presentazione standard di powerpoint - diapositiva 1 · 2019-10-16 · of the rotating mass 1 2...

H2020 OSMOSEOSMOSE WP5: Techno-

economic analysis of DSR and

RES selected services

2019 Sept 19th

EEM19 – 16th Int. Conference on the European Energy Market

Luca Orrù, Marco Pietrucci, Leonardo Zeni - Terna

Dario Siface, Carlo Tornelli, Carlo Sandroni - RSE

Agenda

OSMOSE WP5 results

Introduction & context

Highlights & expectations of WP5

Analysis of flexibility services (WP 5.1 – D5.1)

Preliminary results DSR and RES flexibility resources (WP 5.2 –

D5.2)

4

9

6 146

50

4 4

1919

10 1820

515

5117

148

2017 2030 PNIECCarbone Olio combustibile Gas naturalePompaggi puri Idroelettrico EolicoFotovoltaico Altre FER

RES:

~53GW

RES:

~93GW

177123

46

49

17

40

24 756

71916

290310

2017 2030 PNIECTradizionale Idroelettrico Eolico FotovoltaicoGeotermica Bioenergie

RES:

113

TWh

RES:

187

TWh

x3

x2,4

Sc

en

ari

os

at

20

30

18.3%

29.7%34.1%

55.4%

2017 2030 PNIECQuota FER totale Quota FER - elettrico

Coal plant to be

dismissed

➢ RES coverage

Ma

inta

rge

t P

NIE

C

Installed capacity

[GW]

Italian electricity production

[TWh]

➢ Coal phase-out

at 2025

PNIEC (Italian NECP): coal phase-out by 2025 & strong increase of the amount of demand covered by RES

RES - electricityRES - total

PVWindBioenergyGeothermal

Italian energy scenarios at 2030

Coal

PV

GasOil

Other RES

Pumping


HydroThermal WindHydro

The increasing penetration of renewable energy sources in the generation mix, combined with the simultaneous

decommissioning of conventional carbon-fired power plants, is posing new challenges for the security and

cost-efficiency of grid operation.

-10,000

0,000

10,000

20,000

30,000

40,000

50,000

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Demand Residual Load Renewables

50.000

40.000

30.000

20.000

10.000

0

-10.000

Demand Residual load Renewables

2030 simulation▪ Significant need of ramping-up thermal generation in the evening hours

to balance the drastic output reduction by solar PV

▪ Poor regulating capacity, following the growing share of RES in the

national generation mix

▪ Limited up-ward reserve margins to cover peak load, following the

decommissioning of significant amount of thermal installed capacity

▪ Grid congestions, due to the non-homogeneous distribution of RES

across the Country (most notably disseminated in the Southern areas)

▪ Increased periods of over-generation from non programmable and non

dispatchable renewables

▪ Limited availability of sources providing voltage regulation (reactive

power) and frequency regulation (rotational inertia against the loss of

system stability)

Consumption and ‘residual load’ curvesMajor operational issues for TSOs

50.000

40.000

30.000

20.000

10.000

0

-10.000

Introduction & contextMain impacts on system operations





D5.2)

Agenda

OSMOSE WP5 results

7

WP5: Demo WP assessing the provision of Flexibility Services by Demand Response from large industrial loads

and by RES generations; all sources connected to HV level and integrated in a SMS

Project structure and WP5 italian demo

Highlights & expectations

Technology Provider

Flex. Provider

Research centers and Academy

4,6 M€

Divisione Strategie, Sviluppo e Dispacciamento| Strategia di Sistema

WP5 partners, coordinated by Terna, were accurately

defined in order to minimize overlapping:

❑ 2 R&D centers

❑ 3 Industry players

❑ 4 “energy flexibility service” providers

❑ Others “third parties”involved in the execution phase (industrial customers

connected to HV grid)

TASK 5.1 TASK 5.2

TASK 5.3 TASK 5.4

TASK 5.5 TASK 5.6

Planning & Specification

2018-2019

Use Case Implementation

2019

Execution & Reporting

2020-2021

✓ Tasks mainly guided by Terna and RSE in

coordination with all other partners

✓ Massive participation of third parties

(customers connected to HV grid) for the

assessment and specification of DSR services

✓ ABB will manage the implementation of all the

hardware, the local EMSs and the interface

with the central EMS

✓ IBM will focus on developing a software

solution for the central EMS platform

✓ Terna will be responsible for the execution

phase

✓ RSE and Ensiel will cooperate on performing

the ex-post technical and market analysis

✓ Service providers and third parties will

participate to the market analysis proposing

regulatory evolution

on-going

ISC – Uso [INTERNO] 8

Partners and tasks involved in WP5

Highlights & expectations

Terna coordinates a working group of 9 different partners, well distributed on the tasks.

