European Network Code

Implementation Overview

Wednesday 3 May 2017

Background and purpose

More detail on: Connection Codes – Requirements for Generators

Operational Codes

Balancing Codes

Implementation Progress

Get involved/Keep informed

2

EU Code Implementation Overview

European Network Code

Implementation Overview

Rob Wilson

Technical Codes Development Manager

European 3rd package drivers

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The key players in ENC Development

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European Network Codes

Development Process

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What are the codes and what do they do?

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Markets

Establishes a platform for managing capacity and flow around the

interconnected system to facilitate the setup of a single EU market

Capacity Allocation

& Congestion

Management

(“CACM”)

Forward Capacity

Allocation (“FCA”)

Electricity

Balancing

Guideline

(“EBGL”)

System

Operation

Harmonises the processes Transmission System Operators have to

manage their systems, including system restoration

(Transmission) System

Operation Guideline (“TSOG”)

Emergency & Restoration

(“ER”)

Grid

Connection

Sets consistent technical requirements across EU for new

connections of user equipment (e.g. generation/interconnectors)

Requirements for

Generators (“RfG”)

High Voltage Direct

Current (“HVDC”)

Demand

Connection (Code)

(“DCC”)

More detail on:

EU Connection Codes

9

Overview of the EU Connection codes

Requirements for Generators (RfG)

Entry Into Force: 17th May 2016

Applies to: New generation connections (800 Watts capacity and up) to Distribution and Transmission systems

From: 17th May 2018 onwards

Demand Connection Code (DCC)

Entry Into Force: 7th September 2016

Applies to: New Transmission-connected Demand connections; and new equipment providing Demand Side Response

From: 7th September 2018

High Voltage Direct Current (HVDC)

Entry Into Force: 29th September 2016

Applies to: New Transmission-connected Demand connections,, and new equipment providing Demand Side Response

From: 7th September 2018

More detail on RfG – Generator Banding

Technical requirements in RfG are arranged into x4 Types based

on a user’s connection voltage and MW capacity

Type A - B requirements are close to a product standard

Type C - D requirements need active user management

GB levels will apply consistently across Scotland and England +

Wales. The local TSO (NGET) will make a proposal for the levels -

this is then ratified via industry consultation and regulatory approval

Maximum RfG banding levels permitted for GB:

Type Connection

Voltage Capacity

A < 110kV 800 W – 1 MW

B < 110kV 1 MW – 50 MW

C < 110kV 50 MW – 75 MW

D > 110kV 75 MW +

Current GB Levels:

Generator

Size SHET SPT NGET

Small <10MW <30MW <50MW

Medium 50-100MW

Large >10MW >30MW >100MW

More detail on RfG – Requirements per Type

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Technical Requirements Type A Type B Type C Type D

Operation across a range of frequencies ● ● ● ●

Limits on active power output over frequency range ● ● ● ●

Rate of change of frequency settings applied (likely to be at least 1Hz/sec) ● ● ● ●

Logic interface (input port) to cease active power output within 5 secs ● ● ● ●

Ability to automatically reduce power on instruction ● ● ●

Control schemes, protection and metering ● ● ●

Fault Ride Through requirements ● ● ●

Ability to reconnect ● ● ●

Reactive capability ● ● ●

Reactive current injection ● ● ●

Active power controllability ● ●

Frequency response ● ●

Monitoring ● ●

Automatic disconnection ● ●

Optional Black start ● ●

Stable operation anywhere in operating range ● ●

Pole slipping protection ● ●

Quick resynchronisation capability ● ●

Instrumentation and monitoring requirements ● ●

Ramp rate limits ● ●

Simulation models ● ●

Wider Voltage ranges / longer minimum operating times ●

Synchronisation on instruction ●

Enhanced Fault Ride through ●

More detail on:

Transmission System

Operation Guideline

Rob Selbie

EU Codes Development Manager

Overview of the EU System Operation codes

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Emergency & Restoration Code (E&R):

Harmonisation of system defence and restoration procedures during severe events

Transmission System Operation Guideline (TSOG): system security, operational planning and frequency management standards

Operational

Security • Data Exchange

• System States

• System

Management

Operational

Planning • Regional security

coordination

• Outage

coordination

• Adequacy

Load

Frequency

Control &

Reserves • Operational

agreements

• Quality targets

Harmonises the processes TSO have to manage their systems, including

system operation

So am I impacted?

