TERRE Industry Day

TERRE Industry Day

16 January 2018 ELEXON & National Grid

Introducing the TERRE product to the GB market

Public

Health & Safety

2

Agenda & event outcomes

■ To gain a high level

understanding of the

TERRE balancing product to

be implemented in the GB

market arrangements

■ To have the opportunity to

ask questions about TERRE

to the GB TERRE project

teams from ELEXON and

National Grid

Agenda item Time Presenter

Registration and coffee 09:30

1. Introduction and housekeeping 10:00 Elliott Harper (ELEXON)

2. Welcome 10:05 Mark Bygraves (ELEXON)

3. Introduction to Project TERRE 10:10 Sophie Tilley (National Grid), Elliott

Harper (ELEXON)

4. The detail of the GB solution 10:40 Bernie Dolan (National Grid), Matt

Roper (ELEXON)

Break 11:25

5. The detail of the GB solution

11:40 Bernie Dolan (National Grid), Matt

Roper (ELEXON)

Lunch 12:45

6. The detail of the GB solution

13:30 Bernie Dolan (National Grid), Matt

Roper (ELEXON)

7. The P344 and GC0097 Industry Consultations 13:45 Sophie Tilley (National Grid), Elliott

Harper (ELEXON)

8. Implementation timescales 14:00 Elliott Harper (ELEXON), Sophie Tilley

(National Grid)

Break 14:20

9. Question and Answer session with the GB Project TERRE

teams 14:30 All

Close 16:00

CEO Welcome

Mark Bygraves

Introduction to Project TERRE

Sophie Tilley – National Grid Elliott Harper - ELEXON

Background - Electricity Balancing Guideline

Project TERRE industry day: Project TERRE

6

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

European Balancing Platforms

https://prezi.com/sh39zfzbo-ok/project-terre/

European Implementation Projects

7

• TSO-TSO Model

• Marginal Pricing

• RR Product

• Schedule Activation

• 30min Full Activation Time

• 15min Blocks

• One auction per hour

• HVDC losses taken into account

• Congestion rents generated

Design

• 10 full members (GB, France, Italy, Portugal, Spain, Switzerland, Czech

Republic, Romania, Poland, Hungary)

• More observers in process of joining

• RFP underway

• 1st NRA approval Sept 16

• 2nd Consultation held summer 2017

• NRA currently assessing 2nd design submission

• Go-live Q3 2019

Current Status


What does TERRE mean for GB?

8

• New post gate-closure time

balancing auction (similar to

existing day ahead arrangements)

• Additional process for submitting

offers to TERRE in line with

Balancing Mechanism processes.

• SO will have an additional tool to

conduct coarse energy balancing

actions etc using 15 min blocks of

energy

• Access to additional flexibility such

as “non-BM” units and across

borders for energy balancing.

• New international market for GB

market participants to compete in.

• Introduction of new pay-as-clear

pricing approach (in parallel with

existing arrangements)

• Removal of barriers to entry for

“non-BM participants” and an

increase in price formation

• Estimated reduction in balancing

costs of €13 million for GB

• Currency exchange required:

Operationally Commercially

How big is TERRE and how will it fit into our strategy?

9

National Grid conducted some analysis to understand the below questions:

How much could we use TERRE?

Use to stand down STOR earlier – 164MWh per day (7MW average)

Coarse energy balancing – 1.4GWh per day (60MW average)

Controlling I/C flows – 1.4GWh per day (60MW average)

Total yearly volume 1.10TWh out of 4.42TWh total actions – 25% of

needs

What sort of volumes could be offered into TERRE by the GB market?

Initial analysis has suggested that we could see up to 3.8GW of volume

offered into TERRE from GB market participants


Who is ELEXON and what do we do?

■ Administer the Balancing and Settlement Code (BSC)

■ Manage imbalance Settlement arrangements and payments

■ Settle payments for actions under the Balancing Mechanism (BM)

What else does ELEXON do?