Divisione Strategie, Sviluppo e Dispacciamento| Strategia di SistemaISC – Uso [INTERNO] 9

D5.1Techno-economic

analysis of DSR and RES

D5.4 Implementation of EMS solution

D5.3 Upgrade of industrial load,

aggreg., RES plant and

implementation of grid devices

Final report on the results of the

demonstrations (data analysis)

General technical specification

for EMS and physical demo

implementation

D5.5

D5.6 Final report summarizing

main demo results

Highlights & expectationsTasks & deliverables

D5.2

10

HV connected plant

Aggregator’s NOC

Controller

Inverter

Grid

Other

loads not

involved

• Services pool set points

• Aggregated states and

measures

• Aggregated alarms

• Resources setpoints

• Resources states&measures

• Resources alarms

• Power Set point

• States&measures

• Consumption unit alarms

• Set point

• Machinery states and

measures

•Load alarms

POOL A POOL B POOL C

IEC

104

G G G

•Power modulation







DSR and RES flexibility resourcesIndustrial loads flexibility analysis

11Divisione Strategie, Sviluppo e Dispacciamento| Strategia di Sistema

Aggregated demand sources RES Plant (also integated with Energy Storage)

Automatic Frequency Restoration Reserve: power

exchange with the grid based on a signal received by

the TSO, with the aim to restore nominal system

frequency

Congestion Management: modify generators/loads

production/consumption according to grid conditions

Automatic Voltage Control: increase or decrease the

reactive power exchange with the grid, helping voltage

regulation

Synthetic Inertia: power delivered as a function of

frequency deviation

Automatic Voltage Control: increase or decrease the

reactive power exchange with the grid, helping voltage

regulation

ISC – Uso [INTERNO]

11

DSR and RES flexibility resourcesGrid services recap

Further flexibility potential from several grid services (RES and DSR side) will be investigated

12

WP5 Demo Area and large consumer involvement

DSR and RES flexibility resources

The demo area of WP5 demonstrator is a part of the 380kV and 150 kV grid between Apulia and Basilicata, grouped in 7 main segments.

The grid portion was chosen because of the high penetration of renewable sources as well as a good number of large industrial consumers connected to HV.

Industrial loads (*)

1. Car manufacturer

2. Water utility

3. Foundry

4. Tires manufacturer

5. Powertrain industry

6. Foundry

7. Water utility

8. Packaging industry

9. Water utility

10.Water utility

11.Tech park

12.Concrete industry

13.Car frame manufacturer

14.Steel mill

15.Oil company

16.Aeronautic company

17.Car manufacturer

18.Aeronautic company

19.Cable manufacturer

20.Military site

After a preliminary scouting of 20 industrial players, 9 agreed to get involved in the demonstrator: an energy audit

was performed to investigate their flexibility potential.

B

Backbone 3

2 Large wind power plants:

A. Pietragalla (Enel) ≈ 18 MW

B. Vaglio (E2I) ≈ 15 MW

A

20 Industrial loads on HV grid

Backbone 2

Backbone 4

Backbone 5

Backbone 6

Backbone 7

Backbone 1

13

D5.1 - Analysis of flexibility servicesRES plants involved: Potenza Pietragalla WIND+BESS plant

01❑ 18 MW Wind Power Plant

❑ BESS: 2MW/2MWh, Lithium-ion (NMC)

❑ First BESS power plant in Italy connected to HV

❑ Integrated RES + BESS in operation from Oct 2015

❑ BESS currently active services: Energy Shifting – Unbalancing

Optimization – Dispatch Orders

❑ Services Implemented & tested on BESS, but still not active:

Frequency Regulation – Voltage Regulation

❑ BESS service to be implemented and tested: Synthetic Inertia

Potenza

EGP Potenza Pietragalla WIND+BESS Power Plant

Control System Architecture

14

D5.1 - Analysis of flexibility servicesRES plants involved: Potenza Vaglio WIND plant

01

❑ 15 MW Wind Power Plant

❑ Doubly Fed Induction Generator

❑ Active services: Active and Reactive Power Control

❑ Service to be implemented and tested: Synthetic InertiaPotenza

E2I Vaglio WIND Power Plant

Control System Architecture

15





D5.2)

Agenda

OSMOSE WP5 results

16Divisione Strategie, Sviluppo e Dispacciamento| Strategia di Sistema - IFO

Highlights & expectationsD5.1 Deliverable

17Divisione Strategie, Sviluppo e Dispacciamento| Strategia di Sistema - IFO

Highlights & expectationsD5.1 Deliverable

www.osmose-h2020.eu

→Downloads

→Deliverables

http://www.osmose-h2020.eu/

18

• Today there is no market for system inertia

• Existing startup cost of synchronous generators was

used as a proxy for an economical evaluation of SI

provision

• Economic valorization of amount of synthetic inertia

needed to substitute a conventional generator

D5.1 - Analysis of flexibility servicesSynthetic inertia

• Variation of active power in response to the Rate

Of Change Of Frequency (ROCOF)

• Demo will test SI service from wind power plants

∆𝑃 = −𝑘𝑆𝐺 ∙ 𝑅𝑂𝐶𝑂𝐹 = −𝑇𝑎𝑃𝑛𝑓𝑛

∙ 𝑅𝑂𝐶𝑂𝐹

Mean Min Max

KSG Price

[€Hz/MWs]572 3 6.332

Price per unit of kSG (Italy - 2017)

19

D5.1 - Analysis of flexibility servicesSynthetic Inertia

• Synchronous generators inertial contribution • The inertial response is depending on the kinetic energy

of the rotating mass

𝑑

𝑑𝑡

1

2𝐽𝜔2 = 𝑃𝑚 − 𝑃𝑒

𝐽 is the moment of inertia, 𝜔 the angular rotation speed

𝑃𝑚and 𝑃𝑒 the driving mechanical power and the resistant

electric power applied to the rotor

• The inertial response of a conventional generator to a

certain ROCOF = 𝑑𝑓/𝑑𝑡

𝑃𝑚 − 𝑃𝑒 ≈𝑇𝑎𝑃𝑛𝑓𝑛

∙ ROCOF 𝑤𝑖𝑡ℎ 𝑇𝑎 ≜𝐽𝜔𝑛

2

𝑃𝑛

∆𝑃𝑆𝐺= −𝑇𝑎𝑃𝑛𝑓𝑛

∙ ROCOF = −𝑘𝑆𝐺 ∙ ROCOF

𝑃𝑛 is the generator nominal installed capacity

• Assuming that the driving mechanical 𝑃𝑚 does not

change, the generator injected electric power is

𝒌𝑺𝑮 ≜𝑻𝒂𝑷𝒏

𝒇𝒏

20


• Synchronous generators inertial contribution

• Inertial constant for different generator type

• The inertial response is depending on the kinetic energy

of the rotating mass

𝑑

𝑑𝑡

1

2𝐽𝜔2 = 𝑃𝑚 − 𝑃𝑒

𝐽 is the moment of inertia, 𝜔 the angular rotation speed

𝑃𝑚and 𝑃𝑒 the driving mechanical power and the resistant

electric power applied to the rotor

• The inertial response of a conventional generator to a

certain ROCOF = 𝑑𝑓/𝑑𝑡

𝑃𝑚 − 𝑃𝑒 ≈𝑇𝑎𝑃𝑛𝑓𝑛

∙ ROCOF 𝑤𝑖𝑡ℎ 𝑇𝑎 ≜𝐽𝜔𝑛

2

𝑃𝑛

∆𝑃𝑆𝐺= −𝑇𝑎𝑃𝑛𝑓𝑛

∙ ROCOF = −𝑘𝑆𝐺 ∙ ROCOF

𝑃𝑛 is the generator nominal installed capacity

• Assuming that the driving mechanical 𝑃𝑚 does not

change, the generator injected electric power is

Generator type H [MWs/MVA]

