Capacity Market Coordination Event - EMR Portal - … Markets Document...4 Electricity Market Reform...
Transcript of Capacity Market Coordination Event - EMR Portal - … Markets Document...4 Electricity Market Reform...
3
Electricity Market Reform
Delivery Body
In this section we will cover…
Capacity Market process and coverage of it today
Roles and responsibilities of delivery partners
The EMR Delivery Body’s engagement approach
The 2017/18 Operational Plan
4
Electricity Market Reform
Delivery Body
The end-to-end Capacity Market process
will be covered today…
1. Policy 2.
Capacity 3.
Prequal 4.
Auction 5.
Agreements 6.
Delivery
Arran Morni,
BEIS
Johannes
Pelkonnen
Ofgem
Gareth Lloyd
EMR DB
Faye Purchase
and
Dave Williams
EMR DB
Tim Dart
EMR DB
Emily Hirst,
EMR DB
Dave Preston
NGESO
Joy Nnamani
and
Abdal Hussain
EMRS
5
Electricity Market Reform
Delivery Body
The Capacity Market process is
delivered by five Delivery Partners…
The Electricity Settlements Company
provides control of the monies collected and
disbursed under the Capacity
Market (Payment) Regulations.
BEIS set CM
policy and
oversee changes
to policy.
Deliver settlement
and metering for
the CM on behalf
of ESC.
Government Regulator EMR Delivery
Body
Settlement
Body
Settlement
Services
Works to ensure that market
arrangements are fit for purpose.
It monitors the CM and manages
changes to the rules.
Delivery of the CM in line with the Rules and
Regulations and running the CM
auctions.
6
Electricity Market Reform
Delivery Body
Government sets policy…
Responsible for the Capacity Market
meeting its
objectives under Electricity Market
Reform.
Implementing, revising and reviewing CM legislation
Overall coordination of Capacity Market delivery
Decision of whether to hold CM auctions
Setting the auction parameters
Appeals addressed to the Secretary of State
7
Electricity Market Reform
Delivery Body
Ofgem regulates the market…
Ofgem works to ensure that
market arrangements are fit
for purpose and has a role in
facilitating changes to those
arrangements in the interests
of consumers.
Overseeing the role of the Delivery Body (DB)
Reporting on the operation of the CM
Monitoring the CM in line w/ Rules and Regulations
Determinations on disputes raised on DB decisions
Price Maker Memorandums
Review and revision of CM Rules
8
Electricity Market Reform
Delivery Body
National Grid are the Delivery Body of the
Capacity Market…
Responsible for the
implementation of the
CM in line with the
Rules and Regulations and
running the CM
auctions.
Co-ordinating CM operational activities across delivery
partners and capacity providers
Engaging with potential capacity providers on operational
issues and their participation in the CM
Producing the Electricity Capacity Report annually
Delivery of prequalification process and CM auction
Management of Capacity Agreements and CM register
Assessment of Satisfactory Performance of providers
9
Electricity Market Reform
Delivery Body
Settlements are managed by ESC and
operated by EMRS…
The Electricity Settlements Company is the Settlement Body and provides accountability, governance and control of the monies collected and disbursed under the Capacity Market (Payment) Regulations.
Making payments to Capacity Providers
Verifying, holding and monitoring credit cover from applicants
Meter assurance
Collecting monies from Suppliers to fund Capacity Payments
Monitoring Capacity Provider performance to enable the
calculation of Stress Event penalties
Volume Reallocation
10
Electricity Market Reform
Delivery Body We have listened to feedback and better
understand our customers…
We have held around 10 individual feedback sessions with our
customers
We continue to participate in a number of industry working groups
along with providers
In our latest customer satisfaction survey we were rated 7/10 or
higher by 77% of respondents
We welcome and receive regular feedback through day to day
engagement with providers
11
Electricity Market Reform
Delivery Body We have already acted on improvements
in some areas…
We have implemented a new team structure to be more customer
focussed through a dedicated engagement lead for each customer
We are refreshing our guidance for all processes to help our customers
prepare for each capacity market process
We have implemented the EMR admin portal and will aim to continuously
improve the usability of the system
We are streamlining our internal processes around agreement
management, starting with the customer in mind
We trialled two day auctions with shorter rounds for the Transitional
Arrangements Auction and, after success, will be keep this approach
12
Electricity Market Reform
Delivery Body
We are making commitments to deliver
lasting change…
Regular, consistent and personal engagement with engagement lead will drive
customer focussed change
Transformation of the prequalification readiness programme to support
applicants through their submissions
Targeted engagement with events, webinars and communications more relevant
to customer groups or individual organisations
Improved, plain English guidance for pre-auction, auction and delivery processes
Enhanced support through the disputes process from the engagement lead,
acting as primary point of contact
13
Electricity Market Reform
Delivery Body
The new CM team structure is designed to
deliver improved customer experience…
Matt Magill Capacity Market Manager
Laura Brock CM Implementation Manager
Chris Thackeray CM Delivery Manager
Ian Nicholas CM Delivery Manager
Tim Dart
Vikas Garg
Dave Williams
Faye Purchase
Richard Griffiths
Tim Gregory
Tushar Singh
Charlotte Watts Emily Hirst
Helen Mukkara
Vacancy
Vacancy
CM Front Desk
Heather Stratford
14
Electricity Market Reform
Delivery Body
Operational plan
July 17 Aug 17 Sept 17 Oct 17 Nov 17 Dec 17 Jan 18 Feb 18 March 18 April 18
Prequalification Submissions Window (10 weeks)
Prequalification Assessment Window (6 weeks)
13 Nov – 1 Dec Tier 1 Disputes Window
24 July – 29 Sept
2 Oct – 10
Nov
1st Dec Credit cover deadline 1*
22nd Dec Credit cover deadline 2**
30th Jan T-1 2018/19 Auction
6th Feb T-4 2021/22 Auction
Place your chosen image here. The four corners must just cover the arrow tips. For covers, the three pictures should be the same size and in a straight line.
