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1December 2001 1 CHRISTENSEN ASSOCIATES
Real-Time Pricing and Related Successful Products
Michael T. O’SheasyVice PresidentChristensen Associates
2December 2001 2 CHRISTENSEN ASSOCIATES
What is Real-Time Pricing?
An electricity rate structure in which retail energy prices:
• vary frequently (e.g., hourly),
• with short notice (e.g., hour-ahead or day-ahead),
• to reflect expected hourly costs
3December 2001 3 CHRISTENSEN ASSOCIATES
Topics
Tenets of Real Time Pricing (RTP) RTP at Georgia Power Company Why does an RTP Product make sense (and
cents)? Features of a Two-Part RTP and resultant prices Price Response and Market Effects PPP and Portfolio Pricing Related Demand Response Products
4December 2001 4 CHRISTENSEN ASSOCIATES
Efficient RTP Pricing
1. To ration supply on anything other than price invites disaster. Price may not be the only solution but it is efficient because it recognizes that value is specific to consumers and dynamic.
5December 2001 5 CHRISTENSEN ASSOCIATES
Efficient RTP Pricing
2. Large social benefits can be achieved by offering dynamic pricing to larger customers (i.e. your grandmother need not be on RTP).
6December 2001 6 CHRISTENSEN ASSOCIATES
Efficient RTP Pricing
3. Efficient RTP pricing will inherently reorder competing players into cooperative teammates producing win-win solutions. One participant voluntarily forgoes consumption of a kWh while another participant eagerly consumes a kWh. The whole key here is that kWh value is not only user specific but dynamic in essence.
7December 2001 7 CHRISTENSEN ASSOCIATES
Electric Utility AtmosphereGeorgia Power Company Early ‘90’s
Competitive Electric Suppliers
Sufficient Base Load Capacity
Peaking Requirements in 1996
Short Run Marginal Cost < Average Embedded
Competitive Region
8December 2001 8 CHRISTENSEN ASSOCIATES
RTP Pilot Highlights
Customers say they want:– Greater control over their bill– Simpler, more straightforward rates– No demand ratchet or demand charge– True real time pricing
9December 2001 9 CHRISTENSEN ASSOCIATES
Prices based on hourly marginal cost will:– Send correct price signals that vary with time– Communicate true production and transmission
cost of electricity– Lower prices to customers in most hours– Lower GPC’s costs by increasing plant
utilization– Improve customer value and satisfaction
RTP Pilot Highlights
10December 2001 10 CHRISTENSEN ASSOCIATES
Tariff will contain 2 parts:– Access Charge
• Bridges gap between marginal revenue and embedded revenue requirements
• Insures revenue neutrality; protects non-participants (and GPC)
– Marginal prices vary by hour (from 2 cents to 25 cents per kWh in the first year)
RTP Pilot Highlights
11December 2001 11 CHRISTENSEN ASSOCIATES
RTP Pilot Highlights
Tariff is revenue neutral if customer makes no response
Test pilot provides experience while limiting risk– Up to 25 test customers and 25 control group
customers– 2 year duration– Measure customer response to varying prices
12December 2001 12 CHRISTENSEN ASSOCIATES
RTP Pilot Highlights
Summary– Responds to rate needs expressed by customers– GPC will research new innovation; EPRI will
participate– Large potential to benefit customers, State, and
GPC
13December 2001 13 CHRISTENSEN ASSOCIATES
RTP Pilot Objectives
Reduction in System and Customer Cost Increase Earnings Margins Increase System Reliability Improve Customer Satisfaction Feedback on Price Sensitivity
14December 2001 14 CHRISTENSEN ASSOCIATES
Real Time Pricing Pilot Program Details
Hourly dynamic prices follow the changing cost of power
Service is firm
Price is per kWh for each hour. No demand charge
Each day’s prices sent the previous day via electronic mail
