Offshore Transmission Coordination Project Conclusions Report
Offshore Transmission: Industry Briefing - Ofgem · Offshore Transmission: Industry Briefing...
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Offshore
Transmission:
Industry Briefing
7 October 2011 Offshore Transmission Workshop
23 January 2013
Purpose
www.ofgem.gov.uk
Open discussion of ongoing policy development
Chatham House rules (non attributable)
focus is on good ideas, not company positions
nothing said today is binding
Consultation and decision papers set out our positions - we look
forward to formal responses
Context
www.ofgem.gov.uk
Offshore Platform
Offshore Transmission Owner (OFTO)Onshore TO Generator
Connection to onshore network
132 kV Cable33 kV Inter Array Cables
Onshore Substation
PAC/NAO
reports NSCOGI/
Renewable
trading
EMR &
CfDs Brown &
Laidlaw
reports
Project
bond /
guarantees Financial
markets PF2 &
review
of RPI
Update on tender rounds 1 and 2
www.ofgem.gov.uk
Round Project Status
1
Barrow (90MW) Closed (September 11)
Robin Rigg (East & West) (180MW) Closed (March 11)
Gunfleet Sands (I &II) (173MW) Closed (July 11)
Sheringham Shoal (315MW) PB appointed
Ormonde (150MW) Closed (July 12)
Greater Gabbard (504MW) PB appointed
Thanet (300MW) PB appointed
Walney I (184MW) Closed (October 11)
Walney II (184MW) Closed (September 12)
2a
Lincs (270MW) PB appointed
London Array (630MW) PB appointed
Gwynt-y-Mor (576MW) ITT underway
2b West of Duddon Sands PQ underway
Tender round ‘3’ and beyond
www.ofgem.gov.uk
Policy development via consultation during 2012
Legal framework developed
Expect next tenders to be Generator build, starting from mid
2013
In discussions on OFTO build – more welcome
Looking ahead to coordination and hybrid projects
First half of 2013 is drawing together lessons & setting out
refreshed approach
Regulating transmission Aims
Development of economic and efficient network
Value for money for present and future consumers
outputs, innovation and incentives
Components of infrastructure applied to electricity transmission:
Design System design
Asset design
Build Procure Need for
Project manage Scope for competition? coordination
Finance Debt and equity
Operate Availability
System operation
Overview of current licence policy consultation
www.ofgem.gov.uk
Published end Nov 2012, closes 22 Feb 2013
Focused on following elements of Generator build licence (intention to
focus on OFTO build licence later in 2013):
Policy area Proposal
Revenue framework Keep 20 yr revenue term (but will review for
integrated networks)
Refinancing 2 possible options:
i) no gain share mechanism (status quo);
i) gain share mechanism
Indexation of revenue to RPI 3 possible options:
i) 100% indexation (status quo);
ii) Biddable indexation;
iii) Fixed proportion indexed
Overview of current licence policy consultation
www.ofgem.gov.uk
Policy area Proposal
Availability incentive Preferred option of capacity weighting
mechanism
Detail of mechanism tbc over coming months
(to be covered in today’s final workshop)
Incremental capacity
incentive
Intention to remove current minor
remuneration term.
