Wir schaffen Wissen – heute für morgen
8. Juni 2015 PSI, 8. Juni 2015 PSI,
Paul Scherrer Institut
Can the decentralised CHP generation provide the flexibility required to integrate intermittent RES in the electricity system?
Evangelos Panos , Kannan Ramachandran
67th Semi-Annual ETSAP Workshop, Abou Dhabi
Swiss energy system & Swiss energy strategy to 2050 objectives
The concept of dispatchable biogenic CHPs (electricity-driven)
Extensions on Swiss Times Electricity Model (STEM-E)
Challenges in modelling
Preliminary results from model testing
Conclusions
Introduction
Net Imports Hydro Nuclear Thermal Renewables
Electricity sector Industry
Transport Residential Services -2
40 25
3 1
Electricity production: 66 TWh
Swiss energy system in 2013
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Final energy consumption: 896 PJ
CO2 emissions 41 Mtn:
0 50 100 150200 250 300
350 Renewables
Heat Electricity Gas Oil Wastes Coal Wood
4 5
17 10
5
Energy Strategy 2050 key objectives:
Enhancement of energy efficiency
Unlocking new RES (wind, solar, biomass)
Withdrawal from nuclear energy
Imports and fossil to meet residual electricity demand
Extension of electricity grid
Dams south, Nuclear north
Swiss grid congested lines
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Source: Swissgrid
2/3 of the grid was built between 1950 and 60s with focus on
ensuring regional supplies from nearby plants
Gaseous fuel from waste biomass Wood
Air
Heat storage Energy conversion
with thermal
machine Electricity grid
Combined Heat and Power plant
Specifications for grid stabilisation:
Fast response power generation
Temporal independent production of electricity and heat
A contractor (electricity utility) could operate a CHP swarm by remote:
Dispatchable, scalable and decentralised power plant
Balancing power is sold at high price levels on the market
The concept of biogenic CHP Swarm
Running project ETH/PSI sponsored by BFE and Swisselectric Research
A biogenic flexible CHP can participate in the following markets:
a) Electricity supply, on-site or distributed
competition with power plants
competition with electricity grid price
b) Heat supply for space and water heating, on-site or distributed
competition with boilers and heat pumps
competition with district heating networks
c) Provision of grid balancing services at a grid distribution level:
competition with on-site solutions e.g. batteries
competition with services provided by pump hydro, PtG, etc.
However, the technology is resource-constrained:
it uses biogas or upgraded biogas injected to gas grid
needs access to gas pipelines
competition with other biogas uses
Assessing the potential of CHP Swarms
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To implement biogenic flexible CHPs in TIMES, to assess its
potential and to identify barriers and competitors we need in the model at least:
Representation of decentralised power generation
High time resolution to account for demand and resource fluctuations
Introduction of dispatchability features (e.g. ramp-up constraints)
Representation of heat supply and demand sectors
Representation of electricity & heat storage technologies
Representation of alternatives, such as power-to-gas pathways