TSOs

More transparency

in system operation

Operational security analysis

Cross-border processes

Generators

New data exchange

requirements

Including for distribution connected

SGUs

Distribution Network

Operators

New data exchange

requirements and outage coordination

responsibilities

Interconnectors

Facilitation of exchange of A/S

Including agreements for

cross-border processes

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More detail on:

Electricity Balancing

Guideline; TERRE

Overview of the European MARKET codes

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Early Implementation – Project TERRE

Pan-EU Balancing

Energy Market

• Development of pan-EU platforms

for the exchange of standard

balancing energy products

• 6 year implementation period

• Replacement Reserves (RR)

• Manual Frequency Restoration

Reserves (mFRR)

• Specific products retained

nationally

Harmonisation of Market

Design & Settlement

• Harmonised Gate Closure Time for

standard products

• Harmonisation of ISP at Synchronous

Area level

• Harmonisation of imbalance

arrangements (preference for single

imbalance pricing)

• Harmonisation of reserve procurement

arrangements

Cross Zonal Capacity

Reservation (CZC)

• Opens the possibility for TSOs to

reserve XB capacity for the

exchange of balancing energy

• Co optimisation with market

timeframes

• TSOs to develop detailed

methodologies

Overview of the European Market codes

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TSOs: Access to a wider pool of flexibility EU Platforms procurement closer to real time

Balancing Service Providers: New standard products; Access to EU market; Level playing field

Balance Responsible Parties: Harmonised imbalance settlement; Imbalance Adjustment; More accurate price signals

Interconnectors: Facilitation of exchange of A/S; More variability

Implementation Progress

ENC implementation approach

(multiple interactions to manage!)

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1 Grid Code - RfG Banding and Fast Fault Current Injection, RfG and HVDC Fault Ride Through Grid Code National Grid GC0048 May-2017 17/05/2018Consolidated mod - dependencies between banding

and fault ride through parameters

2 Distribution Code - RfG Banding and Fast Fault Current Injection, RfG and HVDC Fault Ride Through Distribution Code ENA TBC 17/05/2018Consolidated mod - dependencies between banding

and fault ride through parameters

3 Grid Code - RfG and HVDC Voltage/Reactive and Frequency Response requirements Grid Code National Grid GC0048 May-2017 17/05/2018

4 Distribution Code - RfG and HVDC Voltage/Reactive and Frequency Response requirements Distribution Code ENA TBC 17/05/2018

5 Grid Code - Compliance and System Management Grid Code National Grid GC0048 Jun-2017 17/05/2018

6 Distribution Code - Compliance and System Management Distribution Code ENA TBC 17/05/2018

7 Grid Code - DCC Technical & Demand Side Response Requirements Grid Code National Grid GC0091 Jun-2017 07/09/2018

8 Distribution Code - DCC Technical & Demand Side Response Requirements Distribution Code ENA TBC Jun-2017 07/08/2018

9 Grid Code – to enable data provision between NGET and other TSOs Grid Code National Grid TBC Apr-2017 Q2 2018 Common Grid Model Project

10 Grid Code – to enable interconnector data provision to NGET after GB gate closure Grid Code National Grid TBC Apr-2017 Q1 2019 (TBC)