Coal (old) 4

Coal (new) 2

OCGT* 6

CCGT** 9

Cogeneration 2

Biomass 2

Hydro 3

Nuclear 5

CSP*** 2.5

*Open Cycle Gas Turbine

**Combined cycle power plant

***Concentrated solar power

𝒌𝑺𝑮 ≜𝑻𝒂𝑷𝒏

𝒇𝒏=𝟐𝐇𝑨𝒏𝒇𝒏

𝐻 ≜1

2∙𝐽𝜔𝑛

2

𝐴𝑛and 𝑃𝑛 = 𝐴𝑛 ∙ 𝑐𝑜𝑠𝜑.

𝐴𝑛 is the nominal apparent power of

the generation unit

𝐻 is the inertia constant, defined

as the ratio between the stored

rotational energy and the plant

nominal power in MVA

21


• Awarded prices for synchronous generators start

up on the Italian balancing market 2017

• Economic valorization of the synthetic inertia

• Analyzing the prices during year 2017, the statistics of

price per unit of 𝑘𝑆𝐺 were obtained

• A SI provider will be computed the amount of synthetic

inertia needed to substitute a conventional generator

∆𝑃𝑒,𝑆𝐼 = −𝑷𝒏 ∙ 𝒌𝑺𝑹𝑰 ∙ ROCOF = −𝒌𝑺𝑰 ∙ ROCOF

∆𝑃𝑒,𝑆𝐺 = −𝒌𝑺𝑮 ∙ ROCOF

22


• Awarded prices for synchronous generators start

up on the Italian balancing market 2017

• Economic valorization of the synthetic inertia

Generator type n. bids

KSG Price

[€Hz/MWs]

Mean

KSG Price

[€Hz/MWs]

Min

KSG Price

[€Hz/MWs]

Max

Fossil Gas 1.216 453 7 2.468

Fossil Oil 74 3.378 671 6.332

Fossil Hard coal 14 1.201 431 3.017

Other 466 416 3 1.887

• Analyzing the prices during year 2017, the statistics of

price per unit of 𝑘𝑆𝐺 were obtained

On a side note, the prices are not uniquely related to the provision of inertia, as the

production units operation, once turned on, might provide simultaneously other benefits to

the power system (e.g. voltage regulations). Therefore, only a portion of those values is

related to the provision of inertia.

• A SI provider will be computed the amount of synthetic

inertia needed to substitute a conventional generator

𝒌𝑺𝑰 ↭ 𝒌𝑺𝑮

∆𝑃𝑒,𝑆𝐼 = −𝑷𝒏 ∙ 𝒌𝑺𝑹𝑰 ∙ ROCOF = −𝒌𝑺𝑰 ∙ ROCOF

∆𝑃𝑒,𝑆𝐺 = −𝒌𝑺𝑮 ∙ ROCOF

⇓

⇓• Economic valorization

𝐒𝐈 𝐏𝐫𝐢𝐜𝐞[€] = 𝐊𝐒𝐆 𝐏𝐫𝐢𝐜𝐞 ∙ 𝒌𝑺𝑰

23

D5.1 - Analysis of flexibility servicesAutomatic Frequency Restoration Reserve

• automatic Frequency Restoration Reserve (aFRR)

used to compensate for the deviations between

demand and production in the Control Area

• Demo will test provision of the aFRR from

aggregated industrial loads in compliance with

grid code*

02

aFRR service provision from industrial loads

(*) the greatest between ± 10 MW and ± 6% of

the maximum power for thermoelectric units.

24







grid code*

02




25







grid code*

02




• Assumption:o lower costs for reserves provided by new flexible resources

o Pay as Bid market

• Two major evolutionary market scenarios considered

Needed aFRR >

aFRR available from flexible

resources

Needed aFRR <

aFRR available from flexible

resources

Minor impact

• The total cost of the aFRR service

will diminish only for the amount

acquired from flexible resources at

lower prices.

• The benefits will increase with

number and size of new flexible

resources.