■ Training and support for BSC Parties

■ Ensures compliance to the BSC through auditing and a party performance

framework

■ Manages review and implementation of changes to existing GB BSC regulation

GB implementation of the TERRE product overview (1/2)

■ National Grid and ELEXON working together to deliver TERRE

– National Grid: the Grid Code

– ELEXON: the Balancing and Settlement Code

■ Changes required to both Codes in order to implement the necessary arrangements to

facilitate the TERRE balancing product

■ BSC: P344 ‘Project TERRE implementation into GB market arrangements’

■ Grid Code: GC0097 ‘Grid Code Processes Supporting TERRE’

■ Due to interdependencies between the Codes for TERRE, ELEXON and National Grid have

facilitated cross-Code working

– Working together utilising internal and industry resource to deliver an aligned, efficient

TERRE balancing product to the market

https://www.elexon.co.uk/mod-proposal/p344/

https://www.nationalgrid.com/uk/electricity/codes/grid-code/modifications/gc0097-grid-code-processes-supporting-terre

GB implementation of the TERRE product overview (2/2)

■ Both Codes have a similar structure of change process to implement TERRE:

Panel final

recommendations

Proposal to amend

current Code

arrangements

Development of solution

by Industry Workgroup

Industry Consultation on

solution

Initial Panel

recommendations

Industry Consultation on

initial Panel

recommendations

Authority (Ofgem)

decision on changes

Development and testing

of systems to deliver the

TERRE product

Implementation (go-live)

Joint European Stakeholder Group (JESG)

■ An information source for EU legislation impacting the GB market – JESG

weekly newsletter

■ Discussion forum for EU impacts, much wider than TERRE – JESG monthly

meeting

■ For more information, please contact

[email protected]

mailto:[email protected]

The detail of the GB solution

Matt Roper – ELEXON Bernie Dolan – National Grid

End to End Process

15

Registration

Pre-

qualification

Replacement Reserves E2E Process

Data

Submission

Dispatch/

Delivery Product

Settlement

Imbalance

Settlement

Overall End to End Process

TERRE Industry Day

• Proposed by National Grid

• Work Group has been meeting

since summer 2016

• Initial consultation held Feb 17

• Joint working since July 2017

• Proposed by National Grid

• Work Group has been meeting

since Jan 2017

• Joint working since July 2017

BSC Mod - P344 Grid Code Mod - GC0097

Reporting

Introduction

16

Who can participate in TERRE?

What is an Independent Aggregator?

Market Entry Process

What is a Secondary BM Unit?

New BSC Party Comparison

Registration Pre-

qualification

Data Submission

Dispatch/ Delivery

Product Settlement

Imbalance Settlement

Reporting

Who Can Participate in TERRE?

T_NAME-1

E_NAME-1

M

2__ANAME001 ∑M

M

M M

M M Supplier

Additional

BM Unit

Generator

CVA

BM Unit

Trading Party

Embedded

BM Unit


T_NAME-1

E_NAME-1

M

2__ANAME001 ∑M

M

M M

M M Supplier

Additional

BM Unit

Generator

CVA

BM Unit

Trading Party

Embedded

BM Unit

However, the European Electricity Balancing Guidelines (EB GL) requires that TSO’s facilitate demand response participation in TERRE, including independent aggregation facilities and energy storage


T_NAME-1

E_NAME-1

M

2__ANAME001 ∑M

M

M M

M M Supplier

Additional

BM Unit

Generator

CVA

BM Unit

Trading Party

Embedded

BM Unit

Ofgem defines Independent Aggregators as parties who bundle changes in consumer’s loads or distributed generation output for sale in organised markets and who do not simultaneously supply the customer with energy


20

Supplier

M M

M M

M

M

M M M

Generator

£

£


21

Supplier

M M

M M

M

M

M M M

Generator

£

£

Balancing

Services

M


22

Supplier

M M

M M

M

M M M

Generator

£

£

Balancing

Services

M M M [ ]

£

M


23

Supplier

M M

M M

M

M M M

Generator

£

£

Balancing

Services

M M M [ ]

Independent Aggregator

M M M M M [ ]

Balancing

Services

Flexibility

Virtual Lead Party Comparison

24

Energy Accounts (P/C)

Existing BSC Party

Trading party

Virtual Balancing Account

Virtual Lead Party

Non-Trading Party

Primary BM Units Secondary BM Units

ECVN or MRVN

Base Monthly Charge

Funding Share Calculated

No ECVN or MVRN

VLP Base Monthly Charge

No Funding Share Calculated

Reduced Credit Requirements Full Credit Requirements


T_NAME-1

E_NAME-1

V_NAME-1

M

2__ANAME001 ∑M

M

∑M

M M

M M

M M

M M Supplier

Additional

BM Unit

Generator

CVA

BM Unit

Trading Party

Embedded

BM Unit

Virtual Lead Party

Secondary

BM Unit

What is a Secondary BM Unit?