BEIS overview – regulatory consultations
Arran Mornin
Vision and Objectives
BEIS Capacity Market
Consultation –
improving the framework
Arran Mornin
Head of Capacity Market Operations
Energy Security Team
August 2017
Details of the consultation
• The consultation was issued 24th July https://www.gov.uk/government/consultations/capacity-market-
consultation-improving-the-framework-detailed-proposals • Please respond with specific answers to the questions below by 8th
September, detailed drafting of SPD termination event and Storage de-rating will be released within the next few weeks to allow participants to comment before the end of consultation
• Handouts with the consultation questions have been circulated, let us know if you don’t have a copy
• Please direct all consultation responses to [email protected] • All consultation proposals are intended to be forward-looking. They would
not apply to current agreements and we envisage they would be in place ahead of the T-1 and T-4 auctions early in 2018
Upcoming events
• Storage de-rating workshop: this afternoon • Extra storage de-rating workshop: Tuesday 15th
August – Opportunity to submit written comments to NG by
22nd August
• BEIS Policy workshop on Tuesday 5th September – details to follow shortly
Storage de-rating factors Issue
• Ensuring delivery of capacity with changing technology
• 2016 T-4 Capacity Market (CM) auctions saw battery storage win agreements for the first time (around 500MW)
• The government believes that flexible technologies such as storage and DSR have a vital role to play in ensuring the UK has a secure, affordable and clean energy system now and in the future
• There is a mismatch between the duration that most batteries will be able to output for compared to the forecasted duration of stress events
• Initial estimates from National Grid suggest that stress events, if they do occur, could last up to two hours on average, although few are expected to last more than four hours
• The displacement of enduring capacity with short duration batteries risks undermining security of supply
Storage De-rating factor
30 mins maximum X%
1 hour maximum X%
1 hour 30 maximum X%
…. …
Proposal • De-rate storage according to the duration it can generate at its full connection capacity before recharging • Storage technology class to be split into categories differentiated by duration • Self-selection of duration category at pre-qualification with verification through new arrangements for
SPDs – transitional arrangements in place this year • Two proposals for assurance, to be implemented together or separately:
• OEM guarantee • Full capacity demonstrations
• DRFs to be based on Equivalent Firm Capacity (EFCs), factoring in the existing market penetration, technical reliability, and interactions with other commercial revenue streams as appropriate. Further consultation on this will be carried out by NG
Storage de-rating factors
Metering and DSR test deadlines Issue
• Ensuring delivery of capacity • Current metering and DSR test deadlines when applied to T-4 auctions mean we do not have an opportunity
to replace any lost capacity through the T-1 auction • High failure rate of Unproven DSR observed to date – 30% of TA DSR capacity
Proposal
• Bring forward metering and testing deadlines so that Unproven DSR secured through a T-4 auction fails early and to a timeframe which allows us to make good any shortfall by adjusting capacity targeted in the T-1 auction
• Ofgem proposal on DSR asset reallocation should help address likely aggregator concerns • Looking to explore any other proposals that industry has to ensure delivery
Deadline description Current deadlines
(Time before Delivery Year) Proposals
Date within T-4 schedule
Metering assessment 4 months 21 months 15 January
Metering test request
Metering test submission 2 weeks 18 months 1 April
DSR test 1 month 13 months 1 Sept
22
Satisfactory Performance Days
Termination Event Issue • CMUs must complete three SPDs during winter of the relevant delivery year (Rule 13.4.1) • Failure results in suspension of capacity payments until three further SPDs are completed • Consequence is that a CMU can retain a capacity agreement indefinitely despite failing to demonstrate that it is
capable of fulfilling its obligations
Proposal (for T-1 18/19 agreements and T-4 2021/22 agreements onwards) • CMUs must complete three SPDs during winter of relevant delivery year, at least one of the three must be
demonstrated in the period January to April • Failure results in suspension of capacity payments until three further SPDs completed, in the same delivery year • Failure to demonstrate the further SPDs results in the obligation being terminated • Termination fee is set at TF5 (£35k/MW), equivalent to loss of TEC • Providers are able to ask National Grid to reconsider the termination, and appeal the termination to Ofgem or
the Secretary of State • Incorporating changes to termination events and portfolio amendments made by Ofgem in recent consultation • Government will be releasing indicative drafting that explains interaction with Secondary Trading
Metering re-assessment Issue
Metering re-assessment is not envisaged in CM rules and regulations and this poses a problem when: • A Capacity Provider wishes to change its metering configuration • A Capacity Provider makes mistakes in its first application for a metering
assessment Proposal
• We want to enable Capacity Providers to go through re-assessment and therefore provide more flexibility and align legislation to the policy intent made clear in the March FAQ
https://www.gov.uk/government/publications/capacity-market-rules
Planning consent
Issue • The T-4/T-1 planning consents deadline falls between Christmas and New Year’s Eve • The applicant must submit to the DB the declaration by no later than the date falling 22
working days prior to the commencement of the first bidding window • On the date falling 16 working days prior to the commencement of the first bidding
window the DB must notify the applicant in relation to each CMU to state if it has prequalified or not
Proposal • We intend to shift this deadline to January to provide more flexibility to NG and avoid a
significant amount of time during the period between Christmas and New Year’s Eve.
Generating Technology Class Issue • Ofgem has consulted on adding Generating Technology Class to the public CM register • To make this resource as useful as possible we will seek to partly disaggregate the current
technology classes to ensure that plant types are appropriately captured
Proposal • Improving the recording of information in much the same way we are doing for Primary Fuel
Type • Splitting grouped technology types to aid analysis. For example, OCGTs and reciprocating
engines are currently grouped together
Current Technology Class Proposal
Coal/Biomass Coal
Biomass
Energy from Waste
OCGT and Reciprocating Engines Reciprocating Engines
OCGTs
Indicative proposed split:
BEIS Capacity Market Consultation-
Improving the framework
Please direct all consultation responses to
1. The CM Rules change process
2. 2016-17 CM Rules change process
3. Ofgem’s other roles in the CM
4. Next steps
5. Questions
Overview of CM governance
CM Regulations
CM Rules
BEIS manage Regs and also change Rules
Ofgem manage Rules
Overarching design
Practical / policy detail on how the CM operates
The CM rules change process
Open letter inviting proposals
Form and guidance available on our
website
Receipt of proposals (all published online)
Consideration of proposals submitted by
stakeholders – analytical process
Ongoing work on our own proposals
Consultation
Review of consultation responses, refinement of drafting, and final
decisions
Laying before Parliament
Implementation by NGET and ESC
2016-17 CM Rules change process
79 industry proposals received
4 Ofgem proposals Consultation in
March 41 responses
Decision in July 21 amendments, 4 to consider further
Consolidated Rules published in late
July
• Handling disputes, including for prequalification and termination decisions
• Monitoring and taking enforcement action if needed
• Overseeing NGET’s delivery of EMR roles, including financial incentives
• Reporting on the operation of the CM and the performance of NGET – 2 annual reports
• Receiving Price Maker memoranda
Ofgem’s other CM roles
• 2017-18 CM Rules change process to begin in near future
• Open letter will be published during Q2
• We look forward to your proposals
• Don’t be afraid to engage with us early
Next steps
Contact: [email protected]
Place your chosen image here. The four corners must just cover the arrow tips. For covers, the three pictures should be the same size and in a straight line.