Intention to retain current 20% remunerated
capex term, but keep under review
Transmission losses View that losses mainly influenced by
transmission asset design rather than
operation
Agenda
www.ofgem.gov.uk
10.35 – 12:15: Coordination policy (Jon Parker)
Workshop 1: User Commitment Changes
Workshop 2: Gateway Process for anticipatory
investment
12.15 – 13.00: Lunch
13.00 – 14.30: Cost Assessment workshop session (Roger Morgan)
14.30 – 15.15: Energy Bill implementation: generator
commissioning clause (DECC – Duncan Stone;
Ofgem – Alison Russell)
15:15 – 15.30: Coffee break
15.30 – 16.30: Optional: Availability incentive workshop session
(Hannah Evans)
10
Offshore Transmission
Coordination Project
Jon Parker
Senior Manager, Offshore Coordination Policy
Offshore Transmission Coordination
Jon Parker
www.ofgem.gov.uk
Joint Coordination Project during 2011/12 to assess the potential costs, risks
and benefits that may arise from the development of a coordinated offshore
and onshore electricity transmission network
This found that increased coordination could be beneficial, particularly for
larger and more distant from shore projects
The project also considered potential barriers that could hinder efficient
coordination opportunities being taken forward under the current regulatory
regime
As a result, Ofgem published a consultation in March 2012 setting out
possible changes to the offshore regime to better support efficient network
coordination
In July 2012 Ofgem published an open letter providing an update on our
thinking and seeking further industry views
Context
www.ofgem.gov.uk
„It is vital that offshore networks are considered in conjunction with onshore
networks in order to achieve a coordinated national transmission system that
efficiently integrates all generation sources, both onshore and offshore.‟
‘Each zone has to be considered on its merits and timing of decision points‟
„The issue of anticipatory capital investment needs to be addressed... A
robust and consistent process is required to evaluate the options for
anticipatory investment at each decision point.‟
„The potential savings from integrated development [£0.5-3.5bn] are most
significant under the most ambitious generation developmental scenarios, with
the corollary that anticipatory investment and stranding risk is also greatest in
absolute terms‟
Potential benefits and risks of coordination
Potential benefits and risks of coordination
www.ofgem.gov.uk
Potential barriers identified
• NETSO‟s role in connection offer process
• Enhancements to ODIS Designing an
efficient network
• Clarity on framework for coordinated investments within the OFTO regime – main focus of our consultations
Anticipatory investment
• TNUoS methodology needs to reflect coordinated offshore networks
• Changes made to user commitment through CMP192
Charging and user
commitment
• Clarity on regulatory treatment for generation and transmission that sit across different regimes
Regulatory interfaces
• Devolved matter
• DECC and CLG considering guidance on associated development in E&W
Consenting
• Industry-led groups discussing standardisation Technology
www.ofgem.gov.uk
GFAI
Category 1: Generator-Focused Anticipatory
Investment (GFAI)
Investment led by a developer which would enable the
later connection of specific future offshore generation, e.g.
through oversizing.
Category 2: Developer-led Wider Network Benefit
Investment (Developer-led WNBI)
Investment led by developers providing wider network
benefit, e.g. reinforcement of the wider network (onshore
or offshore) through, for example, boundary transfers via
offshore links.
Category 3: Non developer-led WNBI
Investment in wider network benefit assets not related to a
specific connection offer or where the developer(s) do not
have the appetite to develop the project.
Framework for coordinated investment -
proposed investment categories
www.ofgem.gov.uk
Our December 2012 consultation put forward:
Potential changes needed to the user commitment framework to
appropriately share costs and benefits of Generator Focussed
Anticipatory Investment (GFAI) whilst adequately protecting consumers
An Ofgem gateway process at pre-construction and construction stages
for assets requiring Wider Network Benefit Investment (WNBI), linked to
our current cost assessment process
Allow a potential route to fund TOs for carrying out pre-construction works
through RIIO
These proposals are intended enable greater coordination where economic
and efficient, working with current industry and Ofgem processes where
practical
Current consultation
www.ofgem.gov.uk
Investment routes walk-through
Generator-build OFTO-build Generator-build OFTO-build
Ofgem
tenderOfgem tender
Ofgem
tender
Construction
Works
Construction
Works
Construction
Works
Construction
Works
Construction
Works
Construction
Works
Ofgem
tenderOfgem tender Ofgem tender
Cost recovery
for pre-
construction
and
construction
works,
Constructed
and
commissioned
assets enter
operational use
Constructed
and
commissioned
assets enter
operational
use
Constructed and
commissioned
assets enter
operational use
Constructed