26

■ Allows the association of MSIDs to a BM Unit for the purposes of offering Balancing

Services only, i.e.

– Lead Party of a Secondary BM Unit are not responsible for consumption at those

Meter Points

– Metered volumes not used to calculate Imbalance Positions

– Metered volumes will be used to calculate Non-Delivery volumes

■ Secondary BM Units requirements :

– Half Hourly SVA MSIDs only

– MSIDs are in the same GSP Group

– MSID can only be in one Secondary BM Unit at any time

– Secondary BM Unit Monthly Charge

27

Set up Authorised Signatories

Ascension to the BSC

Qualification Testing

Order Comms Lines *

Lodge Credit Cover

Register Party Role

Go Live

Register Secondary BM Units

Market Entry Process

* Low / High grade Communications lines are optional and not mandatory

ELEXON has established a dedicated Market Entry Team to offer support and advice to new BSC Parties going through the process. Parties can contact them on the ELEXON website here

https://www.elexon.co.uk/reference/market-entry/

GC0097 / P344 workgroup

28

System Operator Guideline (SOGL) Article 162 describes the process

RR prequalification process

A potential RR provider shall demonstrate….. that it complies with RR technical minimum

requirements … in Article 161

Within 8 weeks of receiving the formal application the TSO shall confirm that the

application is complete (in terms of information required)

If the application is incomplete the RR provider shall provide the additional required

information within 4 weeks of the request from the TSO (if the provider does not comply

the application is deemed to be withdrawn)

Within 3 months from the confirmation of completeness the TSO shall confirm if the

potential RR provider meets the criteria for prequalification

Qualification will be reassessed

At least once every five years

Where technical requirements or equipment changes

Pre-qualification – SOGL Article 162

TERRE Industry Day Registration

Pre-

qualification


29

System Operator Guideline (SOGL) Article 161 gives minimum technical requirements

Shall comply with activation and de-activation according to set point from TSO

Time stamped scheduled active power output for each RR providing unit and

group (and each generating module or demand unit of a RR group) with

maximum active power >= 1.5MW

Time stamped instantaneous active power output for each RR providing unit

and group (and each generating module or demand unit of a RR group) with

maximum active power >= 1.5MW

Fulfilment of availability requirements

TSO shall specify RR availability requirements and requirements for control

quality

The RR provider will inform the TSO about actual availability or forced outage

Pre-qualification – SOGL Article 161


Pre-

qualification


30

At go-live will assume all existing active BMUs pre-qualify

(one off exercise)

At go-live will have simple way to say whether an existing

BMU wishes to be part of TERRE

Ongoing will treat pre-qualification as separate

Operational metering* – will be down to 1MW to align with the

product (*National Grid purposes, Settlement metering also required)

Metering accuracy – 2.5%

How to indicate availability – will use MIL and MEL

Close participation between the TSO and DSO/DNO is vital

(and mandated in codes) so detailed registration process will

be agreed with DSO/DNOs

Pre-qualification – Proposals


Pre-

qualification


31

Data Submission/Dispatch/Delivery - Overview

TERRE Industry Day

09:00

30min ISP

1hr GCT 30min ISP

10:30 10:45 11:00

RR Process RR Delivery

09:15 09:30 09:45 10:00 10:15

1hr Cross Zonal Intra Day Gate Closure Time (XZIDGCT) 1hr Cross Zonal Market Time Unit (XZ MTU)

1hr Gate Closure Time (GCT)

09:00

Trading stops in XBID for 10:00-11:00

FPN & BOD Submission for 10:00-10:30

TERRE Data Submission for 10:00-11:00

09:15

TSO needs submitted to TERRE for 10:00-11:00

09:30

FPN & BOD Submission for 10:30-11:00

TERRE results published and activations (RRIs) issued for 10:00-11:00

Wall moves from 10:30 to 11:00


32

BSPs submit bids to GB TSO

Must use electronic communication facilities except in exceptional circumstances

Submissions must be submitted before gate closure (9:00 in example)