Electricity Capacity Report 2017
Duncan Rimmer
Agenda
Summary
Modelling developments since 2016 ECR
Recommended capacity to secure for 2021/22
Recommended capacity to secure for 2018/19
Interconnected country de-rating factor ranges for 2021/22
Conventional plant de-rating factors
Questions
36
Summary – the why and what Licence obligation to submit Electricity Capacity Report (ECR) to BEIS before 1st June. ECR published
on 7th July
This year’s ECR contains two capacity requirement recommendations for 2018/19 (T-1 auction) and 2021/22 (T-4 auction)
To reflect the risks around early coal closures, embedded benefits and unproven DSR, our modelling continues to include non-delivery sensitivities
Enhancements this year include over-delivery sensitivities representing additional imports and capacity staying open without a CM contract.
Modelling scrutinised by BEIS, Ofgem & BEIS’s Panel of Technical Experts (PTE)
We also provide in the ECR conventional plant de-rating factors and ranges of de-rating factors in 2021/22 for interconnected countries
The Secretary of State determines:
the capacity to secure and, for 2021/22 the split between T-4 and T-1 auctions
the auction parameters including the demand curve
individual interconnector de-ratings for use in the CM auctions
38
Summary – capacity to secure key points ECR uses probabilistic modelling of a range of scenarios and sensitivities and a Least Worst Regret (LWR) decision tool to
select recommended capacity to secure:
Recommendation for 2021/22 is 50.5 GW compared to 49.7 GW for 2020/21 in 2017 ECR
Covers 19 out of 24 cases modelled (including all FES and up to 2 GW non-delivery). Secretary of State’s decision consistent
with recommendation. He decided to hold back 0.4 GW for the T-1.
Recommendation for 2018/19 (6.3 GW) significant increase over the 2.5 GW held back in 2014 for the T-1 auction, but less
than the 7.3 GW indicative target in the 2016 ECR
Covers 17 out of 26 ̃cases modelled. Secretary of State decided to target 6.0 GW as per PTE’s recommendation. This is within the confidence interval of the calculation
*2018/19 secured figure allows for known CM contract cancellations and connection capacity higher than de-rated TEC ^2018/19 requirement excludes interconnection as interconnectors not allowed to participate. 2.1 GW imports assumed at peak in 2018/19 ˜ Including 3 out of 4 FES scenarios and sensitivities up to 1.2 GW non-delivery, but excluding Two Degrees , low availability and cold winter
39
Year Base Case Eligible
Capacity Requirement
(GW)
Capacity already
secured (GW)
Assumed non-
delivery in LWR outcome (GW)
Recommended
requirement (GW)
Secretary Of
State’s Decision (GW)
2021/22 (T-4) 52.8 -4.3 +2.0 50.5 50.1 (T-4)
0.4 (T-1)
2018/19 (T-1) 51.6 ̂ -46.5* +1.2 6.3 6.0
Summary – de-rating factors We provide range of interconnected countries’ de-rating factors from which Sec. Of State decides de-rating factor for each
interconnector to use in the CM for 2021/22
Top of range based on National Grid’s Bid3 modelling. Bottom based on Pöyry's historical modelling (France, Netherlands
and Belgium) or Bid3 modelling (Norway and Ireland). Decision includes adjustment for technical availability
Conventional plant de-rating factors generally similar to or slightly higher than 2016
Project in progress for summer to investigate de-rating factors for energy limited storage – separate session this afternoon
set aside for this.
40
Country 2021/22
(2017 ECR)
2020/21
(2016 ECR)
2019/20
(2015 ECR)
2017/18
(2016 ECR) Interconnector Decision
(2021/22)
France 48-80% 45-88% 50-70% 45-86% IFA (2 GW)
IFA 2 (1 GW)
Eleclink (1 GW)
63%
65%
69%
Ireland 29-98%* 25-50% 2-10% 2-58% Moyle (0.5 GW)
EWIC (0.5 GW)
14%
59%
Netherlands 75-81% 70-82% 62-80% 70-82% Britned (1.2 GW) 76%
Belgium 65-85% 65-92% 58-70% n/a NEMO (1 GW) 75%
Norway 92-99% 76-96% n/a n/a NSL (1.4 GW) 85%
* The 2021/22 range for Ireland not adjusted for import constraints.
Summary of modelling developments since last year
Additional / Expanded sensitivities
Non-delivery sensitivities account for new policy risk (PTE recommendation 21) on embedded benefits, observed non-delivery of unproven DSR as well as coal closure risk
Inclusion of over-delivery sensitivities representing additional imports and capacity staying open without a CM contract.
Interconnector modelling
Development of in-house pan-European modelling of interconnector flows (PTE recommendation 13) via procurement of Pöyry’s Bid3 pan-European model
Investigation into alternatives to Least Worst Regret (LWR)
Review of strategy and sensitivity probabilities (PTE recommendations 17 & 25) led to hybrid approach (discussed in ECR Annex). Not utilised as no material impact
Use of distributed generation (DG) data (Electralink)
Acquired DG data (PTE recommendation 22). Limited use due to capacity data quality issues. Some use in non-CM de-ratings and demand forecasts
42
2021/22 – LWR decision from range CM eligible capacity is total capacity minus capacity receiving support via RO, CfD or FiTs
The chart shows the level of CM capacity required in each scenario and sensitivity to meet the Reliability Standard of 3 hours LOLE in 21/22.
It excludes any CM plants with 3, 12, 14 or 15 year contracts from the18/19, 19/20 and 20/21 T-4 auctions assumed to operational in 2021/22
LWR outcome and recommendation is 50.5 GW (requirement for 2G MW non-delivery sens)
44
2021/22 waterfall from 2020/21
49.7
48.5
50.5
-2.0
-0.3-0.0
-4.4
+3.5
+1.0
+0.4
+0.5
+0.1
+2.0
45
46
47
48
49
50
51
52
53
2020/2021requirement (BC
Non Delivery2000)
Non DeliveryAssumed InSensitivity
PreviouslyContacted2020/2021
ACS peakdemand
Reserve reqt(largest infeed
loss)
Derated margin Non-CMcapacity,
ROC/CFD
Non-CM Autogen Previouslycontracted2021/2022
Assumed NonDelivery in Base
Case
Base Case2021/22
requirement
Least WorstRegret Decision
(Non deliveryscenario 2000)
LWR 2021/222recommendation
Cap
acit
y t
o p
rocu
re, G
W
45
The following waterfall chart shows how the original 49.7 GW recommendation for 2020/21
(derived from the 2016 Base Case 2 GW non-delivery sensitivity) has changed into total
CM-eligible requirement of 50.5 GW (derived from the 2017 Base Case 2 GW non-delivery
sensitivity):
2021/22 – key points Sensitivity range 46.2 - 52.5GW (lowest: Slow Progression, highest: Non-delivery 4 GW)
For 2021/22, we recommended a target capacity of 50.5GW, a small increase (0.8 GW) on the 2020/21 recommendation in the 2016 ECR
This small increase is the result of following upsides and downsides:
Upsides - higher Base Case peak demand, lower assumed non-CM autogeneration, slightly higher de-rated margin,
slightly lower assumed renewable de-rating factors
Downsides - higher previously contracted capacity in Base Case, reduction in reserve for largest infeed loss, slightly
higher renewable capacity (matching reduction in de-rating factors),
The inclusion of non-delivery sensitivities has ensured uncertainty has been addressed and resulted in a similar level of security of supply to other years
Secretary of State decided to target 50.5 GW for 2021/22, consistent with the recommendation in the ECR
Secretary of State decided to hold back 0.4 GW for T-1 auction leaving 50.1 GW target for the T-4 auction.