11 EB GL - General Compliance (BSC) BSC Elexon TBC Q3 2017 Q3 2018

12 EB GL - General Compliance (Grid Code) Grid Code National Grid TBC Q3 2017 Q3 2018

13 EB GL - General Compliance (Distribution Code) Distribution Code ENA TBC Q3 2017 Q3 2018

14 BSC - Publication of information BSC Elexon TBC Q3 2017 Q4 2018 Project TERRE

15 BSC - Assignment Elexon Tasks BSC Elexon TBC Apr-2017 Q3 2017

16 BSC - Replacement Reserves BSC Elexon P344 Q2 2016 Q4 2018 Project TERRE

17 Grid Code - Replacement Reserves Grid Code National Grid GC0097 Q1 2017 Q4 2018 Project TERRE

18 CUSC - Replacement Reserves CUSC National Grid TBC Q4 2017 Q4 2018 Project TERRE

19 Grid Code - manual Frequency Restoration Reserves Grid Code National Grid TBC Q1 2020 Q3 2021 mFRR Project

20 BSC - manual Frequency Restoration Reserves BSC Elexon TBC Q1 2020 Q3 2021 mFRR Project

21 CUSC - manual Frequency Restoration Reserves CUSC National Grid TBC Q3 2020 Q3 2021 mFRR Project

22 BSC - Imbalance Settlement Harmonisation BSC Elexon TBC Q1 2019 Q3 2020

23 STC - Multi TSO Training Cooperation STC National Grid TBC Q3 2017 Q3 2018

24 SQSS - Determination of Minimum required Inertia SQSS National Grid TBC Q3 2018 Q3 2019

25 Grid Code - TSOG requirements for data exchange Grid Code National Grid TBC Q3 2017 Q3 2018

26 D-Code - TSOG requirements for data exchange Distribution Code ENA TBC Q3 2017 Q3 2018

27 STC - TSOG requirements for data exchange STC National Grid TBC Q3 2017 Q3 2018

28 Grid Code - Regional Outage Coordination and Security Analysis Grid Code National Grid TBC Q1 2018 Q4 2018

29 D-Code - Regional Outage Coordination and Security Analysis Distribution Code ENA TBC Q1 2018 Q4 2018

30 SQSS - Regional Outage Coordination and Security Analysis SQSS National Grid TBC Q1 2018 Q4 2018

31 STC - Regional Outage Coordination and Security Analysis STC National Grid TBC Q1 2018 Q4 2018

32 Grid Code - TSOG requirements in relation to reserve providers and operational agreements Grid Code National Grid TBC Q1 2018 Q4 2018

33 SQSS - TSOG requirements in relation to reserve providers and operational agreements SQSS National Grid TBC Q1 2018 Q4 2018

34 Grid Code - System Defence & Restoration Plans Grid Code National Grid TBC Q3 2017 Q3 2018

35 BSC - Market Suspension BSC National Grid TBC Q3 2017 Q3 2018

36 Grid Code - Market Suspension Grid Code National Grid TBC Q3 2017 Q3 2018

Planned

Date to

Raise at

Code Panel

Op

era

tio

nal

Co

des

TSOG (EIF - 01/07/2017 Expected)

E&R (EIF - Q3 2017 Expected)

Required

Compliance

Date

DependenciesC

on

necti

on

Co

des

Requirements for Generators (EIF - 17/05/2016) & HVDC (EIF - 29/09/2016)

DCC (EIF - 07/09/2016)

Mark

et

Co

des

CACM (EIF - 14/08/2015)

EB GL (EIF - Q3 2017 Expected)

EU

Code

Family

Ref Modification DescriptionWhich GB Code

To be Applied

Code

Administrator

Modification

Reference

Markets & Balancing Development

GB Code Modifications

Where can I

find out more?

For more information/how to get involved

Joint European Stakeholder Group:

A monthly meeting covering all European legislation issues

(supported by BEIS, Ofgem, National Grid amongst others)

Weekly Email Newsletter Update

For more information contact:

europeancodes.electricity@nationalgrid.com

Implementation Workgroups (Grid Code):

RfG Implementation Workgroup – GC0048

RfG Frequency Response provisions - GC0087

HVDC Implementation Workgroup - GC0090

DCC Implementation Workgroup - GC0091

TSOG Implementation Workgroup - GC0095

TERRE Implementation Workgroup – GC0097

For more information contact: Grid.Code@nationalgrid.com

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Fact sheets

Fact sheets providing an overview on each EU code are

available on our website: http://www2.nationalgrid.com/UK/Industry-information/Electricity-

codes/European-network-code/Development-process-and-code-

information/

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Back-up content

Where to find info on SO Ancillary Services

Our Balancing Services web page provides information on

commercial opportunities:

www2.nationalgrid.com/uk/services/balancing-services/

More detail on these services is set out in a range of guides available

at this link:

http://www2.nationalgrid.com/UK/Services/Balancing-

services/Service-Guides/

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For more information

please contact:

commercial.operation

@nationalgrid.com

Update: Review of transmission charging

In light of significant change in recent years, e.g. decentralisation,

decarbonisation and new technologies; we believe Transmission

charging and commercial arrangements need holistic review

This was supported by feedback from two dedicated charging

seminars held in July (outputs here: Charging Review Website)

Feedback from these seminars has informed the scope and

approach of a review. At TCMF on 08/12/16 we presented further

thoughts on the next steps. These are grouped in three areas…

1. Quick wins – a number of activities are progressing, including

CUSC mods on half hourly charging (CMP266), a policy paper on

storage (early 2017) and improvements to tariff forecasting.

2. Holistic review – we want to work with Ofgem to ensure their

areas of work around embedded generation are comprehensive,

particularly with regards to flexibility.