Access charge for (or credit) assures revenue neutrality
15December 2001 15 CHRISTENSEN ASSOCIATES
RTP in the State of Georgia Year 2001
Largest Program in the World > 1600 Customers
– > 5,000 MW– > $1 billion revenue
IRP Resource Increasing Marginal Cost Day-Ahead and Hour-Ahead
16December 2001 16 CHRISTENSEN ASSOCIATES
Real-Time Pricing for GPC
Two-part tariff design Day-ahead RTP
– 250 kW minimum Hour-ahead RTP
– 5 MW minimum IRP Other rate design
17December 2001 17 CHRISTENSEN ASSOCIATES
GPC Philosophy on RTP
1. RTP is our marginal cost of producing electricity
• Lambda
• Losses
• Marginal Cost of Transmission
• Outage/ct Cost
• Risk Adder
18December 2001 18 CHRISTENSEN ASSOCIATES
2. GPC prefers low prices• Customers Satisfaction
• Economic Development
• Customer Choice
• Constant Profit Contribution per kWh
• Credits below CBL
GPC Philosophy on RTP
19December 2001 19 CHRISTENSEN ASSOCIATES
Product Characteristics Create Risk
Cost Risk Load Shape Risk
Expected
Ave ¢/KWH
Hours
Target Customers Load Shape
KW
Off Peak
Off Peak
On Peak
Target Customers Actual Load Shape
Target Customers Forecasted Load Shape
On peak and off peak prices* based upon forecasted load shape
On peak and off peak prices* based upon actual load shape
Hours
¢/KWH
TOU Prices
Scenarios
*Assume Actual Hourly Prices equal Forecasted Hourly Prices
20December 2001 20 CHRISTENSEN ASSOCIATES
Electricity Product Characteristics
Storage/Inventory Cost Volatility Historical Purchasing “rights” Transportation Constraints
21December 2001 21 CHRISTENSEN ASSOCIATES
Customer Risk Propensity Drives Portfolio Pricing
Flat and Blocked Energy Customer Energy Demand (CED) Hours Use of Demand (HUD) Time of Use (TOU) Interruptible Service (IS) Real Time Pricing (RTP)
22December 2001 22 CHRISTENSEN ASSOCIATES
Risk on Seller
100%, 100%
100%
100%0
•HUD
•CED
•TOU
•1 Part RTP
•2 Part RTP
•Curtailable EnergyLoad
Shape Risk on Seller
Cost Risk on Seller
•Flat Bill
•Flat Energy
24December 2001 24 CHRISTENSEN ASSOCIATES
Features of “Two-Part” RTP
Customer pays for a baseline level of usage (e.g., recent historical usage) at standard tariff prices
Differences in usage from the baseline (increases or decreases) are billed at RTP prices
25December 2001 25 CHRISTENSEN ASSOCIATES
Features of “Two-Part” RTP
Customer revenue neutral at baseline usage
Demand response benefits the RTP customer, the utility, and all other customers
26December 2001 26 CHRISTENSEN ASSOCIATES
Two-Part RTP Bill
Customer’s bills change from their “Standard” Bill only when they change their hourly loads from the “Baseline” load shape
RTPBill
=StandardBill
LoadHour
+ M.C.Hour
x
27December 2001 27 CHRISTENSEN ASSOCIATES
Implicit Contract Under Two-Part RTPPart One – Baseline load
• Payment for baseline load:Billed at standard tariff
CONTRACT
Current Tariff
@
1 24
Baseline Charge
kWh
28December 2001 28 CHRISTENSEN ASSOCIATES
Implicit Contract Under Two-Part RTP Part Two – Incremental load
• Incremental energy charge:Differences between baseline and actual usage are billed at RTP prices that reflect wholesale costs
CONTRACT
MarketPrice
@ IncrementalEnergy Charge
1 24
kWh
29December 2001 29 CHRISTENSEN ASSOCIATES
Example of Incremental Energy Charges (Relative to Baseline)
MWh
1 24
Actual load
Customer “sells” load at high RTP prices
Customer “buys” load at low RTP prices
CBL
Hour of Day
30December 2001 30 CHRISTENSEN ASSOCIATES
Summary of Two-Part RTP Structure
Customer buys their CBL at standard tariff prices according to mutually agreed upon contract
Customer buys or sells electricity (relative to the CBL) to suit their needs in each hour at prices based on a forecast of the wholesale market prices
31December 2001 31 CHRISTENSEN ASSOCIATES
How are RTP Prices Calculated?