and
commissioned
assets enter
operational use
Constructed and
commissioned
assets enter
operational use
Constructed
and
commissioned
assets enter
operational
use
Key Developer NETSO Onshore TO
OFTO Ofgem Proposed new
process
*presented from the lead developer's perspective, that is, the developer
undertaking the GFAI on behalf of a later generator**Potential process, subject to further development
Ofgem tender
Construction Works
Constructed and
commissioned assets
enter operational use
Generator-build OFTO-build OFTO-build (lead option)
Ofgem gateway 1
Ofgem gateway 2 Ofgem gateway 2
Preliminary works Preliminary works Preliminary worksPreliminary works
with cost recovery
Straightforward radial
connections for a single
phase windfarm
Connections with GFAI*Connections with
developer-led WNBI
Non developer-led
WNBI**
Connection Application Connection Application Connection Application
Connection Offer Connection Offer Connection Offer
Ofgem gateway 1
Background system planning plus optioneering for connection
leads toidentification of GFAI for
second generator
Background system planning plus optioneering for connection
leads toidentification of WNBI and
development of high-level needs case
Background system planning plus optioneering
leads toidentification of
WNBI and
development of high-level needs case
Background system planning plus optioneering for connection
Connection Agreement
Transfer of
preliminary
works assets,
including WNBI
elements
Transfer of preliminary
works assets
Transfer of
preliminary
works assets,
including GFAI
elements
Transfer of assets
Transfer of assets,
including WNBI
elements
Transfer of assets,
including GFAI elements
Connection Agreement Connection Agreement
User commitment for onshore works for developer's needs
User commitment for onshore works for developer's needs
User commitment
for offshore works for
developer's
needs
User
commitment
for offshore
works for
developer's
needs
User
commitment
for offshore
works for
developer's
needs
User
commitment for GFAI for later generation
project applies post transfer
User commitmentfor onshore works for
developer'sneeds
User commitment
for GFAI secured from
later generator
www.ofgem.gov.uk
Workshop 1: potential changes to user commitment to support coordination
Overview of why user commitment changes may be needed [10 mins]
Break out group discussions of key questions [25 mins]
Feedback [15 mins]
Workshop 2: gateway approach
Overview of potential gateway approach [5 mins]
Break out group discussion of key questions [25 mins]
Feedback [15 mins]
Factsheets on your tables provide an overview and useful diagrams/tables for reference
Workshop structure
18
Offshore Transmission
Coordination Project
Jon Parker
Senior Manager, Offshore Coordination Policy
Potential changes to user commitment
to support offshore coordination
What issues need to be addressed?
www.ofgem.gov.uk
Stranding risk
• Clear and appropriate allocation
• Protection of consumers
Cost recovery
• Greater certainty for developers undertaking coordinated investments
Options considered and impacts addressed
www.ofgem.gov.uk
Developer
(builder)
Later Generator Consumer
User commitment
type
arrangements
Greater certainty
on cost recovery,
subject to cost
assessment
Provides user
commitment for
assets built for its
benefit
Protected as
onshore
Up front cost
benefit
assessment
Greater certainty
on cost recovery,
subject to cost
assessment
Does not allocate
stranding risk to
party best placed
to manage it
Minimal protection
provided to
consumers
Additional cost
assessment
criteria in the
tender exercise
No improvement
to certainty of cost
recovery as reliant
on later generator
Does not allocate
stranding risk to
party best placed
to manage it
Protected as
assets only
transferred if later
generator meets
criteria
Current offshore user commitment liabilities
Wider liability
(zonal charge)
Attributable
liability: onshore
TO works *
Attributable
liability:
Offshore
transmission
assets
OFTO build
Generator build
* In the event that the offshore transmission assets connect directly into an onshore substation, and
no work is required by the onshore TO, there would no attributable liability under generator build.
GSP
Nearest existing MITS node
Generator build
OWF
1
OWF
2
Current user commitment arrangements under
Generator build
www.ofgem.gov.uk
No gap - developer bears construction cost for its first and
later project(s)
Potential gap – OFTO pays developer for
transmission assets, does developer then
provide user commitment for its later
project(s)?
Gap - lead developer bears constructions
costs for other party‟s later project(s), other
party does not provide user commitment
Potential gap – OFTO pays developer for
transmission assets, does second generator
then provide user commitment for its later
project(s)?
Single party
Multiple parties
Pre-transfer to OFTO
Post-transfer to OFTO
Round Table discussion and feedback
www.ofgem.gov.uk
Question 1:
Do you agree that user commitment arrangements offer the best way to provide
greater certainty to developers on cost recovery for GFAI assets while protecting
consumers?
