL H2 USED (KWH) % H2 UTILISED
95,288.8 95,288.8 100.0%
ANNUAL GRID INFLATION (%) LIFECYCLE COST W/O GRID
2.0% -$6,215,446
FUEL CELL POWER ($/kWh) GRID SAVED (LIFE)
$3,973,699
FUEL CELL HEAT SALES PRICE ($/kWh)
$0.00
FUEL CELL HEAT RECOVERY ($/kWh) CAP. COST W/O GRID (LIFE)
$0.00 -$4,784,391
H2 PRODUCED OVER LIFETIME (KWH)
1,905,776
W/O GRID POWER PURCHASE:
H2 WASTED OVER LIFETIME (KWH(H2) / LIFE) % CAP. / LIFECYCLE COSTS
0 77%
VALUE OF H2 WASTED ($/kWh) ECONOMIES OF SCALE
$0.00 DISCOUNT FACTOR FOR:
ANNUAL H2 PRICE INFLATION (%) FUEL CELL SYSTEM
-10.00% 1.00
LIFETIME VALUE OF H2 WASTED (NZ$) FUEL CELL STACKS
$0.00 1.00
SYSTEM LIFE-TIME (YEARS) REF. ECONOMIES OF SCALING
20 FACTOR FOR BOTH THE
SURPLUS WIND POWER WASTED (KWH / LIFE) FC SYSTEM AND STACKS
0.00 0.69
SURPLUS WASTED WIND PRICE (c/kWh)
0.00 STACK BUY DELAY
VALUE OF SURPLUS WIND POWER WASTED DISCOUNT FACTOR
$0.00 0.50
VALUE OF GRID POWER SUPPLIED BY RE / YR TIME FRAME:
$163,544 12
TOTAL ANNUAL H2 STORED (KWH) MONTHS FROM NOW
95,288.8 (FROM APR 2001)
HYBRID GRID
HYBRID GRID
-
-
INTEGRATED
INTEGRATED
ROTTNEST SITE ASSUMPTIONS
ROTTNEST SITE ASSUMPTIONS
1,966,743kWh
1,966,743kWh
ANNUAL DEMAND (kW)
ANNUAL DEMAND (kW)
7.21kW
7.21kW
MIN DEMAND (kW)
MIN DEMAND (kW)
479.94kW
479.94kW
MAX DEMAND (kW)
MAX DEMAND (kW)
7.35m/s
7.35m/s
AVERAGE ANNUAL WIND SPEED (M/S)
AVERAGE ANNUAL WIND SPEED (M/S)
65m (600kW) or 50m
65m (600kW) or 50m
(230kW)
(230kW)
TOWER HEIGHT (METRES)
TOWER HEIGHT (METRES)
7%
7%
CAPITAL INTEREST (%)
CAPITAL INTEREST (%)
25kW
25kW
200kW
200kW
FUEL CELL SIZE ( KW (ELECTRIC) )
FUEL CELL SIZE ( KW (ELECTRIC) )
1,000kWh
1,000kWh
10,000kWh
10,000kWh
HYDROGEN STORAGE SIZE ( KWH (H2) )
HYDROGEN STORAGE SIZE ( KWH (H2) )
100kW
100kW
1,300kW
1,300kW
ELECTROLYSER SIZE ( KW ( ELECTRIC) )
ELECTROLYSER SIZE ( KW ( ELECTRIC) )
1 x 600kW or 8 x 230kW
1 x 600kW or 8 x 230kW
WIND TURBINE CAPACITY (KW)
WIND TURBINE CAPACITY (KW)
1.00
1.00
FUEL CELL ECONOMIES OF SCALING FACTOR APPLIED
FUEL CELL ECONOMIES OF SCALING FACTOR APPLIED
12
12
SYSTEM PURCHASED X MONTHS FROM APRIL 2001
SYSTEM PURCHASED X MONTHS FROM APRIL 2001
20
20
SYSTEM LIFE
SYSTEM LIFE
-
-
TIME (YEARS)
TIME (YEARS)
1,966,743kWh
1,966,743kWh
ANNUAL DEMAND (kW)
ANNUAL DEMAND (kW)
7.21kW
7.21kW
MIN DEMAND (kW)
MIN DEMAND (kW)
479.94kW
479.94kW
MAX DEMAND (kW)
MAX DEMAND (kW)
7.35m/s
7.35m/s
AVERAGE ANNUAL WIND SPEED (M/S)
AVERAGE ANNUAL WIND SPEED (M/S)
65m (600kW) or 50m
65m (600kW) or 50m
(230kW)
(230kW)
TOWER HEIGHT (METRES)
TOWER HEIGHT (METRES)
7%
7%
CAPITAL INTEREST (%)
CAPITAL INTEREST (%)
25kW
25kW
200kW
200kW
FUEL CELL SIZE ( KW (ELECTRIC) )
FUEL CELL SIZE ( KW (ELECTRIC) )
1,000kWh
1,000kWh
10,000kWh
10,000kWh
HYDROGEN STORAGE SIZE ( KWH (H2) )
HYDROGEN STORAGE SIZE ( KWH (H2) )
100kW
100kW
1,300kW
1,300kW
ELECTROLYSER SIZE ( KW ( ELECTRIC) )
ELECTROLYSER SIZE ( KW ( ELECTRIC) )
1 x 600kW or 8 x 230kW
1 x 600kW or 8 x 230kW
WIND TURBINE CAPACITY (KW)
WIND TURBINE CAPACITY (KW)
1.00
1.00
FUEL CELL ECONOMIES OF SCALING FACTOR APPLIED
FUEL CELL ECONOMIES OF SCALING FACTOR APPLIED
12
12
SYSTEM PURCHASED X MONTHS FROM APRIL 2001
SYSTEM PURCHASED X MONTHS FROM APRIL 2001
20
20
SYSTEM LIFE
SYSTEM LIFE
-
-
TIME (YEARS)
TIME (YEARS)
Projected Cost Variables
With regard to future price projections, models and
algorithms have been developed which consider
historical fuel prices, the consumer price index and other
associated inflation reflective indices, historical
electricity prices, production progress cost reductions,
economies of production, and economies of scale .