Fuel plus variable O&M of incremental generator or a purchase (system lambda)
– Stable in most hours– Higher on high-load days
Losses between generator and customer meter
– Varies by hour– Greater in high-load and/or hot weather
32December 2001 32 CHRISTENSEN ASSOCIATES
How are RTP Prices Calculated?
Four (4) mills per kWh contribution to fixed costs
– Helps recover fixed costs– Compensates for risks– Protects non-participants
33December 2001 33 CHRISTENSEN ASSOCIATES
How are RTP Prices Calculated?
Incremental transmission cost– Occurs on summer weekday afternoons– Expect 200 to 300 hours per year– About 2-10 cents per kwh– Reflects transmission capital costs– Assigns costs to appropriate hours– Assigns costs to those causing it
Reliability (or scarcity) value– “Loss of load probability”– Realized in “capacity constrained” hours– Expect about 50 hours per year
34December 2001 34 CHRISTENSEN ASSOCIATES
Economy
Weather
Fuel Price
Unit Availability
Tie Lines
Wholesale Market
RTP RTP PricesPrices
Factors with Major Influence on RTP Prices
35December 2001 35 CHRISTENSEN ASSOCIATES
GPC’s RTP-DA Prices
*Hour at end of interval
HR* cent/kWh status
17 89.4200 A
18 49.5094 A
19 29.2998 A
20 8.2002 A
21 7.6772 A
22 5.2903 A
23 3.6407 A
24 3.2380 A
HR* cent/kWh status
01 3.1440 A
02 3.1151 A
03 2.9661 A
04 2.9329 A
05 2.9307 A
06 2.9384 A
07 2.9980 A
08 3.0449 A
HR* cent/kWh status
09 3.0531 A
10 3.6141 A
11 4.7617 A
12 5.2418 A
13 7.8890 A
14 39.1817 A
15 79.3005 A
16 109.7100 A
36December 2001 36 CHRISTENSEN ASSOCIATES
Events of Last July
Load Spot HA Price
Day Hour (MW) ($/MW) (¢ents)
7/30 1200 36,168 240 24.62
1300 37,600 430 48.56
1400 37,863 800 86.42
1500 37,592 106 18.20
1600 37,500 6300 642.66
1700 37,000 5200 527.68
1800 36,100 138 18.87
37December 2001 37 CHRISTENSEN ASSOCIATES
Do Customers Respond to RTP?Summary of Findings
Portion of customers found to respond significantly to RTP prices: 60-75%
Range of flexibility parameters: .01 - .40 (Approximately equal to negative of own-price elasticity)
A short-period price spike of 10 to 20 times the typical price can yield load reductions of 10 to 20% (e.g., 150 MW from 1,000 MW of load)
38December 2001 38 CHRISTENSEN ASSOCIATES
Typical Load Response
Increased Usage in All Hours
0:00 4:00 8:00 12:00 16:00 20:00 24:005
6
7
8
9
10
5
6
7
8
9
10
No Response in Low-Price Hours and Decreased Usage in High-Price Hours
(Peak Shavings)
0:00 4:00 8:00 12:00 16:00 20:00 24:00
Increased Usage In Low-Priced Hours and No Response in High-Price Hours(Hiding behind the Baseline Load)
0:00 4:00 8:00 12:00 16:00 20:00 24:00
5
6
7
8
9
10
Increased Usage in Low-Price HoursDecreased Usage in High-Price Hours
0:00 4:00 8:00 12:00 16:00 20:00 24:0056
7
8
9
10
39December 2001 39 CHRISTENSEN ASSOCIATES
Demand Profile
Tuesday
0
5000
10000