Question 2:
Have we identified the right gaps in current user commitment arrangements and are
there any barriers to addressing these?
24
Offshore Transmission
Coordination Project
Jon Parker
Senior Manager, Offshore Coordination Policy
Proposal to support developer-led wider network benefit investment: Ofgem
gateway assessments
www.ofgem.gov.uk
Proposed approach
Key barrier: lack of clarity on how developer-led WNBI will be treated during a
tender exercise
We are currently consulting on:
Introducing two voluntary Ofgem assessment gateways as part of a tender
exercise to give developers early clarity on our approach to cost assessment
At gateways Ofgem would review rationale for including the WNBI in a
developer‟s design solution at both preliminary works and construction stage
We are also seeking views on the potential to support some types on low cost
WNBI outside gateway assessment, through setting a de minimis threshold. This
is subject to further work but we welcome early stakeholder input.
www.ofgem.gov.uk
Proposed approach
Consultation sets out proposals for:
• A role for the NETSO and TO‟s in supporting the needs case for WNBI at the
gateway assessments and in monitoring changes in the needs case
• Assessment criteria including: economic needs case; timing, scope and
technical readiness; proposal for ETSO-developer engagement; developer‟s
commitment to triggering a tender exercise
• Timing of gateways will be flexible and triggered by developers when they
have sufficient information to enable us to conduct an informed assessment
www.ofgem.gov.uk
Round table discussion and feedback
Question 1:
What needs to be addressed for gateways to work effectively?
Question 2: What are your views on how a de minimis threshold should work, while ensuring consumers are not exposed to significant stranding risk?
28
www.ofgem.gov.uk
Consultation closes on 1st March – encourage formal responses
Intend to publish final proposals in key areas this spring, with further policy
development and implementation actions expected over the coming year
We are keen to continue engaging closely with industry on potential changes
needed to the industry frameworks to ensure these happen as quickly as
possible, including on integrated TNuOS charging and user commitment
Next steps
29
Offshore Transmission
Coordination Project
Jon Parker
Senior Manager, Offshore Coordination Policy Cost Assessments
Roger Morgan
Agenda
Xx
www.ofgem.gov.uk
Summary of progress to date
Cost assessment guidance document
Developments to the cost assessment process breakout sessions on the
following:
Process improvements
Assessing transmission asset design
Use of benchmarking
We will conclude today‟s session with feedback from each breakout group
Progress to date
Completed cost assessments: Barrow, Robin Rigg, Gunfleet Sands, Walney I &
II and Ormonde
We are progressing final cost assessments: Sheringham Shoal, London Array,
Greater Gabbard, Lincs and Thanet
Key themes/issues:
cable installation cost overruns
IDC adjustments (duration/imposition of caps)
cost allocations between generation & transmission assets
developers require clarity and guidance on process
Ofgem’s cost assessment guidance
This document covers the following:
Guidance on our cost assessment process that will apply to all cost
assessments
The range and types of issues that are considered in cost assessments
How we determine whether costs and economic and efficient
We intend to keep this guidance under review and will update this
periodically
Cost assessment process development
Key Issues:
emerging technologies
pressure to drive down costs per MWh
flexibility in our approach e.g. early engagement and certainty over
treatment of costs
to respond to these challenges and policy developments elsewhere
will require further thinking of how we conduct cost assessments
Today‟s workgroups will discuss:
Group 1: Process improvements
Group 2: Assessing transmission asset design
Group 3: Benchmarking
Breakout groups
30 minute task:
Each group to discuss questions and discussion points that have
been prepared
Record findings on flipcharts provided
Pick a spokesperson to present findings
Each group in turn to explain findings to the wider group
Ofgem will summarise and set out proposed next steps
35
Offshore Transmission
Coordination Project
Jon Parker
Senior Manager, Offshore Coordination Policy
Energy Bill implementation:
The Generator Commissioning clause
Alison Russell & Duncan Stone
Agenda
1. Overview of generator commissioning clause – DECC
• Background
• Purpose
• Scope
• Duration of exception
• Means of implementation
2. Implementation of generator commissioning clause – Ofgem
• Modification of Codes & Agreements
• Completion Notice
• Expected Code and Licence Changes
3. Questions
Background
OFTO-builders will have a transmission licence in advance of commissioning
However, generator-builders will have a generation licence, so cannot also
obtain a transmission licence
The completion notice concept, utilised in the clause, is already part of the
legislative framework
Purpose
The clause amends section 4 of the Electricity Act 1989 to create an
exception in certain circumstances to the prohibition of participating in the
transmission of electricity without a transmission licence
The exception will:
provide generator-builders with confidence that they can commission
transmission assets lawfully
ensure that renewable electricity can continue to flow
facilitate the timely transfer of transmission assets to OFTOs
enable the full commencement of the offshore transmission regime
Scope
The exception can apply in relation to generator-build projects that are
qualified into a tender exercise but are not yet transferred to an OFTO
A transmission system is considered generator-built if it is or has been
constructed or installed by one, or a combination of, the following:
The current developer in relation to the tender exercise and who is
operator of the generating station
An associated body corporate of the current developer
A previous developer
An associated body corporate of the previous developer
A sub-contractor of the above
The exception could apply to projects that are „in flight‟ at entry into force,
and their 18 months would start to run on receipt of a completion notice.