Major impact

• Flexible resources cover the total

aFRR needs

• The prices will be determined by

the new market players at lower

cost with an economic benefit (at

least in some hours of the day)

• Expected benefits in total cost reduction for FRR

• Analysis of current prices payed for aFRR service

Italy

July 2017 – June 2018 Upward Downward

aFRR Price (mean) 110 €/MWh 16 €/MWh

26

D5.1 - Analysis of flexibility servicesCongestion management

• Demand response P service

• Demo will test provision of congestion

management service from industrial loads in

compliance with UVAM* Italian regulation

(*) Mixed Aggregated Virtual Unit

1 MW

at least

120 minutes max

27

• Expected benefits in total cost reduction for the resolution

of local congestions

• Analysis of current value in the Balancing Market

D5.1 - Analysis of flexibility servicesCongestion management

• Demand response P service

• Demo will test provision of congestion

management service from industrial loads in

compliance with UVAM* Italian regulation

• Assumption:o Lower costs for P provided by new flexible resources

o Pay as Bid market

o Intrinsic local constraints in using flexibilities

(*) Mixed Aggregated Virtual Unit

1 MW

at least

120 minutes max

Needed local P > P available from

flexible resources

Needed local P < P available from

flexible resources

Minor impact

• The total cost for local congestion

resolution will diminish only for the

power amount acquired from

flexible resources at lower prices

• The benefits will increase with

number and size of new flexible

resources in congested locations

Major impact

• Flexible resources cover the total

needs for congestion resolution

• The prices will be determined by

the new market players at lower

cost with an economic benefit

Italy

July 2017 – June 2018 Upward Downward

Balancing Market

Price (mean) 125 €/MWh 26 €/MWh

28

• Today in Italy, the AVC is a mandatory service and it is

not remunerated

• Value indirectly evaluated for Italy using other indicators

• An international comparison proposed, using the British

system as a reference case

D5.1 - Analysis of flexibility servicesAutomatic voltage control

• Demand response Q service

• Demo will test provision of AVC service by both

loads and wind power plants, with or without

BESS, either by the WTG itself or by the BESS

ItalyYear 2014

ARERA,

«Documento di

consultazione

420/2016/R/eel,»

Reactive Energy

provided

Dispatching

costs for voltage

regulation

Mean Reactive

Energy price

Total 33.5 TVAr h 150 M€ 4.48 €/MVAr h

GBSep. 2017 –

Aug. 2018

Reactive Energy

provided

Reactive Service

Cost

Mean Reactive

Energy price

Total 25.5 TVAr h 79,3 M£ 3.11 £/MVAr h

Reactive energy quantities and prices for obligatory reactive

power service (ORPS)

29





D5.2)

Agenda

OSMOSE WP5 results

FOCUS ANALYSIS: IDENTIFIED FLEXIBILITIES

In the 8 industrial plants analyzed the following flexibilities have

been found overall* :

❑ Congestion management

→ Up to 121.3 MW (27.3 loads, 94 generators)

❑ Frequency Restoration Reserve

→ Up to a 94.5 MW (500 kW loads, 94 generators)

❑ Automatic Voltage Control

→ Thousands of MVAr, of which 30 from loads

*Theorethical maximum values resulting from the analysis are shown.

For technical and budget reasons, only some of the flexibilities found will be tested

Load flexibilities for congestion management and aFRR to be investigated in

the WP5 demonstrator: illustrative aggregation sketch

Flexibility analysis found out some interesting resources to be tested for electrical flexibility. These resource

will be properly aggregated in order to provide a significant result for the Grid

FOCUS ANALYSIS: MAIN TAKEAWAYS

Industrial processes

highly optimizedFew buffers between

process phases

Most of the availability

is for auxiliary services

DSR and RES flexibility resourcesIndustrial loads flexibility analysis

H2020 OSMOSE

OSMOSE WP5: Techno-economic

analysis of DSR and RES selected

services

Thank you

Luca Orrù – [email protected] Strategy, Development & Dispatching - System

Strategy – Innovation Factory

Carlo Tornelli – [email protected] – Transmission and Distribtion Technologies dept.

presentazione standard di powerpoint - diapositiva 1 · 2019-10-16 · of the rotating mass 1 2...

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