Representation of bio-methane production options
Representation of demand for balancing services
Challenges in TIMES modelling
STEM-E:
Swiss Electricity Model
288 time slices:
4 seasons X 3 days X 24h
Exogenous electricity
demand linked to economic activity
Electricity load profiles
Different types of power plants
Resource potentials
Swiss Times Electricity Model
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STEM-HE:
All STEM-E plus:
Decentralised generation
Heat demands & load profiles
Heat supply options
Storage for electricity & heat
Power-to-gas / gas-to-power
Upgraded biogas production
Ramping constraints
Balancing services
FROM STEM-E to STEM-HE
2012 2014
Representation of decentralised sector
Very High Voltage Grid Level 1 Nuclear
Hydro Dams Pump Storage Imports
Exports
Distributed Generation
Run-of-river hydro Gas Turbines CC Gas Turbines OC Geothermal
High Voltage Grid Level 2 Large Scale
Power Generation
Medium Voltage Grid Level 3 Wind Farms
Solar Parks Oil ICE
Waste Incineration
District Heating CHPs
Wastes, Biomass Oil
Gas Biogas H2
Low Voltage Distribution Grid
Large Industries &
Commercial CHP oil
CHP biomass CHP gas CHP wastes CHP H2 Solar PV Wind turbines
Commercial/
Residential Generation
CHP gas CHP biomass CHP H2 Solar PV Wind turbines
4 different grid voltage levels are represented
Allows for compensation of RES generation that is fed into grid
Similar structure with TIMES-PET (and perhaps with other models)
Not always straightforward assignment of power plants to each level
To reduce complexity the focus is on heat that can be supplied by CHPs
Space and water heating in buildings and commercial sectors
Differentiation between different types of houses
Two classes of heat in industrial sectors: <500
oC, >500
oC
Heat demand sector
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Residential Sector
Single Family Multi Family
Space Heating Existing buildings
Space Heating
New buildings
Space Heating Existing buildings
Space Heating
New buildings
Water Heating Industry
Heat
>500 oC (CHPs NO)
Services
Space Heating &
Water Heating
Heat Supply Technologies
(boilers, resistors, heat pumps, night storage devices, Decentralised CHP) Heat
<500 oC (CHPs YES )
Statistical estimation of consumer behaviour from surveys [1]
Data reconciliation to minimise the deviation between actual and calculated annual heat demand from the profiles:
Heat demands and load profiles
HDD Annual
Demand Outside
temperature Typical Daily Profile
% of seasonal demand
% of demand per typical day
% demand for 288 typical hours
Adjustment of electricity load curve
min� 𝑤𝑤1,𝑡𝑡 𝐷𝐷𝑡𝑡 − 𝐹𝐹𝑡𝑡 2 +� 𝑤𝑤2,𝑡𝑡 𝑥𝑥𝑡𝑡𝑡𝑡 − 𝑦𝑦𝑡𝑡𝑡𝑡 2
𝑡𝑡𝑡𝑡 𝑡𝑡
𝐹𝐹𝑡𝑡 𝑥𝑥1… .𝑥𝑥𝑛𝑛 = 0 𝐶𝐶𝑘𝑘 𝑥𝑥1… .𝑥𝑥𝑛𝑛 = 0
𝒘𝒘 weights, user defined 𝒚𝒚 Initial hourly profiles 𝒙𝒙 Adjusted hourly profiles
𝑭𝑭 Calculated annual heat demand 𝑫𝑫 Actual annual heat demand 𝑪𝑪 Other constraints that must hold
Single family houses Multi family houses
Commercial Industry
Space heating: morning peak followed by a long day-time plateau and a smaller evening peak
Water heating: sharp variations depending on use
Examples of obtained heat profiles
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Existing single family houses – Space heating in PJ