15000
20000
25000
30000
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
KW
DE
MA
ND
0
2
4
6
8
10
12
CE
NT
S/K
WH
Cents/kWh Actual kW CBL kW
40December 2001 40 CHRISTENSEN ASSOCIATES
Distribution of RTP Price Elasticities SIC 20 Food Products
0.000
0.050
0.100
0.150
0.200
0.250
0.300
0.350
0.400
0.450
0.500
1 3 5 7 9 11
13
15
17
19
21
23
25
27
29
31
33
35
37
39
41
43
45
47
49
51
53
55
57
41December 2001 41 CHRISTENSEN ASSOCIATES
Distribution of RTP Price Elasticities Commercial Office Buildings
0.000
0.050
0.100
0.150
0.200
0.250
0.300
0.350
0.400
0.450
0.500
1 3 5 7 9 11
13
15
17
19
21
23
25
27
29
31
33
35
37
39
41
43
45
47
49
51
42December 2001 42 CHRISTENSEN ASSOCIATES
Distribution of RTP Price Elasticities Schools and Universities
0.000
0.050
0.100
0.150
0.200
0.250
0.300
0.350
0.400
0.450
0.500
1 4 7 10
13
16
19
22
25
28
31
34
37
40
43
46
49
52
55
58
61
64
67
70
73
76
79
43December 2001 43 CHRISTENSEN ASSOCIATES
Distribution of RTP Price Elasticities Supermarkets
0.000
0.050
0.100
0.150
0.200
0.250
0.300
0.350
0.400
0.450
0.500
1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 47 49 51 53 55 57 59
44December 2001 44 CHRISTENSEN ASSOCIATES
0.60
0.70
0.80
0.90
1.00
1.10
1.20
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hour
Nor
mal
ized
Loa
d
0
2
4
6
8
10
12
14
16
Loga
rithm
of
Pric
e ($
/MW
)
Load at highest prices
Highest prices
Reference Load
Load at moderate prices
Reference prices
Moderate prices
RTP-DA Prices and Load Response, by Price Day-type
45December 2001 45 CHRISTENSEN ASSOCIATES
Price/Load Response
5
57
414
323
4242
132
92
Days
0
50
100
150
200
250
300
350
400
450
Loa
d R
esp
onse
(M
W)
RTP Price Load Response
RTP-DARTP-DA
46December 2001 46 CHRISTENSEN ASSOCIATES
0.00
0.20
0.40
0.60
0.80
1.00
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hour
No
rma
lize
d L
oa
d
0
4
8
12
16
20
Log
arith
m o
f P
(in
$/M
Wh)
Load at highest prices
Highest prices
Reference Load
Load at moderate prices
Reference prices
Moderate prices
RTP-HA Prices and Load Response, by Price Day-type
47December 2001 47 CHRISTENSEN ASSOCIATES
Price/Load Response
RTP-HARTP-HA
189168
190
319
450
232
Days
0
100
200
300
400
500
Loa
d R
esp
onse
(M
W)
RTP Price Load Response
48December 2001 48 CHRISTENSEN ASSOCIATES
Georgia Power’s RTP Load Response Modeldeveloped by Christensen Associates
January, 2001Prices ($/MWh):
Hour Index Hour Day-Ahead Hour-Ahead
1 12 am - 1 am 23 149 2 1 am - 2 am 22 57 3 2 am - 3 am 22 40 4 3 am - 4 am 22 24 5 4 am - 5 am 22 22 6 5 am - 6 am 22 22 7 6 am - 7 am 22 22 8 7 am - 8 am 23 22 9 8 am - 9 am 24 22 10 9 am - 10 am 38 28 11 10 am - 11 am 413 40 12 11 am - 12 pm 661 66 13 12 pm - 1 pm 1,000 102 14 1 pm - 2 pm 1,326 262 15 2 pm - 3 pm 1,445 280 16 3 pm - 4 pm 1,705 265 17 4 pm - 5 pm 1,791 259 18 5 pm - 6 pm 1,937 268 19 6 pm - 7 pm 1,784 255 20 7 pm - 8 pm 1,443 238 21 8 pm - 9 pm 1,181 217 22 9 pm - 10 pm 662 208 23 10 pm - 11 pm 465 199 24 11 pm - 12 am 344 202