Data can be submitted up to 5 days in advance (as per current BM submissions)

Expect PN covering time period of bids (same format etc. as now)

Must ensure have Run Up/Run Down rates (same format etc. as now)

Bids should ensure that any acceptance is physically realisable (using linked bids, blocks etc.

as specified by Central TERRE Programme)

RR Providers submit data to TSOs

TERRE Industry Day

09:00 09:15 09:30 09:45 10:00 10:15

RR Providers submit

data to TSOs

TSO

assess submission

TSO

determine

need

LIBRA TSO issues RRIs

TSO sends data TSO receives RRAs

BSPs ramp

(times depends on rates)

BSPs full

activation

(depends on

rates)

Data

Submission


33

GB TSO will check for manifest errors (e.g. incorrect format)

Must have PN for the period

Bids must not violate Transmission or Distribution constraints

RR Provider has not already accepted a prior commitment (response, sync decisions)

Must not be already providing support to DNO/DSO

Bids will be marked as “restricted” before passing to LIBRA if these conditions are broken

TSO assess submission

TERRE Industry Day

09:00 09:15 09:30 09:45 10:00 10:15

RR Providers submit

data to TSOs

TSO

assess submission

TSO

determine

need



BSPs ramp


BSPs full

activation

(depends on

rates)

Data

Submission


34

GBTSO will determine need

Based on demand forecast

Based on reserve and response requirements

Will request an “inelastic” volume

May send in an “elastic” volume based a min/max price

TSO sends data to central platform (LIBRA)

TSO determine need & forward data

TERRE Industry Day

09:00 09:15 09:30 09:45 10:00 10:15

RR Providers submit

data to TSOs

TSO

assess submission

TSO

determine

need



BSPs ramp


BSPs full

activation

(depends on

rates)

Data

Submission


35

Central algorithm (LIBRA) chooses from the submitted bids to match TSO needs

Netting and matching performed by algorithm

Pay as clear price established

LIBRA returns Replacement Reserve Acceptances (RRAs) to the TSOs for each of the BSPs

in their control area

LIBRA

TERRE Industry Day

09:00 09:15 09:30 09:45 10:00 10:15

RR Providers submit

data to TSOs

TSO

assess submission

TSO

determine

need



BSPs ramp


BSPs full

activation

(depends on

rates)

Optimisation


36

GB TSO adds ramps to the MW level deviation “blocks” described in the RRAs

The feasibility of the returned RRAs is checked from the perspective of ramping

Adjustments are made if infeasibility is found

Replacement Reserve Instructions (RRIs) are sent to the BSPs so that the Full Activation

Times (FAT) for each 15 minute period is honoured

For the ½ hour after the TERRE delivery period Final Physical Notifications (FPNs) are not

available (the “beyond the wall issue”)

Final instructions may be delayed until the FPNs is available but still respecting the 30 minute

FAT

TSO issues RRIs

TERRE Industry Day

09:00 09:15 09:30 09:45 10:00 10:15

RR Providers submit

data to TSOs

TSO

assess submission

TSO

determine

need



BSPs ramp


BSPs full

activation

(depends on

rates)

Dispatch


37

There are reasons why the GB TSO may not follow the RRA

The unit may declare a change in availability (using MIL/MEL)

The GB TSO may have issued a BOA due to interim system issues

Having issued an RRI this will be treated as a Capped Committed Level (CCL) and

subsequent Bid Offer Acceptances (BOAs) will be taken from this level

Does RRI always follow RRA/interaction with BM

TERRE Industry Day

09:00 09:15 09:30 09:45 10:00 10:15

RR Providers submit

data to TSOs

TSO

assess submission

TSO

determine

need



BSPs ramp


BSPs full

activation

(depends on

rates)

Dispatch

TERRE/ BM interactions: BOA before RRI proposed solution

TERRE Industry Day

38

Actions in the same direction:

The restriction of RRIs will occur when a BOA has been issued if deemed necessary

When a BOA has been issued before an RRI and they are in the same direction and

the BOA volume is larger than the RRI, no RRI will be issued

unit to be settled for the RRI volume using the RR Activation with the remaining

volume settled at the BOA price (i.e. the red area in the bottom left diagram)

When a BOA has been issued before an RRI and they are in the same direction and

the RRI volume is larger than the BOA, a RRI will be issued for the difference (blue

area above red area in bottom right diagram).