Pre-qualification to determine adjustments required e.g. opted out plant that will remain operational or plants with different closure assumptions to the Base Case
46
2018/19 – LWR decision from range
48
The chart shows the level of CM capacity required in each scenario and sensitivity to meet
the Reliability Standard of 3 hours LOLE in 2018/19.
It excludes CM plants with contracts from the 18/19 T-4 auction assumed to operational in
2021/22
LWR outcome is 6.3 GW (requirement for 1.2 GW non-delivery sensitivity).
2018/19 waterfall from original 18/19 T-1 requirement
49
The following waterfall chart shows how the original 2.5 GW set aside for the 2018/19 T-1
auction (derived from the 2014 Slow Progression Low Availability sensitivity) changed into a
recommendation of 6.3 GW (derived from the 2017 Base Case 1.2 GW non-delivery
sensitivity):
2.5
5.1
6.3
-0.2
-2.1
-2.0
-0.7
+1.1
+2.1
+1.7
+2.7
+1.2
0
2
4
6
8
10
12
2014 ECRoriginal T-1
requirement (fromSP Low Avail.
Sensitivity)
ContractedCapacity -
Derated TEC
Opted out andoperational plant
Existingcontracted plantnon-delivery in
base case
ACS peakdemand
Derated margin(derating factorslow availability)
Interconnectorflow
Non-CM capacitychange
Additional T-4capacity due to
low clearing price
Base case 2017ECR T-1
requirement
Least WorstRegret Decision
(Non deliveryscenario 1200)
LWR 2018/2019Recommendation
Cap
acit
y to
secu
re, G
W
2018/19 – key points
Sensitivity range 3.4 GW - 7.9 GW (lowest: Warm Winter, highest: Non-delivery 2.8 GW)
18/19 T-1 auction recommendation has increased from that originally set aside by the Secretary of State in 2014 from
2.5 GW to 6.3 GW
This is due to the following upsides & downsides:
Upsides - “opted out but operational” plant closing or opting in, non-delivery of contracted plant, connection capacity being
higher than TEC and higher end user demands due to additional distribution connected plant, wider sensitivity range than in 2014 ECR
Downsides – Additional distribution plant being non-CM, additional capacity procured in T-4 auction above target and higher
import assumptions
Imports have increased based on the interconnector de-ratings utilised for 17/18 and 19/20 auctions as opposed to the
original float assumption
The inclusion of non-delivery sensitivities have increased the recommendation since 2014 as the T-4 analysis didn’t
include such sensitivities
Secretary of State decided to target 6.0 GW as per PTE’s recommendation. This is still within confidence interval of the
calculation of the recommended capacity.
Pre-qualification to determine adjustments required e.g. opted out plant that will remain operational or plants with
different closure assumptions to the Base Case
50
Country de-rating factor ranges
France, Netherlands, Belgium France: 48 to 80
Netherlands: 75 to 81
Belgium: 65 to 85 52
Country de-rating factor ranges
Ireland, Norway
Ireland: 29 to 98
Average of FES simulations sets the top of the range for Ireland. The bottom of the range is set by Base Case Low Ireland. It is not appropriate to use the history to set the bottom of the range because none of the forecast sensitivities are as low.
Norway: 92 to 99
53
2017 Conventional plant de-rating factors
Technology class Plant types included 2018/19 T-1 2021/22 T-4
Oil-f ired steam generators Conventional steam generators using fuel oil 88.04% 88.04%
OCGT and reciprocating engines (non-
autogen.)
Gas turbines running in open cycle f ired mode
Reciprocating engines not used for autogeneration 94.81% 94.81%
Nuclear Nuclear plants generating electricity 85.24% 85.24%
Hydro
Generating Units driven by w ater, other than such units:
(a) driven by tidal f low s, w aves, ocean currents or geothermal sources; or
(b) w hich form part of a Storage Facility
87.92% 87.92%
Storage
Conversion of imported electricity into a form of energy w hich can be stored,
the storing of the energy w hich has been so converted and the re-
conversion of the stored energy into electrical energy
Includes hydro Generating Units w hich form part of a Storage Facility
(pumped storage hydro stations).
96.11% 96.11%
CCGT Combined Cycle Gas Turbine plants ‘88.54% 90.00%
CHP and autogeneration Combined Heat and Pow er plants (large and small-scale)
Autogeneration – including reciprocating engines burning oil or gas 90.00% 90.00%
Coal / biomass / w aste Conventional steam generators using coal or biomass or w aste 87.58% 87.58%
DSR 86.34% 86.34%
55 We are keen to hear your feedback on how we determine conventional plant de-rating factors.
Should we continue with / evolve the current approach or should we do something different?
57
Electricity Market Reform
Delivery Body
Prequalification
Timeline
Upcoming milestones
Prequalification readiness surgeries
Themes from surgeries so far
Feedback from surgeries
58
Electricity Market Reform
Delivery Body
Prequalification timeline
24 July
Prequalification window opens
29 September
Prequalification window closes
2 October
Prequalification assessments begin
24 July – 22 September
Prequalification readiness “surgeries”
25 – 29 September
Final week of Prequalification
window
59
Electricity Market Reform
Delivery Body
Upcoming milestones
Milestone Date
Prequalification submissions window of 10 weeks
24 July – 29 September
Prequalification assessments will last for 6 weeks
2 October – 10 November
Tier 1 disputes 13 November – 1 December
T-1 2018/19 Auction 30 January 2018
T-4 2021/22 Auction 6 February 2018
60
Electricity Market Reform
Delivery Body
Prequal readiness surgeries
A face-to-face meeting with members of the CM team
Delivered in locations suited to you
Surgeries allocated on a first come, first served basis
One surgery per company
Make the most of your sessions – Pre-requisites
Spaces still available
61
Electricity Market Reform
Delivery Body
Themes of queries from surgeries so far
Connection
agreements
Planning
consents Auxiliary load
Extended
Years Criteria
Metering
arrangements
Primary Fuel
Type Credit cover
62
Electricity Market Reform
Delivery Body
Feedback from surgeries
Prequalification
Guidance
Come with
questions
94% increased
confidence in their
Prequalification
Application
"Most stressful
thing I've done in
my life (CM)"
"This approach is
the best thing
you've done so
far"
"I'm pretty sure
that if I didn't come
here I would have
made mistakes"
Place your chosen image here. The four corners must just cover the arrow tips. For covers, the three pictures should be the same size and in a straight line.