0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4
H01 H02 H03 H04 H05 H06 H07 H08 H09 H10 H11 H12 H13 H14 H15 H16 H17 H18 H19 H20 H21 H22 H23 H24
SPR-WK SUM-WK FAL-WK WIN-WK
Existing multi family houses – Space heating in PJ
0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4
H01 H02 H03 H04 H05 H06 H07 H08 H09 H10 H11 H12 H13 H14 H15 H16 H17 H18 H19 H20 H21 H22 H23 H24
0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4
H01 H02 H03 H04 H05 H06 H07 H08 H09 H10 H11 H12 H13 H14 H15 H16 H17 H18 H19 H20 H21 H22 H23 H24
SPR-WK SUM-WK FAL-WK WIN-WK
All households– Water heating in PJ
Representation of heat systems
[2]Heat supply option 1 Heat supply option 2 Heat supply option N
Heat storage
Heat System
𝑎𝑎
𝑝𝑝,𝑡𝑡∙ 𝑋𝑋
𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝑁𝑁+𝑏𝑏
𝑝𝑝𝑝𝑝,𝑡𝑡∙ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝑁𝑁= 𝑐𝑐
1,𝑡𝑡∀𝑝𝑝 ∈ 𝑃𝑃
𝑁𝑁𝑃𝑃𝑃𝑃; 𝑝𝑝𝑝𝑝 ∈ 𝑃𝑃
𝑆𝑆𝑆𝑆𝑁𝑁∪𝑆𝑆𝑆𝑆𝑆𝑆; 𝑡𝑡 ∈ 𝑇𝑇 ; 𝑡𝑡𝑡𝑡_𝑝𝑝𝑝𝑝𝑎𝑎𝑝𝑝 ∈ 𝑇𝑇𝑇𝑇 ; 𝑎𝑎
𝑝𝑝,𝑡𝑡, 𝑏𝑏
𝑝𝑝,𝑡𝑡, 𝑐𝑐
1,𝑡𝑡, 𝑐𝑐
2,𝑡𝑡, 𝑐𝑐
3,𝑡𝑡 const𝑎𝑎
𝑝𝑝,𝑡𝑡∙ 𝑋𝑋
𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝑁𝑁+𝑏𝑏
𝑝𝑝𝑝𝑝,𝑡𝑡𝑀𝑀𝑁𝑁𝑀𝑀∙ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝑁𝑁≤ 𝑐𝑐
2,𝑡𝑡𝑎𝑎
𝑝𝑝,𝑡𝑡∙ 𝑋𝑋
𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝑁𝑁+𝑏𝑏
𝑝𝑝𝑝𝑝,𝑡𝑡𝑀𝑀𝑃𝑃𝑁𝑁∙ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝑁𝑁≥ 𝑐𝑐
3,𝑡𝑡Fixed capacity ratio: e.g. solar thermal and gas boiler
Upper and lower bounds on capacity ratios: e.g.
micro CHP and gas boiler
� 𝑋𝑋
𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝑝𝑝∈𝑁𝑁𝑃𝑃𝑅𝑅𝑅𝑅
≥ 𝑑𝑑𝑝𝑝𝑑𝑑𝑎𝑎𝑑𝑑𝑑𝑑
𝑡𝑡,𝑡𝑡𝑡𝑡_𝑝𝑝𝑝𝑝𝑝𝑝𝑘𝑘 Match demand capacity requirement with the capacity of the primary heat supply systems Combinations of primary and secondary heating systems is possible via user constraints:
Heat demand
Avoiding technology mix in heat supply
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H01 H03 H05 H07 H09 H11 H13 H15 H17 H19 H21 H23
Wood boiler Solar thermal Gas boiler District heating Heat from CHP on-site Oil boiler
Heat Pump Electric boiler Coal boiler H01 H03 H05 H07 H09 H11 H13 H15 H17 H19 H21 H23
Wood boiler Solar thermal Gas boiler District heating Heat from CHP on-site Oil boiler
Heat Pump Electric boiler Coal boiler
No individual technology
optimisation is applicable for heat supply systems:
a) Go for MIP by ensuring that only one heat system will supply a heat demand class [2] (not directly supported in TIMES) OR:
b) Introduce a utilisation curve for each heat supply system with NCAP_AF(UP) and ACT_UPS(FX) in accordance with the demand curve
Primary reserves react to frequency deviations within 30 seconds
Secondary reserves are activated just slightly after the primary reserves and maintain a balance between generation and demand within each balancing area (duration from 1 to 60 minutes)
Tertiary reserves are called only after secondary control has been used for a certain duration, to free the secondary reserves for other purposes
Introducing balancing services
Secondary reserves
Secondary reserves Tertiary reserves
Source: Swissgrid
Each power plant is producing 4 additional commodities related to the primary & secondary upward and downward reserves
The set of the attributes of a power plant is augmented by:
Its minimum stable operation
The % of total capacity available for primary and secondary upward and downward reserves
The ramp-up and ramp-down rates
We can also provide the % of upward reserve met by online
plants to avoid unrealistically provisions of upward reserves from offline technologies
The additional equations for balancing services:
Can be introduced as UC (takes time to enter the constraints in EXCEL)
Can be implemented as TIMES extension in GAMS (prone to errors)
Porting OSEMOSYS methodology
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Each power plant eligible for participating in the balancing markets is divided into two parts
A capacity transfer UC ensures that the capacity-related costs are paid only once:
Demand for balancing services: 3 ∗ 𝜎𝜎
𝐷𝐷2+ 𝜎𝜎
𝑆𝑆2+ 𝐾𝐾
Porting OSEMOSYS methodology
𝑋𝑋
𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁= 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁Power Plant p (participation in the
electricity market) Power Plant pp (participation in the
balancing markets)
ELC Electricity demand Primary upward reserve demand
Primary downward reserve demand Secondary upward reserve demand
Secondary downward reserve demand
PU
PD SU SD
PU_DEM
PD_DEM SU_DEM SD_DEM
ELC_DEM
𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁= 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝐸𝐸𝑁𝑁/(𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝∙ 𝑦𝑦𝑦𝑦𝑦𝑦𝑦𝑦
𝑡𝑡,𝑡𝑡𝑡𝑡) :online capacity of process 𝑝𝑝 Downward reserve:
𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑘𝑘≤ 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁∙ 𝑑𝑑𝑎𝑎𝑥𝑥
𝑘𝑘,𝑝𝑝𝑝𝑝∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝𝑝𝑝: 𝑝𝑝 ∈ 𝑃𝑃𝐷𝐷, 𝑇𝑇𝐷𝐷
Upward reserve for a fast ramping plant: (𝐦𝐦𝒂𝒂𝒙𝒙
𝒌𝒌,𝒑𝒑𝒑𝒑≥ 𝒔𝒔𝒔𝒔𝒂𝒂𝒔𝒔𝒔𝒔𝒔𝒔𝒔𝒔𝒑𝒑
𝒑𝒑𝒑𝒑) 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑘𝑘≤ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁∙ 𝑎𝑎𝑦𝑦
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡∙ 𝑑𝑑𝑎𝑎𝑥𝑥
𝑘𝑘,𝑝𝑝𝑝𝑝∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝𝑝𝑝: 𝑝𝑝 ∈ 𝑃𝑃𝑈𝑈, 𝑇𝑇𝑈𝑈
𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝐷𝐷+ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝑆𝑆≤ 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝐸𝐸𝑁𝑁𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝐸𝐸𝑁𝑁≤ 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝Upward reserve for a slow ramping plant: ( 𝒎𝒎𝒂𝒂𝒙𝒙
𝒌𝒌,𝒑𝒑𝒑𝒑≤ 𝒔𝒔𝒔𝒔𝒂𝒂𝒔𝒔𝒔𝒔𝒔𝒔𝒔𝒔𝒑𝒑
𝒑𝒑𝒑𝒑) 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑘𝑘≤ 𝑋𝑋
𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁∙ 𝑎𝑎𝑦𝑦
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡∙ 𝑑𝑑𝑎𝑎𝑥𝑥
𝑘𝑘,𝑝𝑝𝑝𝑝∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝𝑝𝑝: 𝑝𝑝 ∈ 𝑃𝑃𝑈𝑈, 𝑇𝑇𝑈𝑈
𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝐷𝐷+ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝑆𝑆+ 𝑋𝑋
𝑝𝑝,𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁∙ 𝑡𝑡𝑡𝑡𝑎𝑎𝑏𝑏𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝
𝑝𝑝𝑝𝑝∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡_𝑝𝑝 ≤ 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝐸𝐸𝑁𝑁𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝐸𝐸𝑁𝑁+ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝐷𝐷+ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝑆𝑆≤ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝𝑝𝑝Key equations for balancing services