The RR schedule will be used to ensure that the unit is paid the TERRE clearing

price for the blue area and BOA price for the blue area.

Dispatch

TERRE/ BM interactions: BOA before RRI proposed solution

TERRE Industry Day

39

Actions in opposite directions:

Where a BOA has been issued before an RRI and they are in opposite directions the

RRI will not be issued and the unit will continue to follow the instructed BOA output.

Option 1: By automatically unwinding the RRI at the bid/offer price in the BM

Option 2: By automatically unwinding the RRI at the bid/offer price in the BM but

capping the unwinding cost at £0

Option 3: By removing any unwinding cost for the RRI

Option 1 was chosen

Dispatch


40

The TERRE product has a maximum Full Activation Time (FAT) of 30 minutes

FAT = preparation time + ramping time

The Central TERRE programme wishes to incentivise product shapes that start to ramp 5

minutes before the RRA and complete 5 minutes into the RRA

This is to reduce imbalance caused by interconnector ramping

RR Providers submit data to TSOs

TERRE Industry Day

09:00 09:15 09:30 09:45 10:00 10:15

RR Providers submit

data to TSOs

TSO

assess submission

TSO

determine

need



BSPs ramp


BSPs full

activation

(depends on

rates)

Delivery


41

Expected shapes of delivery

TERRE Industry Day Delivery

09:30 09:45 10:00 10:15 10:30 10:45

Starts 09:59 / Ends 10:01

09:30 09:45 10:00 10:15 10:30 10:45

Starts 09:35 Ends 10:05

09:30 09:45 10:00 10:15 10:30 10:45

TSO receives

RRAs

Starts 09:55 Ends 10:05

Ideal

Shape

Faster

Rate

Slowest

Rate

Introduction

42

What data will Settlement receive?

How will a Quarter Hour (QH) RR Acceptance be Paid?

How will Non-Delivery work?

Will Lead Parties Imbalance Position be affected?

How will a QH RR Acceptance volumes be Settled?

Will the registered Suppliers Imbalance Position be affected?

Will the Imbalance Price Calculation be affected?

Registration Pre-

qualification

Data Submission

Dispatch/ Delivery

Product Settlement

Imbalance Settlement

Reporting

What data will Settlement Receive?

Quarter Hour Interconnector

Scheduled Volume

Quarter Hour Volume GB Need Met

Quarter Hour RR Acceptance Data

Balancing Mechanism Data

RR Auction Result Data

Details of each successful QH TERRE bid including MW, price and start/end times

Details of each Interconnector and the associated TERRE scheduled flow per QH

The total volume of GB need met for each QH through the TERRE auction.

Details of SBMU FPN, Dynamic Data Set, Bid Offer Data & BOA

What data will Settlement Receive?

Quarter Hour Interconnector

Scheduled Volume

Quarter Hour Volume GB Need Met


• RR Cashflow • RR Deviation Cashflow • RR Schedule

• Imbalance Price Calculation

• Imbalance Price Calculation

• RR Schedule • BM Settlement • Non-delivery calculation

Balancing Mechanism Data

How is it used in Settlement?

How will QH RR Acceptances be paid?


RR Cashflow

RR Deviation Cashflow

P344 uses the Quarter Hour RR Acceptance

Data to calculate how much a Party should be

paid for a successful TERRE bid

= RRAViJ * Price £ / MWh

TERRE introduces a second cashflow to

incentivise delivery of the TERRE Standard

Product Shape (TSPS) by applying a Balancing

Energy Deviation Price (BEDP) to volumes

delivered in addition to / missing from the TSPS

15 min RR Acceptance Period

P344 solution has set BEDP = £0


How will QH RR Acceptances volumes be Settled?

Why is it needed?

■ National Grid have indicated they will not always issue a full RR Instruction.

■ Settlement needs to account for all TERRE volumes for Non-Delivery purposes. Therefore the SAA will

construct an ‘RR Schedule’ for use in settlement to account for the instances where a RR Instruction is not

received.