Auction Readiness and Secondary Trading
Vikas Garg
64
Electricity Market Reform
Delivery Body
Agenda
Auction Guidelines
Secondary Trading and Volume Reallocation
Questions
66
Electricity Market Reform
Delivery Body
Auction Parameters
Parameter T-1 (2018/19) T-4 (2021/22)
15 year threshold n/a £260/kW
3 year threshold n/a £130/kW
PriceCap £75/kW/yr £75/kW/yr
NetCone £49/kW/yr £49/kW/yr
Price Taker Threshold £25/kW/yr £25/kW/yr
Target Capacity 6GW 50.1GW
Capacity at the price cap Target capacity -1.0GW Target -1.5GW
Capacity at £0/kW/year Target capacity +1.0GW Target +1.5GW
67
Electricity Market Reform
Delivery Body
Capacity Demand Curve
05
1015202530354045505560657075
43,500 44,500 45,500 46,500 47,500 48,500 49,500 50,500 51,500 52,500
£/k
W/Y
Capacity Demand (MW) Target Capacity at Net CONE T-1 6GW
Price Cap
Price Taker
Threshold
68
Electricity Market Reform
Delivery Body
R1
R2
R3 R4
R5
R6
R7
R8
R9
All in at Price
Cap
Supply reduces as price drops
Auction Clears
when supply meets Demand
Capacity Demand Curve
69
Electricity Market Reform
Delivery Body
Auction Process
Eligible participants who do nothing at auction will get an agreement
at the clearing price
Exit bid takes you out of the auction (unless your exit bid is equal or
less than the clear price)
Duration Bid amendment used to change agreement length (to 1
year)
Duration Bid amendment used to change from refurb to pre-refurb
Auction System is internet based
70
Electricity Market Reform
Delivery Body
Auction and Delivery year timeline
Dec1
4
Jan
15
Dec 15
Jan
16
Oct
16
Dec
16
Jan
17
May
17
Oct
17
Dec
17
Jan
18
Oct
18
Dec
18
Jan
19
Oct
19
Dec
19
Jan
20
Oct
20
Dec
20
Jan
21
Oct 21 Dec
21
Jan
22
CM delivery year1 18/19
CM delivery year 1 19/20
TA delivery year 16/17
TA delivery year 17/18 TA Auction
CM delivery years 2-15
CM delivery years 2-15
(18/19) T-1
(19/20) T-1
EA delivery year 17/18 EA Auction
TA/EA
T-4 2018/19
T-4 2019/20
CM delivery year 1 20/21
CM delivery
years 2-15
T-4 2020/21
(20/21) T-1
CM delivery year 21/22 T-4 2021/22
(21/22) T-1
71
Electricity Market Reform
Delivery Body
Auction results to date
T-4 2018/19 £19.40
T-4 2019/20 £18.00
T-4 2020/21 £22.50
TA1 2016/17 £27.50
TA2 2017/18 £45.00
EA 2018/19 £6.95
72
Electricity Market Reform
Delivery Body
Overview of typical auction
T-10 wks T-4wks Auction T+20
Prequalified
for Auction
Training
-web based
screen cast
Auction
results
Participate
in auction
Bidder setup
Passwords +
PIN
Confirmation
s at T-15 to T-
10
Auction
Monitor
Report
(Clear+2)
Capacity
Agreement
Notice
Participate
in Mock
auction
74
Electricity Market Reform
Delivery Body
CM obligation hedging options
Auction participants with a
Capacity Agreement may
be unable to deliver
(planned or forced
outages) have the
following options to hedge
position;
1. Physical secondary
trading (ex ante)
2. Volume Reallocation
(ex post)
3. Parties are free to
procure a financial
product outside of the
Capacity Market
mechanism.
75
Electricity Market Reform
Delivery Body
Secondary Trading - Requirements
Minimum requirements required for Transferor and Transferee
Min time period 1 day
Min volume 2MW
Can carry out multiple transfers - within de-rating
The holder of an obligation across winter (even 1 day) will need to prove
Satisfactory Performance Days - NB If full delivery year traded out then SPD not required
76
Electricity Market Reform
Delivery Body
Secondary Trade – who?
An Acceptable Transferee is any of the following:
Prospective CMU that has achieved the Substantial Completion Milestone prior
to the Delivery Year *
A Capacity Provider of a CMU that Prequalified but does have a Capacity
Agreement *
CMU Opted-out at the T-4 Auction and has since Prequalified in the T-1
An Eligible Secondary Trading Entrant (table discussion)
*most likely scenario
77
Electricity Market Reform
Delivery Body
Early Auction delivery year
April May June July Aug Sep Nov Dec Sep 18
Oct
2017
Webinar and training material
launch
Secondary Trading Entrant - apply to prequalify for ST
(not during auction prequalification)
Secondary Trading Contact details published
Secondary Trade Registration to DB
Auction PQ
Volume reallocation
Trading Timeline
78
Electricity Market Reform
Delivery Body
Oct Nov Dec Jan Feb Mar Apr May Jun Jul
Aug Sep Oct A Transferor
B Transferee CM Obligation
Winter Outage Feb, March,2018
Acceptable Transferee -takes
on the Mar, April obligation
Stress Event Responsibilities Event 1 Party A
Event 2 Party B
Event 3 Party A
1 2 3
CM obligation CM obligation from trading
Stress event
Transfer Must be
initiated at least
5Wd before start of
period
CM Obligation
Secondary Trading example
79
Electricity Market Reform
Delivery Body
Why trade?
Value of obligation trading;
For every HH non-delivered (during a stress event) lose
= 1x 24th annual payment
In any month max loss is capped at 2 months payments
(i.e. 4HH non delivery in a stress event)
Delivery year max loss = 100% capacity payment
81
Electricity Market Reform
Delivery Body
Volume Reallocation
Ability to cover obligation post stress event with registered participant.