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Minimum online upward reserve ( 𝑝𝑝 ∈ 𝑃𝑃𝑈𝑈, 𝑇𝑇𝑈𝑈 )
∑ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑘𝑘𝑝𝑝𝑝𝑝
≥ 𝐷𝐷𝐷𝐷𝑀𝑀
𝑘𝑘,𝑡𝑡,𝑡𝑡𝑡𝑡∙ 𝑑𝑑𝑚𝑚𝑑𝑑𝑠𝑠𝑑𝑑𝑠𝑠𝑚𝑚𝑑𝑑𝑝𝑝
𝑡𝑡All reserve from online plants when m𝑎𝑎𝑥𝑥
𝑘𝑘,𝑝𝑝𝑝𝑝≤ 𝑡𝑡𝑡𝑡𝑎𝑎𝑏𝑏𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝
𝑝𝑝𝑝𝑝: 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑘𝑘= 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝐶𝐶𝑁𝑁𝐸𝐸𝑃𝑃𝑁𝑁𝑆𝑆𝑘𝑘∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝Share of reserve from online plants when m𝑎𝑎𝑥𝑥
𝑘𝑘,𝑝𝑝𝑝𝑝≥ 𝑡𝑡𝑡𝑡𝑎𝑎𝑏𝑏𝑠𝑠𝑝𝑝𝑠𝑠𝑝𝑝
𝑝𝑝𝑝𝑝: 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑘𝑘≥ 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝐶𝐶𝑁𝑁𝐸𝐸𝑃𝑃𝑁𝑁𝑆𝑆𝑘𝑘∙ 𝑐𝑐𝑎𝑎𝑝𝑝𝑎𝑎𝑐𝑐𝑡𝑡
𝑝𝑝Upward reserve is limited by online capacity minus power output:
𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁− 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑆𝑆𝐸𝐸𝑁𝑁≥ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝐶𝐶𝑁𝑁𝐸𝐸𝑃𝑃𝑁𝑁𝑆𝑆𝑃𝑃𝑃𝑃+ 𝑋𝑋
𝑝𝑝𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝐶𝐶𝑁𝑁𝐸𝐸𝑃𝑃𝑁𝑁𝑆𝑆𝑆𝑆𝑃𝑃Upward reserve by online plants limited by their max contribution to upward reserve:
𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝑁𝑁𝑁𝑁𝑁𝑁𝐶𝐶𝑁𝑁∙ 𝑑𝑑𝑎𝑎𝑥𝑥
𝑘𝑘,𝑝𝑝𝑝𝑝≥ 𝑋𝑋
𝑝𝑝,𝑡𝑡,𝑡𝑡𝑡𝑡𝐶𝐶𝑁𝑁𝐸𝐸𝑃𝑃𝑁𝑁𝑆𝑆𝑘𝑘Key equations for balancing services
[3] The related to this work project is currently running and we are still integrating information from our partners regarding grid
constraints, balancing services, CHP technology characterisation and biomass resource potentials
“Reference” scenario assumptions used to test the model:
Based on the “POM” scenario of Swiss energy strategy 2050, implementing strong efficiency measures
Fuel prices from IEA ETP 2014, translated to Swiss border pre-tax prices
Nuclear phase out to be completed by 2034
No CCS and no coal in electricity generation
CO2 price rises to 58 CHF/t CO2 in 2050
Solar potential: ~10 TWh, Wind potential: ~3 TWh, Hydro: ~40 TWh
Preliminary results from model testing
08.06.2015
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Energy service demands in PJ
Forecast of demands
0 100 200 300 400 500 600
2010 2012 2015 2020 2030 2040 2050
Residential thermal
Residential electric specific
Services thermal
Services electric specific Industry thermal
Industry electric specific
(excl. transport)
Final energy consumption in PJ
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0 100 200 300 400 500 600 700
2010 2020 2030 2040 2050
Hydrogen Biogas Solar Wastes Wood Heat * Coal
Natural gas Heavy fuel oil Light fuel oil Electricity
Share of technologies in residential heat
0%
10%
20%
30%
40%
50%
60%
2010 2020 2030 2040 2050
Heat pumps Heat *
Gas boilers Oil boilers
Operational profiles of heat technologies
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0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0
H01 H03 H05 H07 H09 H11 H13 H15 H17 H19 H21 H23
Wood/Pelletts Gas
Heat radiators Oil
Heat pumps
Electric boilers/resistors Solar
Single family houses
0.0 1.0 2.0 3.0 4.0 5.0 6.0 7.0
H01 H03 H05 H07 H09 H11 H13 H15 H17 H19 H21 H23
Wood/Pelletts Gas
