Catch a recording of the webinar here: http://www.energycentral.com/events/26390/Smart-Power-Generation
Slides by Joseph Ferrari, MSEng, MS-NR, Business Development Analyst, Wärtsilä North America Inc., and Alan Roark, Manager of Risk Assessments, DNV KEMA Energy & Sustainability.
Presented on October 17th, 2012.
7. Impact on Thermal Dispatch
Most volatile (Low load) 20% Wind
Wind
GTCC
1 week
Coal cycling
GTCC deep turndown, cycling
New England Wind Integration Study
http://www.iso-ne.com/committees/comm_wkgrps/prtcpnts_comm/pac/reports/2010/newis_report.pdf
8. Uncertainty, Day Ahead vs. Real Time
Real Time Wind
Day Ahead Wind
Difference
Source: IMM Quarterly Report Summer 2011:
https://www.midwestiso.org/Library/Repository/Report/IMM/2011%20IMM%20Quarterly%20Report%20Summer%20Final
.pdf
21. Quantifying Smart Power Generation Benefits
DNV KEMA Energy & Sustainability
October 17, 2012
22. Our Global Experience of Professionals in Energy and Sustainability
provide Insight across the Energy Value Chain
Policy & Transport &
Production Trading Use
Strategy Distribution
Our passionate professionals work in multidisciplinary teams to enable our
customers in finding the optimal solutions.
Their impartiality, high-level expertise, and experience are widely recognized.
They understand the business consequences of a technical decision and the
technical consequences of a business decision.
They are present at major conferences and seminars and participate in
international advisory boards, associations, and standardization bodies to share
knowledge and stimulate innovative thinking.
Enabling the energy transition
22
23. SPG Study Focus
As the amount of renewable generation increases, the need for
Ancillary Services will increase:
- We focus on both generation cost and ancillary services
We decided to use CAISO as a study system
- well-developed market that shares many features with other ISOs/RTOs-
increased renewable penetration, retirements of GW of capacity
- In CAISO Ancillary Services includes load following (up and down),
regulation (up and down) spinning and non-spinning
Enabling the energy transition
23
24. SPG Study Scenarios: CAISO 2020
To analyze CAISO we used the WECC model (and isolated the impacts on
CAISO).
- We used CPUC and CAISO LTPP projections for the Base Case (Environmentally
constrained case + High Load scenario)
- We focus on comparing 5.5 GW of new and Once Through Cooling (OTC)
repowered with 5.5 GW of gas turbines in simple and combined cycle (scenario 1,
the “base case”). These are the “OTC replacement” units.
We then explored several scenarios of changing out or adding to the new or
OTC replacement units with Wärtsilä SPG.
Today we’ll focus on one of the scenarios (Scenario 4).
- In this scenario we added 3.2 GW of Flexicycle and 2.3 GW of Wärtsilä 34SGs in
addition to the already included 3.2 GW of GTCCs and 2.3 GW of simple cycle
GTs.
- We allowed the dispatch software to pick/choose the most appropriate dispatch
sequence to meet the load projections for CAISO 2020 with 33% renewable
penetration.
Enabling the energy transition
24
25. Scenarios to Highlight SPG Benefits in 2020
Scenario 1: Base Case
- Environmentally constrained generation asset assumptions
- Includes 5,517 MW of new and Once Through Cooling (OTC) re-powered assets
- High Load sensitivity case
Scenario 2: SPG in Simple Cycle instead of new and OTC
- Base Case assumptions, except
- Instead of 5,517 MW of new and OTC re-powered assets use 5,500 MW of simple cycle SPG
Scenario 3: SPG mix instead of new and OTC
- Base Case assumptions, except
- Instead of 5,517 MW of new and OTC re-powered assets use 3,300 MW of combined cycle SPG and
2,200 MW of simple cycle SPG
Scenario 4: Optimal Mix of new and OTC with SPG
- Base Case assumptions, and
- Add 3,300 MW of combined cycle SPG and 2,200 MW of simple cycle SPG
Enabling the energy transition
25
26. Smart Power Generation – Deployed in concert with other energy
resources, enhances the grid and provides other benefits….
Peak Hour Supply
Measuring benefits of Flexible Capacity in
70,000
Load + Flexibility = 64,254 MW
60,000
Load = 56,018 MW
North American RTO (CAISO) 50,000 Imports = 10,474 MW
Import(+)/Export(-)
- Net savings in generation costs are about 5% 40,000
New OTC = 4,157 MW New OTC Gens
Gas
- Reserve margins can be managed at lower costs
MW
Nat Gas = 14,764 MW Hydro
Wind
30,000
Solar
Hydro = 7,523 MW Other
20,000 Nuclear
Wind = 1,147 MW
Minimizing cost of providing Ancillary Services
Load + Flexibility
Solar = 8,776 MW
10,000
Other = 4,575 MW
New OTC = re-
in an RTO (CAISO) 0
Nuclear = 4,486
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
powered Once-
Through-Cooling
capacity which is gas
fired.