■ The RR Schedule will respect the BM Unit declared Dynamic Data Set (where possible) and align with TSO

RR Dispatch Principles (as defined by National Grid)

■ RR Schedules will be treated as Acceptance Data issued 60 min prior to the RR Auction Period and act as

baseline for any subsequent Acceptance Data received.


RR Schedule


How will QH RR Acceptances volumes be Settled?

How will the volumes be Settled?

■ The volumes relating to RR Schedules are not included in any cash flow calculations

■ Therefore SAA will need to differentiate and calculate RR Schedule Volumes independently

– i.e. an equivalent calculations to those for those used to settle BOAs (Period Accepted Offer Volume

and Period Accepted Bid Volume)

■ This will ensure that the volumes for RR Acceptances and BOAs do not mix,

– which could result in a BSP being paid twice (once via RR Cashflow and again via BM Cashflow).

■ Note – in the majority of cases settlement will receive RR Instructions from the TSO but will not calculate

any associated volumes (as they would be duplicate due to the RR Schedule) will be calculated.


RR Schedule


How will Non-Delivery work?

■ RR Schedule will be treated exactly the same as BOA for calculating Non-Delivered Volumes

■ However the RR Schedule shall not be entered into the pricing stack for the apportionment of Non-

Delivered volumes to Accepted Balancing Services Bids / Offers

■ Instead Deemed Standard Product Offer Volumes (priced at the RR Acceptance price) and RR Deviation

Volumes (priced at BEDP = £0) shall be entered

Expected Meter Volume = FPN + RRAO

Compared against Actual Metered Volume


DSPO @ £50 / MWh

BOA1 @ £40 / MWh

BOA2 @ £35 / MWh

IOD @ £0 / MWh

Will Lead Parties Imbalance Position by adjusted?

Supplier / Trading Party

Lead Party Adjustment

Yes Adjusted for all RR Schedule volumes RR Accepted Offer / Bid volumes will feed into BM Unit Balancing Service Volumes (QBSij)

Yes Only adjusted for any Non-Delivered Volumes VLP will be exposed to imbalance as an incentive to deliver any accepted bids

M M

M M

Primary BM Unit

Virtual Lead Party

Secondary BM Unit

M M

M M

Will affected Suppliers Imbalance Position by adjusted?

Virtual Lead Party

Secondary BM Unit

M M

M M

M M

M M

M

M

M

M

M

M

M

M

A Secondary BM Unit can contain SVA Metering Systems registered by many Suppliers in their Primary BM Units

Supplier A

Will affected Suppliers Imbalance Position by adjusted?

Virtual Lead Party

Secondary BM Unit

M M

M M

M M

M M

M

M

M

M

M

M

M

M Adjustment Calculated

Supplier B

Supplier C

Supplier D

Yes VLP will be obligated to register all MSID Pairs they wish to allocate to a Secondary BM Units centrally with Settlement on the ‘SVA Metering System Balancing Services Register’. VLP will also provide ‘Delivered Volumes’ per MSID Pair so that Settlement can aggregate per Supplier per Secondary BM Unit an appropriate adjustment to applied at the Supplier BM Unit level

YES A Secondary BM Unit can contain SVA Metering Systems registered by many Suppliers in their Primary BM Units

Will the Imbalance Price Calculation be affected?

P344 proposes that the calculation of imbalance prices should include all the physical actions taken on the GB system, but only those taken to meet a GB need should be treated as priced.

QH Volume of GB Need Met

QH Interconnector Scheduled Volume

∑ RR Schedule Volumes

QH RR Acceptances will not state whether they are to fulfil a local or foreign need P344 proposes that actions (volumes/prices) are calculated at an aggregate level for each QH.