Enter Time Period: July 16 - Aug 15
Enter Day Type: Monday
Maximum Temp (deg F): 95
Minimum Temp (deg F): 78
49December 2001 49 CHRISTENSEN ASSOCIATES
Predicted Load Change
Predicted Load Change Predicted Load Level Weather-Adjusted Reference Load Level
Hour Total RTP Hour Ahead Non-SE Ind Non-SE Com SE Ind SE Com On Site Ind On Site Com Total RTP Hour Ahead Non-SE Ind Non-SE Com SE Ind SE Com12 am - 1 am (124) (123) 1 1 0 (0) (3) 0 2,858 526 1,105 353 518 83 1 am - 2 am (49) (49) 1 1 0 (0) (2) 0 2,958 617 1,113 349 522 85 2 am - 3 am (29) (28) 1 1 0 (0) (2) 0 2,975 634 1,114 351 523 85 3 am - 4 am (9) (8) 1 1 0 (0) (2) 0 3,003 656 1,114 356 521 87 4 am - 5 am (6) (6) 1 1 0 (0) (2) 0 3,044 655 1,127 372 523 91 5 am - 6 am (5) (5) 1 1 0 (0) (2) 0 3,146 660 1,173 400 532 97 6 am - 7 am 57 22 7 10 8 2 6 1 3,307 676 1,241 437 552 104 7 am - 8 am 59 22 7 11 8 2 7 1 3,478 686 1,332 468 576 111 8 am - 9 am 61 23 8 12 9 2 6 1 3,600 688 1,382 505 588 118
9 am - 10 am 45 15 9 15 6 2 (2) 0 3,637 672 1,404 533 588 123 10 am - 11 am (197) 1 (57) 1 (82) (10) (40) (12) 3,453 675 1,356 535 505 114 11 am - 12 pm (300) (29) (82) (6) (110) (13) (45) (16) 3,367 647 1,335 535 479 111 12 pm - 1 pm (453) (83) (111) (25) (142) (18) (55) (19) 3,198 602 1,291 511 449 105 1 pm - 2 pm (575) (157) (129) (30) (160) (20) (58) (22) 3,095 529 1,286 508 434 102 2 pm - 3 pm (597) (164) (134) (32) (164) (21) (60) (22) 3,038 494 1,274 506 425 101 3 pm - 4 pm (619) (158) (144) (35) (175) (22) (61) (24) 2,991 506 1,246 496 411 99 4 pm - 5 pm (608) (147) (144) (35) (176) (22) (60) (23) 2,921 490 1,223 480 405 97 5 pm - 6 pm (613) (145) (146) (35) (182) (22) (60) (23) 2,833 481 1,184 460 398 93 6 pm - 7 pm (572) (134) (138) (31) (171) (20) (58) (19) 2,753 468 1,165 428 392 86 7 pm - 8 pm (525) (129) (123) (26) (157) (17) (56) (17) 2,755 474 1,168 413 405 81 8 pm - 9 pm (483) (123) (110) (22) (144) (15) (54) (15) 2,783 491 1,177 403 419 80
9 pm - 10 pm (387) (122) (77) (13) (107) (11) (47) (10) 2,866 498 1,212 397 455 81 10 pm - 11 pm (359) (130) (63) (9) (92) (9) (47) (9) 2,876 502 1,220 375 469 79 11 pm - 12 am (327) (133) (51) (6) (78) (8) (44) (7) 2,876 501 1,221 359 486 76
50December 2001 50 CHRISTENSEN ASSOCIATES
Implications for Demand-Side Strategies
market prices sensitive to demand at high demand levels (elasticity 12)
$70, Retail
Retail Demand
MWs
$400
$200
Supply
Demand response – e.g., RTP – an essential market feature
51December 2001 51 CHRISTENSEN ASSOCIATES
What Customers Like About RTP
Access to competitive market prices Low expected energy cost Certainty of cost of consumption changes
52December 2001 52 CHRISTENSEN ASSOCIATES
What Do Customers Think?