Duration of Exception
This is described as the “commissioning period” and comprises:
The period before a completion notice is issued in respect of a
transmission system; and
18 months starting on the day the completion notice is issued
One completion notice will be issued in relation to each qualifying project‟s
transmission system, so if the qualifying project is staged the notice will not
be issued until it is possible to make all stages available for transmission
The draft clause consulted on last summer allowed 12 months for transfer
post-completion notice, but this was amended as a result of feedback
However the 18 months can be reduced to 12 between 2–5 years after entry
into force, though would only apply to projects yet to be qualified
Means of implementation
The clause will come into force 2 months after Royal Assent. We currently
anticipate Royal Assent by the end of 2013.
For the clause to be effective, it is likely that there will need to be changes to
licences, codes and/or agreements
These documents will need to be reviewed holistically and, if necessary,
changed speedily, which does not lend itself to standard industry processes
The SoS power to make such changes expires on 17 April 2013
Rather than extend those powers, Government recognises Ofgem‟s
expertise in this area and decided to grant it a specific, targeted power to
amend relevant codes and agreements following consultation.
Agenda
1. Overview of generator commissioning clause – DECC Background
Purpose
Scope
Duration of exception
Means of implementation
2. Implementation of generator commissioning clause – Ofgem Modification of Codes & Agreements
Completion Notice
Expected Code and Licence Changes
3. Questions
Modification of Codes or Agreements
• The clause includes powers for the Authority to modify codes (or the
agreements which give effect to them) where the modifications are
necessary or desirable to implement this clause
• The powers last for 7 years
• The Authority must consult, which can be done prior to the passing of the
Energy Act 2013, and provide reasons after making such modifications
• Licence modifications must be made using existing processes
Indicative timelines – subject to Parliament
Bill passes through both Houses and amendment stage during 2013
Royal Assent - anticipated
end 2013
Code changes identified Informal
consultation Formal
consultation
Codes modified
post assent
Licence changes identified Informal consultation Statutory
consultation Licence Direction
Aligned to codes
Stakeholder engagement during identification and consultation processes
Completion notice
• Concept already exists in the Transmission Licence
• A completion notice (CN) is given to the Authority by the co-ordination licence
holder (NETSO) and sets out that it would be possible to transmit electricity
by making the system available
• Further work is needed on exact timing of CN issuance, but:
• Our initial view is on completion of Stage 2 acceptance (or equivalent)
for the last stage of the qualifying project
• The arrangements will need to ensure commissioning is equivalent to
the TO standards as the assets become (OF)TO assets.