Meet the acceptable transferee requirements
Register to be CMVR registered participant in advance of delivery
period
Capacity volume register updated WD10
Allocate volume to Submit a CMVRN WD 11-19
84
Electricity Market Reform
Delivery Body
Key milestones: Pre - Auction
July 17 Aug 17 Sept 17 Oct 17 Nov 17 Dec 17 Jan 18 Feb 18 March 18 April 18
Prequalification Submissions Window (10 weeks)
Prequalification Assessment Window (6 weeks)
13 Nov – 1 Dec Tier 1 Disputes Window
24 July – 29 Sept
2 Oct –
10 Nov
1st Dec Credit cover deadline 1
22nd Dec Credit cover deadline 2
30th Jan T-1 2018/19 Auction
6th Feb T-4 2021/22 Auction
85
Electricity Market Reform
Delivery Body
Key milestones: Pre - Auction and Agreement Management
July 17 Aug 17 Sept 17 Oct 17 Nov 17 Dec 17 Jan 18 Feb 18 March 18 April 18
Prequalification Submissions Window (10 weeks)
Prequalification Assessment Window (6 weeks)
13 Nov – 1 Dec Tier 1 Disputes Window
24 July – 29 Sept
2 Oct –
10 Nov
1st Dec Credit cover deadline 1
22nd Dec Credit cover deadline 2
30th Jan T-1 2018/19 Auction
6th Feb T-4 2021/22 Auction
31st Aug Metering
Assessments: DSR CMUs
31st Aug DSR Tests
1st Oct start of Delivery Year
Deadline for demonstrating Satisfactory Performance 30th April
15th Aug 6 monthly reports
1st Oct SCMs for EA 2017 Prospective CMUs
21st Nov FCMs for T-4 2020/21 Prospective CMUs
30th Sept Metering
Assessments: Prospective CMUs
86
Electricity Market Reform
Delivery Body
Six monthly construction progress reports
Prospective CMUs with agreements in the 2017 EA must submit the
construction progress report documents by the 15th August.
Update on Construction Milestones, a report from an Independent
Technical Expert, and a certificate from 2 directors of the Applicant
company. Upload documents to the EMR portal.
We will check the Construction Milestone dates and report any issues to
BEIS, with a focus on MW at risk.
Who needs to
complete?
What is
required?
What will the
Delivery Body
check?
15th Aug six monthly construction report deadline for EA 2017 CMUs
87
Electricity Market Reform
Delivery Body
Metering Assessments
Upcoming deadlines are for Unproven DSR and New Build CMUs
with EA 2017/18 and TA 2017/18 agreements.
Answer the questions on the EMR Portal and upload Single Line
Diagram.
The DB will assess the requirement for a Metering Test.
Who needs to
complete?
What is
required?
What will the
Delivery Body
check?
31st Aug Metering Assessment deadline: Unproven DSR CMUs
30th Sept Metering Assessment deadline: Prospective
CMUs
88
Electricity Market Reform
Delivery Body
DSR Tests
Who needs to
complete? Unproven DSR CMUs with EA 2017/18 and TA 2017/18 agreements.
Before requesting a DSR Test via the EMR Portal, please ensure data
flows are set up with EMRS.
The DB will inform the control room and request the metered data from
EMRS. Once received, we will perform the DSR Test analysis.
What is
required?
What will the
Delivery Body
check?
31st Aug DSR Test deadline
89
Electricity Market Reform
Delivery Body
Substantial Completion / Financial Commitment Milestones
Prospective CMUs
with EA 2017/18
agreements.
90% of AACO
achieved, metering
assessment complete.
Check and update, if
required, the AACO.
Who needs to
complete
SCM?
What is
required?
What will the
Delivery Body
check?
Prospective CMUs
with T-4 2020/21
agreements.
10% of total project
spend and major
contracts entered into.
Check against Prequal
application to ensure
£/kW threshold is met.
Who needs to
complete
FCM?
What is
required?
What will the
Delivery Body
check?
1st Oct SCM deadline for EA 2017 CMUs
21st Nov FCM deadline for T-4 2020/21 CMUs
90
Electricity Market Reform
Delivery Body
Satisfactory Performance Monitoring
All CMUs participating in each Delivery Year
Submission of 3 separate dates on which the CMU met the capacity
obligation between 1st October and 30th April
The DB will request the metered data from EMRS. Once received, we
will compare the output to the AACO and let you know the outcome via
the EMR Portal.
Who needs to
complete?
What is
required?
What will the
Delivery Body
check?
Deadline for demonstrating Satisfactory Performance 30th April
Place your chosen image here. The four corners must just cover the arrow tips. For covers, the three pictures should be the same size and in a straight line.
Metering, EMR Aggregations and Volume Reallocation
EMRS
Disclaimer
Please note that whilst this document has been prepared with due care
by EMR Settlement Limited on behalf of the Low Carbon Contract
Company and the Electricity Settlement Company Limited , EMR
Settlement Limited, Low Carbon Contract Company and Electricity
Settlement Company Limited do not make any representation, warranty
or undertaking, express or implied, in relation to the completeness and
or accuracy of information contained in this document, and accordingly
EMR Settlement Limited, Low Carbon Contract Company and Electricity
Settlement Company Limited shall not be liable for any damages
resulting from the use of this information or action taken in reliance on
it.
Capacity Market Coordination Event_10 August 2017
• Overview
• Volume Reallocation Scenario
• Timetable
• Capacity Volume Register
• Capacity Market Volume Reallocation
Notification
• Notifications from EMRS
• Settlement
Volume
Reallocation
Capacity Market Coordination Event_10 August 2017
Overview Volume Reallocation and parameters are covered in Chapters 8 and 10 of the
Capacity Market Rules.
A process where Capacity Providers may reallocate volume (in MWh) for any Settlement
Period that is part of a Stress Event from one over-delivering CMU to another under-
delivering CMU.
Capacity Providers have the opportunity to reduce the amount of Penalty Charges they
owe.
Volume reallocation window opens 10 Working Days after the end of a month in which a
Stress Event occurs.
Capacity Providers who have over or under delivered may trade volume between each
other.
Capacity Market Coordination Event_10 August 2017
Eligibility
Capacity Agreement
holders are eligible to take
part in volume reallocation
during the Delivery Years
that they hold an
agreement.
The Capacity Market Rules
Amendment 2017, opened
up volume reallocation to
Capacity Providers who do
not hold an agreement for
that Delivery Year.
Pre-requisites to become a CMVR Registered Participant with the Delivery Body:
Successfully prequalified*; or
Qualified as Secondary Trading Entrants.
EMRS require Capacity Providers to have completed:
Capacity Provider Registration;
Validated Aggregation Rules; and
Approved Metering.
* Substantial Completion Milestone (SCM), Proven DSR Capacity and Metering Assessment – Full details in the Delivery Body guidance on Volume Reallocation Registration.
Responsibilities
Capacity Market Coordination Event_10 August 2017
EMRS Delivery Body Capacity Providers
Publish the Capacity Volume Register (CVR)
Identify acceptable transferees Identify CMUs to trade with
Receive, match and validate trades Maintain a register of Capacity Market Volume Reallocation Participants
Complete and submit CMVRNs
Republish the CVR every day with new positions while the reallocation window is open
Pay Penalty Charges for any outstanding Under-Delivery volume
Calculate and invoice for Penalty Charges and Over-Delivery payments when the window closes.