- Regulation (Up and Down) Hour
- Load Following (Up and Down)
- Spinning
- Non-Spinning
Determining how Smart Power Generation
plays in concert in a Resource Portfolio
- SPG competes in different markets against
different resources
- Resource adequacy improves
Enabling the energy transition
26
27. Trends faced by North American RTOs
Renewable Portfolio Standards
Thermal plant retirements and additions
Environmental restrictions on siting new plants and operations of existing
plants
Increased demand response and distributed resources
Changing Power Flows and High levels of import/export activity
Enabling the energy transition
27
28. Time Domains for SPG Benefits in Frequency Control/Ancillary
Services in an Uncertain Portfolio
Seconds Inertia
Primary Governor Response
Control
SPG strengths
Secondary Minutes
Regulation
Control
Tertiary Minutes
Economic Dispatch
Control
Flex Ramp
Time Hours
Supply Stack
Control
10 minutes
Spinning Reserve Contingency
30 minutes Reserve
Non-Spinning Reserve
Minutes
Forecast Error
Load Following
Enabling the energy transition
28
29. Scenario 1: Base Case Capacity Mix to Meet Peak Load and
Flexibility in 2020
Peak Hour Supply
70,000
Load + Flexibility = 64,254 MW
60,000
Load = 56,018 MW Flexibility:
Spinning & Load
50,000 Imports = 10,474 MW Following Up:
Import(+)/Export(-) 49% supplied
New OTC = 4,157 MW New OTC Gens by existing CCGT
40,000 Gas
Regulation UP:
MW
Nat Gas = 14,764 MW Hydro
38% supplied by
Wind
30,000 hydro; 38% supplied
Solar by OTC CT
Hydro = 7,523 MW Other
20,000 Nuclear During peak hour,
Wind = 1,147 MW
Load + Flexibility Demand Response
Solar = 8,776 MW
Provided portions.
10,000
Other = 4,575 MW
New OTC = re-
Nuclear = 4,486 powered Once-
0 Through-Cooling
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 capacity which is gas
fired.
Hour
Enabling the energy transition
29
30. Scenario 1: Base Case Has Substantial Increase in Energy and
Ancillary Services in 2020; SPG reduces Costs
2020 Base Case
2011 2020 Base
Ancillary Case + SPG
Ancillary + $158 Services =
Costs in Millions $
Services met by CT - $33 Ancillary
= $139 backstop* = Services
$381 = $348
Generation 5%
Cost = Generation Generation
$8,061 - $1,359 Cost = - $349 Cost =
$6,702 $6,351
Gas Gas Gas
OTC
60%
Ancillary Services
0%
target GWh and
Hydro CT Backstop
Hydro
suppliers
A/S = 45,687 GWh OTC
SPG
Hydro
A/S 72,662 GWh A/S 72,662 GWh
*Sources: 2011 State of Market Report, LTPP assumptions, simulation results. Using the Demand Response
backstop costing on average $17,500/MWh and with shortfall penalties the cost is $1,2 billion for the base case.
Enabling the energy transition
30
31. Scenario 1: Base Case with Demand Response supplying Ancillary
Service Shortfall at $17,500/MWh
2020 Base Case
2011 2020 Base
Ancillary
Case + SPG
Ancillary + $1,062 Services
Costs in Millions $
Services - $777 Ancillary
= $139 = $1,201 Services
= $348
Generation 15%
Cost = Generation Generation
$8,061 - $1,359 Cost = - $349 Cost =
$6,702 $6,351
Gas Gas Gas
OTC
60%
Ancillary Services
0%
target GWh and
Hydro Demand Response
Hydro
suppliers
A/S = 45,687 GWh OTC
SPG
Hydro
A/S 72,662 GWh A/S 72,662 GWh
*Sources: 2011 State of Market Report, LTPP assumptions, simulation results
Enabling the energy transition
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32. SPG Cost Savings in RTD: Peak Hour Day
Scenario 1 RTD: Base Case Scenario 2 RTD: All Generators
8 41% savings
by:
7 • Reducing
high cost
6
Demand
$/MW for 5 minute interval
Response
5
• Cheaper
4
start/stop and
ramping
3
2
1
0
100
109
118
127
136
145
154
163
172
181
190
199
208
217
226
235
244
253
262
271
280
289
82
91
10
19
28
37
46
55
64
73
1
5 minute dispatch interval
Enabling the energy transition
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33. Resource Adequacy = Deliverability @ Risk
Base Case
Probability
Base Case + SPG
1 day in 10 Years Event
Capacity 364 MW
Resource Mix Delivery risk with:
1) Thermal units (35%) 1) Forced Outage
2) Demand Response (15%) 2) Start up Failure
3) Renewables – 33% 3) Ramping
4) Imports – 20% 4) Miss-forecast
Enabling the energy transition
33