This chemical company’s threshold is around the 6¢/kWh range. At times they will “buy through” some higher priced hours when they have to meet a customer’s order. They love the rate.
This mining company responded heavily to pricing in July. When the price were over 20¢/kWh, they would curtail below their SE threshold by a couple of mW.
53December 2001 53 CHRISTENSEN ASSOCIATES
What Do Customers Think?
This paper manufacturer’s threshold is above 9¢/kWh for short periods. Their profit margins are low so they are fairly aggressive about saving money.
This mining company cranks up self generation when the price trend shows that the RTP price will be above 8-10 cents.
54December 2001 54 CHRISTENSEN ASSOCIATES
What Do Customers Think?
This wood product company break point is around 3.0 cents per kWh. At 3.0 cents or lower, they maximize RTP purchases. At 8.0 cents per kWh, they maximize self generation.
This aggressive commercial facilities manager cuts back florescent fixtures by 1/3, adjusts thermostat, reduces chillers in the afternoon, turns down water heating, and allows the temperature to float on chilled water loop.
55December 2001 55 CHRISTENSEN ASSOCIATES
Why Offer RTP?
Lowest priced product based upon sound risk principles
Provides a connection between wholesale and retail energy markets
– Retail prices reflect wholesale costs– Demand response to high prices provides
needed capacity relief and reduces wholesale prices
– Mitigates market power
56December 2001 56 CHRISTENSEN ASSOCIATES
Two-part feature provides:
– Customer bill stability at baseline usage levels– Conservation incentive on decrements
Why Offer RTP?
57December 2001 57 CHRISTENSEN ASSOCIATES
What Support Activities are Required for a Successful RTP Program
Reliable and accurate communication of prices
Strong customer support network; education on RTP
Limits on price risk
58December 2001 58 CHRISTENSEN ASSOCIATES
Wholesale Markets Employ Vehicles to Mitigate Risks
Few can tolerate the level of price risk; forwards and options essential to electric markets
PRIC
ES
DAYS
$140
$ 30
$ 18
SPOT
FORWARD
60December 2001 60 CHRISTENSEN ASSOCIATES
Price Protection Products
Allows RTP customer to manage RTP price risk and volatility
Financial hedge contracts that lock in a price for a specific time period
3 Types of CfDs (Contract for Differences):–Standard CfD–Range CfD–Limited CfD
61December 2001 61 CHRISTENSEN ASSOCIATES
Caps, Collars, Indexes Customer still benefits by reducing load in
response to high RTP prices in specific hours
Price Protection Products
62December 2001 62 CHRISTENSEN ASSOCIATES
Standard CfD
A CfD is a fixed price on GPC’s average offered RTP price over a specific time period. CfD is an acronym for Contract for Differences. No upfront premium is required. You select the Time Period and the amount of load to contract.
CfD
GPC pays Customer
Cen
ts/k
Wh
High Avg.
Low Avg.Customer pays GPC
63December 2001 63 CHRISTENSEN ASSOCIATES
Time Period July, All Hours
Contracted kW 1,000
# Hours 744
Contracted kWh 744,000
CfD Price 6.0 Cents/kWh
CfD Example:
64December 2001 64 CHRISTENSEN ASSOCIATES
Settlement for High Average Price: = (10.0-6.0) * 744,000 = $29,760. GPC pays Customer $29,760.