Capacity Market Coordination Event_10 August 2017
Volume Reallocation Scenario Stress Events have occurred at periods 1, 2 and 3 in the Delivery Year.
CMU A under-delivered during 2 and 3.
CMU B over-delivered during all three Stress Events.
CMUs agree to trade, CMU B Over-Delivery in period 3 to make up CMU A shortfall.
CMU A and B complete and send Capacity Market Volume Reallocation Notification Notices
to EMRS to volume reallocate.
CMU B
(CMVR Transferor
)
CMU A
(CMVR Transfere
e)
EMRS
Validate and
match
MWh, per Settlement Period
Capacity Volume Register
Capacity Volume Register includes:
Capacity delivered by a CMU (i) during
the Settlement Period (j), (E);
Adjusted Load Following Capacity
Obligation (ALFCO);
(if any) Initial Over-Delivery Volume
(IOD);
(if any) Initial Under-Delivery Volume
(IUD);
Aggregated traded Capacity Market
Volume (ACMV); and
Adjusted metered output (AE), which is
equal to E plus ACMV.
Capacity Market Coordination Event_10 August 2017
Settlement Date Settlement Period CMU ID E ALFCO IOD IUD ACMV AE27/04/2017 33 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 33 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 34 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 34 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 35 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 35 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 36 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 36 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 37 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 37 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 38 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 38 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 39 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 39 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 40 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 40 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 41 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 41 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 42 ENG_01 300.02 200 100.02 0 -100.02 20027/04/2017 42 GEN_12 0 120 100.02 19.98 100.02 100.0227/04/2017 43 ENG_01 197.48 100 97.48 0 -97.48 10027/04/2017 43 GEN_12 0 110 97.48 12.52 97.48 97.4827/04/2017 44 ENG_01 197.48 100 97.48 0 -97.48 10027/04/2017 44 GEN_12 0 110 97.48 12.52 97.48 97.4827/04/2017 45 ENG_01 197.48 100 97.48 0 -97.48 10027/04/2017 45 GEN_12 0 110 97.48 12.52 97.48 97.4827/04/2017 46 ENG_01 197.48 100 97.48 0 -97.48 10027/04/2017 46 GEN_12 0 110 97.48 12.52 97.48 97.48
Capacity Market Coordination Event_10 August 2017
Format This illustrates the format of the Capacity Market Volume Reallocation
Notification (CMVRN).
Cell reference A B C
1 [EMR Party ID of the Company who is submitting]
2 CMVRN_[transferor CMU ID]_[transferee CMU ID]
3 [From EMR Party ID] [CMU ID] 4 [To EMR Party ID] [CMU ID] 5
[Settlement Date e.g. 27/04/2016] [Settlement Period e.g. 33] [volume to 3 d.p. e.g.-100.025]
[repeat for each Settlement Period] [repeat for each Settlement Period] [repeat for each Settlement
Period]
Capacity Market Coordination Event_10 August 2017
Things to remember! When completing a Capacity Market Volume Reallocation Notification
(CMVRN), worth remembering the following:
Trading CMUs must each submit CMVRNs with matching data items
The volume in the transferor’s file should always be negative and the volume in the
transferee’s file should always be positive
You can include multiple Settlement Periods in one CMVRN
Volume should be expressed in MWh
An initially over-delivering CMU cannot trade an amount so that their remaining Over-
Delivery exceeds the Initial Over-Delivery Volume or lead to them under-delivering
An initially under-delivering CMU, cannot trade an amount so that their remaining Under-
Delivery exceeds the Initial Under-Delivery Volume or lead to them over-delivering
Completed CMVRNs are emailed to [email protected]
Capacity Market Coordination Event_10 August 2017
Notifications from EMRS Once EMRS has validated the CMVRN’s received, EMRS will confirm:
1. You will receive an email to confirm your trade has been successful or unsuccessful
2. If unsuccessful, the email will contain the reasons why your CMVRN was not accepted
While the volume reallocation window is open you can re-submit the CMVRN.
Capacity Market Coordination Event_10 August 2017
Timeline for Volume Reallocation
EMRS will calculate and issue Credit Notes for Over-Delivery as soon as practicably possible after the end of the
Delivery Year
Capacity Market Coordination Event_10 August 2017
Settlement
When the volume reallocation window has closed, EMRS will calculate penalty charges for
CMUs with a remaining Under-Delivery amount.
The invoice will be issued on the 21st Working Day of the month following the month in
which there was a Stress Event.
Over-Delivery Payments are calculated and paid at the end of the Delivery Year
when all Under-Delivery Penalties have been received from Under-Delivering Capacity
Providers.
Under-Delivery Penalty “Pot” is used to pay Over-Delivery Payments.
In the event, no Penalty Payments are received as a consequence of a System Stress
Event then no payments for Over-Delivery are made.
Capacity Market Coordination Event_10 August 2017
Volume Reallocation
Would you like
to participate in
any testing?
ESC and EMRS would like to give
Capacity Providers the opportunity to
suggest how, if at all, they would like to
test the volume reallocation process.
We’d welcome your feedback.
More information
For Volume Reallocation
WP48 - Volume Reallocation https://www.emrsettlement.co.uk/publications/working-practices/
EMRS Service Desk
[email protected] 020 7380 4333
Volume Reallocation Registration Guidance
https://www.emrdeliverybody.com/cm/home.aspx Capacity Market Coordination Event_10 August 2017
CM Metering
10 August 2017
Iain Nicoll
Metering Identifiers and Aggregation Rules Metering Pathways
Public
Capacity Market Coordination Event_10 August 2017
• What is this activity?
• What is the format of the template?
• Let’s go through an example
• How will the process work?
Metering Identifiers
and Aggregation
Rules for the
2017/18 Delivery
Year
Capacity Market Coordination Event_10 August 2017
What is the activity?
To be able to perform the settlement activity in the Capacity Market EMRS, require the
Metering Systems set up for the CMU.
We need to be able to identify the correct Metered Volumes to be used for each CMU ID and
each CMU Component.
We need to know what we should do with those Metered Volumes to correctly determine the
Capacity Obligation has been met.
Capacity Providers will be asked to complete a template.
A separate template for each Capacity Provider and for each Auction and CMU Category (e.g.
Existing Generating CMUs).
1.Existing Generating and Proven DSR CMUs
2.Unproven DSR, Prospective and Interconnector CMUs
Guidance on how to complete the template will be attached to the email.
Capacity Market Coordination Event_10 August 2017
What is the format of the template?
• The grey cells will be pre-populated.
Row No.