Heat radiators Oil
Heat pumps
Electric boilers/resistors Solar
Multi family houses
Storage technologies for heat in services
0 1'000 2'000 3'000 4'000 5'000 6'000
1 3 5 7 9 11 13 15 17 19 21 23 Total Heat
Demand -120
-100 -80 -60 -40 -20 0 20 40
1 3 5 7 9 11 13 15 17 19 21 23 Thermochemical
Storage of CHP heat Night boilers
Electricity generation sector
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0 2 4 6 8 10
2010 2020 2030 2040 2050
Solar Wind Wood &
Biogas
-10 0 10 20 30 40 50 60 70 80
2010 2012 2015 2020 2030 2040 2050
Solar Wind
Geothermal Wastes Wood Biogas Gas Nuclear Hydro
Pump storage Net Imports
Electricity production by fuel in TWh Electricity
production from
renewables in TWh
CHP Swarms (capacity & operation profile)
2020 2030 2040 2050
Capacity (MW) 109 185 124 56
Electricity production (GWhe) 585 1200 522 415
% of total electricity production 1% 2% 1% 1%
% of decentralised thermal only electricity production 39% 80% 35% 28%
% of decentralised total electricity production 17% 16% 5% 3%
Heat production (GWhth) 838 1719 748 595
0 20 40 60 80 100 120 140 160 180 200
0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200
1 3 5 7 9 11 13 15 17 19 21 23
CHP Swarms MW Solar PV
(MW)
Solar PV CHP Swarms Winter working day
0 20 40 60 80 100 120 140 160 180 200
0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200
1 3 5 7 9 11 13 15 17 19 21 23
CHP Swarms MW Solar PV
(MW) Summer Sunday
CHP Swarms seems a promising technology for providing flexibility to the electric system
Potential parameters affecting their uptake include:
Developments in the large-scale generation
Costs of bio-methane and access competition from other uses
Feed-in tariffs for biomass
Competition in heat supply from heat pumps
Storage costs for storing excess heat from CHP Swarms
Modelling challenges:
No satisfactory solution for the technology mix effect in heat sectors
Improvement of the dispatching of the power plant technologies:
crucial factor for the balancing services as well
Conclusions – Further Challenges
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References
[1] Main Sources used for obtaining the heat demand profiles:
BFE, “Analyse des schweizerischen Energieverbrauchs 2000 - 2012 nach Verwendungszwecken“, 2013
Rossi Alessandro, “Modelling and validation of heat sinks for combined heat and power simulation: Industry”, 2013
Ayer Roman, “Modelling of heat sinks for combined heat and power simulation: Households”, 2013
Federal office of Meteorology and Climatology MeteoSwiss
Mark Hellwig "Entwicklung und Anwendung parametrisierter Standard-Lastprofile", 2003
Ulrike Jordan, Klaus Vajen, “Realistic Domestic Hot-Water Profiles in Different Time Scales”, 2001
[2] Modelling heat systems:
Merkel E., Fehrenbach D., McKenna R., Fichter W., Modelling decentralised heat supply: An application and methodological extension in TIMEs, Energy 73 (2014), 592-605
[3] Modelling balancing services:
Welsch M., Howells M., et al., Supporting security and adequacy in future energy systems: the need to enhance long-term energy system models to better treat issues related to variability, Int. J. Energy Res. 39 (2015), 377-396
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