-OR-
Settlement for Low Average Price: = (4.0-6.0) * 744,000 = ($14,880). Customer pays GPC $14,880.
CfD Example:
65December 2001 65 CHRISTENSEN ASSOCIATES
“Range” CfD
GPC bills customers
Low Avg. Price
Max Payout Price
Very High Avg. PriceGPC pays customer
¢/kWh
“Range” CfD Price
Payout Range“Standard” CfD Price
Range CfDs are different from Standard CfDs in two ways. 1) Range CfDs have lower prices. 2) Range CfDs have a maximum payout price. The customer benefits from a lower price. And, payouts to the customer may only be made within the payout range as opposed to the Standard CfDs which have no upper boundary on the payout.
Range CfD Example
66December 2001 66 CHRISTENSEN ASSOCIATES
“Limited” CfD
Hourly RTP Prices
050
100150200250300350400450500
1 744Hour
Cen
ts/k
Wh
Protection is limited to hours in which the RTP price is less than a “RTP price limit”, e.g., $1/kWh.
Protection Limit
67December 2001 67 CHRISTENSEN ASSOCIATES
“Limited” CfD
Hourly RTP Prices < $1/kWh
050
100150200250300350400450500
1 744Hour
Cen
ts/k
Wh
Prices $1/kWh (100 cents/kWh) and greater are excluded from the settlement calculation.
TypeCfD
Price
Resultant Average
RTP Price SettlementStandard 6.00 6.60 (0.60)Ltd (< 1$) 5.00 5.70 (0.70)
Since the price protection does not include RTP prices of $1 or greater, the CfD price is lower. Here is a potential settlement comparison for a Standard CfD and a Limited CfD. () indicate a payment to the customer.
68December 2001 68 CHRISTENSEN ASSOCIATES
Summary of Products (Prices below are examples intended to be used only for illustration)
Type of Product CfD Price Difference from
“Standard”
“Standard” CfD = 6.0 ¢/kWh -
“Range” CfD = 5.5 ¢/kWh
Payouts only within range of average prices between 5.5 and 9.0 ¢/kWh.
“Limited” CfD = 5.0 ¢/kWh
Protection is limited to hours in which the price is < RTP Price Limit.
69December 2001 69 CHRISTENSEN ASSOCIATES
How Do They Work?
CapA Price Cap is a ceiling price on GPC’s average RTP price over a specific time period. You pay an upfront premium for the product. You select the Cap Price, the Time Period, and the amount of load to contract.
Cap
GPC pays Customer
Cen
ts/k
Wh
High Avg.
No Settlement Necessary for Low Average Price
70December 2001 70 CHRISTENSEN ASSOCIATES
How Do They work?
CollarA Collar is a Cap and a Floor price on GPC’s average RTP price over a specific time period. No upfront premium is required. Each Cap Price has a Floor Price associated with it. You select the Cap Price, the Time Period and the amount of load to contract.
Cap
GPC pays Customer
Cen
ts/k
Wh
High Avg.
Low Avg.Customer pays GPC
FloorNo Settlement Necessary
71December 2001 71 CHRISTENSEN ASSOCIATES
Real Time Pricing Summary Benefits Coupled with PPP
Participants– Provides industrial and commercial customers the
cost-based pricing they want and gives them more control over their bill and lower unit costs
Non-participants– Protects them from revenue erosion and benefits
them by allowing Utility to operate more efficiently at a lower cost to all ratepayers
72December 2001 72 CHRISTENSEN ASSOCIATES
Utility Company– Provides more efficient pricing and a more
competitive position State
– Attracts new business and rewards business expansion, resulting in increased employment and tax revenues.
Real Time Pricing Summary Benefits Coupled with PPP