CMU ID Component
ID Change
Flag Effective
Date Metered
Entity Type Metered Entity ID
Multiplier Distributor
ID LLFC ID
Boundary Point MPAN /
MSID
Balancing Services ID
Address of CMU Component
1 ABCD ABCD01 01/10/2017 123 Main Street,
London, SW12 3DE
Identifies whether
NEW or an Update
Identifies type of
Metering System:
• BMU
• Supplier Settlement
• Non-BSC
• Interconnector
Identifies Metered Volumes via
BMU ID, MPAN, Interconnector
ID. For non-BSC this must
match the CSV file identifier
Identifies shared demand
circuits, ineligible generation
(e.g. low carbon subsidised or
part of another CMU) to be
netted off another Metering
System
Only completed for non-BSC Metering
Systems where the site is embedded within
a site connected to a Distribution System
Allows Line Losses to be applied to Metered
Volumes
Identifies whether the CMU Component
is involved in any Balancing Services
To account for Balancing Services
actions during a Stress Event
Capacity Market Coordination Event_10 August 2017
Let’s go through an example • One Component making up the CMU that has an Import and Export MPAN
Row
No. CMU ID
Component
ID
Change
Flag Effective Date
Metered
Entity Type Metered Entity ID Multiplier Distributor ID LLFC ID
Boundary Point
MPAN / MSID
Balancing
Services ID Address of CMU Component
1 ABCD001 ABCD001 NEW 01/10/2017 MPAN 1200087654321 1.00 X Power Station, UK
• Complete the pre-populated row for the CMU Component ID for one of the
MPANs
• Insert a second row for the other MPAN and copy the pre-populated details into this row
2 ABCD001 ABCD001 NEW 01/10/2017 MPAN 1200012345678 1.00 X Power Station, UK
Capacity Market Coordination Event_10 August 2017
How will the process work? The process that will be followed during the Metering Identifiers and Aggregation Rules
activity is outlined below.
EMRS will email Capacity Providers a template per Auction and CMU Category.
CMU ID, Component ID, Effective Date and the address of the CMU Component will be
pre-populated. Any issues with the pre-populated data, please contact the Delivery Body.
Capacity Providers email the completed template to [email protected].
EMRS validate and any issues identified we’ll contact the Capacity Provider to resolve.
EMRS confirm back to the Capacity Provider once successfully validated.
Once all CMU’s are validated both Delivery Body and EMRS upload the required data.
Aggregation Rules will be loaded into the EMR Settlement System.
Any queries please email [email protected].
Capacity Market Coordination Event_10 August 2017
• Have you started preparing setting
up your metering pathways?
• Set up data flows for your MSIDs
• Do you know the format of the CSV
file for self submission?
• Set up a SFTP account with EMRS to
be able to self submit
• Where is more information
available?
Metering Pathways
Capacity Market Coordination Event_10 August 2017
Setting up a Metering pathway There are three options: • Balancing Mechanism Units (BMU)
• Supplier Settlement (MPAN)
• Self submission CSV (Balancing Services and
Bespoke)
Capacity Market Coordination Event_10 August 2017
Settlement Metering
Systems BM Units
EMRS automatically receives
BMU data via the Settlement
Administration Agent.
Capacity Provider has to take
no action.
If the BMU is being split the
CMU becomes Bespoke and the
self submission pathway must
be used.
MPANS
Capacity Provider must contact the Supplier to
establish the data flows.
You may require to do this for both the Import
and Export MPAN. These may have different
Suppliers.
Capacity Market Coordination Event_10 August 2017
Format of the CSV file Defined CSV format must be used to uploaded data into the EMR Settlement System. The
CSV file will be checked as part of the Metering Test process.
Capacity Market Coordination Event_10 August 2017
Setting up an SFTP account To be able to submit CSV files with Metered Volumes for your CMUs you will need to have a
Secure File Transfer Protocol (SFTP) account with EMRS.
Email the Service Desk [email protected] to request a Secure File Transfer
Protocol (SFTP) account and provide the following details:
Contact name
Email address
Mobile number
Within 5 WDs EMRS will issue a username, password and the address of the SFTP site.
Username and password will be sent separately.
More information
For registering as a Capacity Provider and setting up an EMR Party ID: WP22 – Applicant & Capacity Provider Registration
For Metering Pathways and the CSV file:
WP195 – Capacity Market and CFD Metered Data https://www.emrsettlement.co.uk/publications/working-practices/
EMRS Service Desk
[email protected] 020 7380 4333
Capacity Market Coordination Event_10 August 2017
Capacity Market Notices
1,700+
subscribers 2 CMNs
31 Oct / 07 Nov
0 EMNs
issued
Website and
Purpose
16/17 Winter
Outturn
Survey
Results
Summary
• gbcmn.nationalgrid.co.uk operational from 01 October 2016
• Designed to increase awareness of tight system, not a dispatch tool
• Some evidence of change in behaviour but likely to be consistent with what would be expected with TRIAD warning
• Difficult to draw conclusions of appropriateness of CMN process to date
• Generally benign winter, further supported by SBR contingency
• 17/18 to be more representative as first discrete CM only period
• Elexon introduced new System Warning Alert service
Failed CMN on 20 June
124
CMN Cancellation published in isolation at 15:08 on 20 June ‘17
CMN website updated with Message from SO at 15:51
Linked to an Emergency Preparedness Exercise with DNO
Failure tracked to website certificate authentication issue
Issue fixed, enhanced monitoring, general lessons learned
Business Process, Systems and Emergency Exercise reviews
Discussion with Ofgem re CM Rules and Emergency Exercises
Future of Capacity Market Notices
125
No change to CMNs in 2017 CM Rules
Conscious of call for additional CMN data
Concerned about potential confusion with other information
CMN remains simple tool, not a dispatch for Stress Event
Likely flow of events for true capacity issue (not DCE or LF)
Here to help, inform and discuss options in break / afternoon
Opportunity exists to update FAQs on website as appropriate
Likely signposts prior to capacity challenge
CMN
Triggers
Margin below threshold set out in Capacity Market Rules
Demand Reduction Instruction
Low Frequency
Disconnection
CMN published following unexpected event giving 4 hrs grace
CMN published 4 hours in advance of higher risk period of Stress Event
Day Ahead Within Day Real Time
Wholesale Prices
DA De-rated
Margins (DRM)
8hr
DRM
2 – 14 Day Ahead
Demand
Control Event
1 2 3
Information sources and likely flow of events in advance of Capacity driven challenge
2-14 DA National Surplus Data (peak SP)
Day and Day Ahead Margins (by SP)
Operational Warnings
(EMN, HRDR, DCI)
CMN 4hr, 2hr, 1hr
DRM
Available on BMRS Warming Instructions
on SONAR