3. Stakeholder forum – we want to establish a forum to discuss

broader industry reform and develop a route-map for change 26

Other Grid Code mods

GC0096 – Storage is a new workgroup kicking off

in early 2017

In conjunction with the BEIS/Ofgem call for

evidence on Flexibility, it will define (Electricity)

Storage in the Grid Code, and make clear what

technical requirements are required for:

Stand-alone Storage connections, and...

Storage configured with existing generation or

demand units

For more details on how to get involved please

email Grid.Code@nationalgrid.com 27

Market Design

Capacity Allocation & Congestion Management

(CACM) Guideline

• Implicit Day Ahead & Intraday cross border trading

• Bidding zone reporting process and subsequent review

Forward Capacity Allocation (FCA) Guideline

• Long term transmission rights;

-Physical Transmission Rights (PTRs) with Use It or

Sell It (UIOSI)

- Financial Transmission Rights (FTR) options

-FTR obligations

• Single Allocation Platform with Harmonised Allocation

Rules

Regional Capacity Calculation

• CACM and FCA both increase regional TSO

coordination with capacity calculation used to determine

interconnector capacities

• Calculation underpinned by a pan- EU Common Grid

Model (CGM)

It establishes a platform for managing capacity & flow around the

interconnected system to facilitate a single EU market

Overview of the European MARKET codes

CACM and FCA have been published and

become law within the UK;

- CACM entry into force 14 Aug 2015

- FCA entry into force 17 Oct 2016CACM

and FCA now requires T

TSOs, NEMOs to draft, consult, and submit

proposals to regulators on detailed design

aspects.

CACM proposals largely complete by end

of 2018, FCA by end of 2019.

Any changes to GB codes to implement

CACM and FCA will be raised and consulted

on through the normal GB code governance

routes

TSO = Transmission System Operator

NEMO= Nominated Electricity Market

Operator

Overview of the European MARKET codes

NG and other TSOs will develop new processes to increase

regional coordination

Trading Interconnector capacity in the forwards markets trading

cross border energy in the day-ahead & intraday timeframes

Generators and demand to provide information on which TSO

decisions are made on a regional basis (see Common Grid Model)

Power exchanges (in their new role as NEMOs) will develop new

processes to deliver a pan-EU marketplace

Interconnector owners (current and future) will operate under new

rules, including new requirements on interconnector firmness

Overview of the European MARKET codes

CGM built

at D-2

CGM built

at D-1

Common Grid Model (CGM)

• A European-wide network model assembled from each TSO’s individual grid model (IGM)

• Realistic and accurate representation of the Transmission & Distribution networks

• One scenario for each market time unit (1 hour)

• Built to a common standard with a harmonised modelling approach

• Used as a key tool for many new coordinated European processes – incl. capacity calculation

Each TSO’s IGM is built

using the latest available

data from market

participants for specific

delivery times

Rolling Daily Process that supports target

model

TSO A

IGM

Overview of the European MARKET codes

TSO B

IGM

TSO C

IGM

Overview of the European MARKET codes

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Obligations Q2 Q3 Q4

2016

Q1 Q2 Q3 Q4

2017

Q1 Q2 Q3

2018

ENC

deadlines

CGM

Methodology

GLDP

Methodology

Early testing

and parallel

run of CGM

process

NR

A

ap

pro

va

l DA & ID CGM

Requirements

(for CACM)

delivered

Update CGMM

& GLDPM for

FCA (Long-

term

timescales)

FC

A E

IF

TS

OG

EIF

DA & ID data

requirements for

CACM) delivered

Update

CGMM &

GLDPM for

TSOG

CGM process fully

operational

NR

A

ap

pro

va

l TSO develop

IGM

capability

TSOs

publish list

of parties

required to

provide data

Data Provision process

fully operational

CA

CM

EIF

Au

g 2

01

5

So when does it come into effect?

Deadline Proposal Project Key

Overview of the Joint European stakeholder group

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The Joint European Stakeholder Group is a

GB Stakeholder forum which will

cover the development, Comitology process and implementation of

European Network Codes (ENC), which provides a single group for GB

stakeholder

to engage on all aspects of European Policy

Want to get Involved?

WebEx/teleconference facilities available

Weekly update – sign up on feedback form

Monthly meetings – come along, held at Exelon offices, London

Next meeting: 13th December 2016 – EID discussions.

Come and talk at lunch should you want to know anymore

Barbara Vest

Director of

Generation

(Chair)

Chrissie Brown

NETSO Code

Administration

(Technical Secretary)