The production progress cost reduction is associated
with learning/progress curves.
A learning curve describes the phenomenon by which the
time per cycle to perform a particular task decreases as
the number of repetitions of the task increases.
Typically, the effect is strongest when a single product is
produced in a single factory by the same manufacturer).
Economies of Manufacturing,
Economies of Scale
Economies of manufacturing or production
represent another means by which per unit
production costs can be reduced, and are not
necessarily directly related to production progress
curves. This type of cost reduction is a function of
the production rate, which allows the plant to
leverage indirect costs more efficiently.
Economies of scale cost reductions are based on
real manufacturers costs per unit projections for
bulk orders of different modular technologies, and
costs per kW projections for modules of increasing
size.
Summary of Model Functions and
Capabilities: Resource Data
Regionalrenewable energy data input solar, wind,
hydro, biomass or fuel resource supply data for any
region in the country, from a single house location
to a region or an island or the entire country.
Regional historical renewable energy resource
analysis this uses whatever historical data is
available to determine the best and worst case
scenarios over a system s lifetime.
Renewable energy resource type especially solar,
wind, hydro and biomass in annual, monthly, daily,
hourly or half -hourly increments.
Type of load profile any type of demand profile may
be used, and the shape and size of this profile may be
modified in the model.
Size of load profile any size can be modelled.
Regional load profile data individual household,
cluster of houses, commercial business, industrial
complex, GXP demand level, or aggregated GXP
demand level up to total national demand level.
Summary of Model Functions and
Capabilities: Profile Data
Summary of Model Functions and
Capabilities: Cost Data
Type of Capital cost (including installation where
necessary) and interest repayment period include
amortized costingsfor any time period and any interest rate
and loan.
Scale-adjusted capital cost any adjustment can be
considered.
O&M cost considered as a percentage of the capital
purchase cost or the capital and installation cost or as a
cents/kWh value for fuel -driven DES applications etc.
Lifecycle cost considering capital purchase, installation,
O&M, labour, and any other fixed and running costs
applicable.
Summary of Model Functions and
Capabilities: Grid Supply Data
Grid supply cost, including for example, the following options:
Six 4-hourly weekday energy tariffs and six 4 -hourly weekend tariffs,
half-hourly wholesale GXP prices, fixed and variable line charges,
Average line replacement costs, average line operating and
maintenance costs,
Maximum distribution capacity costs, coincident distribution cap acity
costs, metering costs, average retail, distribution and transmis sion
costs for different network regions,
Variable electricity price inflation rates and fuel price inflat ion rates,
transmission capacity reduction rebates,
Variable DES tariffs which are independent of the grid supply co sts,
consideration of on -site and dispersed power production issues with
respect to both grid supply and DES supply,
And export-metering factor to account for variable
returns from exporting surplus electricity generated
back to the grid.
Examples of Grid Supply Costs
Average charges for the consumer group: e.g.
10cents/kWh, anytime.
True multi-part tariffs (with separate fixed, variable
and TOU charges): e.g. (a) domestic tariff; and, (b)
industrial tariff:
MANAGING VARIABLE HEAT SUPPLY
MANAGING VARIABLE HEAT SUPPLY
(AN EXAMPLE)
(AN EXAMPLE)
Typical IDES Winter Heat Load Profile for a Community
0
20
40
60
80
100
120
140
160
180
0:001:303:004:306:007:309:00
10:3012:0013:3015:0016:3018:0019:3021:0022:30
Time of Day
Energy Supply (kWh)
Cogen (Heat)
Solar Hot Water
Conservation
IDES Planning Process
Collect reliable data on electricity use patterns,
resource data and technical options for improving
energy efficiency or load profiles.
Project future energy requirements.
Calculate the costs and electrical -load impacts of
the demand -side options.
Design an optimum integrated distributed supply
plan that satisfies least -cost economic and
environmental impacts.
Compare the costs with the impacts of
conventional electricity supply options.
Implement the least -cost strategy.
IDES Definition
An Integrated Distributed Energy System is a distributed
electrical energy system which services a local energy load,
and is connected in parallel to a conventional supply (which
may be a grid supplied distribution system, or a diesel
gensetetc. It may include electrical generation and heat
capture, and electrical and heat storage.
The four key characteristics of IDES are they are:
Integratedembedding renewable and sustainable supply
technologies with existing infrastructure.
Distributedmatching small-scale supply and use (