A

g

g

r

e

g

a

t

e

d

Total Volume of GB Need Met @ £ TCP

Aggregated unpriced System Buy / Sell Action @ £ 0


53

Publication

TERRE Industry Day Publication/

Reporting

European Level National Level (BMRS)

• Type of product

• Delivery Period

• Offered Volume

• Activated Volume

• Bid Price

• Paid Price

• Was bid restricted

• Total volumes

• No later than 30

mins after TERRE

period

• Bid details

• PNs

• Ramp rates

• RRAs

• RRIs

• Restricted bids

• No later than 30

mins after TERRE

period

P344 and GC0097 Industry

Consultations

Elliott Harper – ELEXON Sophie Tilley – National Grid

BSC Modifications process

IWA prepared Proposer presents

Mod to Panel

Panel considers and agrees way

forward

Assessment

Procedure

With

Authority

Report Phase

Initial Written

Assessment

Modification

Raised

Decision

Workgroup

meeting(s)

Impact Assessment

(if required)

Workgroup

meeting(s)

Assessment

Procedure

Consultation

Panel considers

Assessment Report

Workgroup

meeting(s)

Panel makes initial

recommendation

Report Phase

Consultation

Panel considers

Modification Report

Panel makes final

recommendation

Authority receives

Final Mod Report

Authority considers

Modification Report

Regulatory Impact

Assessment

Authority Decision

25 Working Day KPI

Licensee Direction

Notice

56

Project TERRE industry day: Grid Code mod process

Overview of Consultations

■ GC0097 Industry Consultation period: 8 January 2018 – 26 January 2018

■ P344 Industry Consultation period: 10 January 2018 – 30 January 2018

■ Consultation documents can be found on the respective Code Modification pages

Why are we consulting?

■ Gather industry views on solutions that have been developed

■ Consultations are part of the formal BSC and Grid Code change processes

■ Workgroup considers consultation responses before making its recommendations

to the respective Code Panels

P344 Timescales ■ 10 Jan 2018 – 30 Jan 2018: P344 Industry Consultation

■ 7th Feb 2018 – 22 Mar 2018: Workgroup consider consultation and finalise

solution

■ 12 Apr 2018: BSC Panel considers Assessment Report

■ 16 Apr 2018 – 4 May 2018: Report Phase Consultation

■ 14 Jun 2018: BSC Panel considers Draft Modification Report

■ 18 Jun 2018 – 31 Jul 18: Authority considers Final Modification Report

Project TERRE industry day: GC0097 Timetable

8th January: Workgroup Consultation issued (Close 26th January)

7th Feb – 22nd March : Workgroups to review consultation responses and consider alternative options

26th April: Submit report to Grid Code Review panel

30th April: Code Admin consultation Report (close date ~ 22nd May 2018).

31st July: Authority decision

5th June: Draft modification report issued to industry and panel (5 working days)

14th June 2018: Final modification report presented to panel

21st June: Panel recommendation vote

26th June: Modification report submitted to the Authority

7th August: Implementation

TERRE Central project timelines and parallel run

Sophie Tilley

61

Project TERRE industry day: Project TERRE timelines

2016 2017 2018 2019

62

Project TERRE industry day: Parallel Run

The Parallel Run phase will aim to validate the Go-Live of the project and the TSOs participation to the Go-Live.

End-to-End test will be done. Chain tested: BSP-Connecting TSO-LIBRA (all TSOs and all services)-Connecting TSO-BSP/BRP.

Submission of standard offers

Clearing

Reception of results (Activation orders and Marginal Price)

Offers not activated

The Parallel duration will be fixed in Q3 2018. It should not exceed 6 months.

Simulation

Counter Activation

CBA

Settlement Models

Performance

TSOs intend to develop more on this topic during the workshop which will be scheduled in S2 2018.

P344/GC0097 Implementation

timescales

Elliott Harper – ELEXON

P344/GC0097 Implementation Timescales

■ Following Parallel Running, go-live window for the Central TERRE Project will

commence

■ TERRE product will be used for live balancing of the Transmission System and

payments made through Settlements

■ Implementation date therefore needs to account for this:

–Code implementation date expected to be Q2/Q3 2019

–GB go-live date expected to be Q3 2019

■ Hope to have further information by April 2018 on Central TERRE Project

progress

–More detail on the GB implementation framework will then become available

Question and Answer Session

Contact details

ELEXON:

■ Elliott Harper – Senior Change Analyst – [email protected]

■ Matt Roper – Market Architect – [email protected]

National Grid:

■ Sophie Tilley – European Markets Analyst – [email protected]

■ Bernie Dolan – EU Codes Development Manager -

[email protected]





Documents

TERRE Industry Day