• These standards are currently set out in the STC or NGET internal
documentation
Expected Code & Licence changes - 1
Currently, formal transmission commissioning obligations and processes sit
within STC/STCPs or NGET internal documents
Only SO/TOs are signatories to STC, generators are not party to or
bound by it
Generator commissioning is carried out under auspices of the relevant
commissioning panel
As assets ultimately become transmission assets, the commissioning
requirements for generator developers must meet the same standards as
those imposed on TOs
NGET & Ofgem are working through the possible impacts of the
commissioning requirements on industry codes
Expected Code & Licence changes - 2
Detailed evaluation ongoing and will be consulted upon, however, some
changes have initially been identified
Commissioning process equivalents to STCPs will need to be applied to
developers – current thinking is that this might best sit under the Grid
Code and relevant associated documents
Some changes may be needed to other industry codes and documents,
not yet defined, and changes would be minimised where possible
Codes which are not expected to need changes:
STC – but it may provide source material
Distribution codes
Minor changes may be required to the NGET Transmission Licence and
possibly Generation Licence conditions, but this is still under evaluation
Expected Code & Licence changes - 3
Change process:
We expect to consult and engage with stakeholders on changes
We welcome input to identify changes and issues, formally and
informally
We would like to understand stakeholder preference for engagement: for
example
Seminar(s) plus informal/formal written consultations; or
A stakeholder (non-decision making) group which meets at regular
intervals – perhaps bi-monthly plus formal consultation
If a stakeholder group type approach - to make it practical, a
smaller group of representatives would be helpful
Representatives‟ commitment would be essential in surfacing
issues and debating potential solutions
Agenda
1. Overview of generator commissioning clause – DECC
Background
Purpose
Scope
Duration of exception
Means of implementation
2. Implementation of generator commissioning clause – Ofgem
Modification of Codes & Agreements
Completion Notice
Expected Code and Licence Changes
3. Questions
For discussion during questions:
1. Is Stage 2 Acceptance (or equivalent) the best trigger for the issue of the
Completion Notice?
2. Transmission commissioning arrangements are set out in the STCPs –
equivalent arrangements could be applied to generators via the Grid Code,
does that cause any concern – if so, what?
3. If not via the Grid Code/essential licence changes, what would be the best
way to formalise these arrangements
4. Is there a preferred way to engage with industry stakeholders on this work?
a. Informal and formal consultation ?
b. Formal consultation plus working group (non decision making)?
Illustration of a phased project
Phase 2
Onshore
Substation 1
Onshore
Substation 2
Wider electricity
transmission
system
Offshore
Substation
Platform 1
Offshore
Substation
Platform 2
= Stage 1
= Stage 2
= Stage 3
Key:
Notes:
1) Three distinct stages of the
transmission asset build out.
2) Build out of stages occurs
consecutively with stages
electrically linked.
3) Stages 1 & 2 provide capacity to
carry export power.
4) Stage 3 adds additional security to
transmission system.
Phase 1
Onshore
Substation 3
Offshore
Substation
Platform 3
Phase 1 Phase 2
= Single stage
52
Offshore Transmission
Coordination Project
Jon Parker
Senior Manager, Offshore Coordination Policy
Availability Incentive
Hannah Evans
Context
www.ofgem.gov.uk
Reviewing incentive mechanism to ensure it is fit for purpose for future projects
Building on:
May 12 consultation
Stakeholder feedback
Further internal analysis
Propose to adopt capacity weighting mechanism
Incentivises behaviour that maximises export, while retaining a simple
mechanism providing an appropriate risk profile for OFTOs.
Retain the 10% and 50% revenue caps
Not retrospective
Overview of capacity weighting proposal
www.ofgem.gov.uk
0% 20% 40% 60% 80% 100%
Pen
alt
y
Capacity of outage
axb
a = intercept point where a = 1 is the status quo. We expect a ≥
1
b = steepness of curve where b=1 is a straight line, and as b
increases so does the steepness. We expect
b ≥ 1
x = capacity of outage where 100% means that the transmission
system is completely unavailable, and for
example 25% means that only one of four
circuits is unavailable.
Note that we propose that for now, the same weighting level will apply to all OFTO
configurations, so that there would not be a bespoke weighting for each OFTO.
Capacity weighting proposal - Example
www.ofgem.gov.uk
0% 20% 40% 60% 80% 100%
Pen
alt
y
Capacity of outage
axb
5
20
25
Outages and Penalties
For outages of 1 hour:
100% outage (4 cables) = 25 penalty points
50% outage (2 cables) = 5 penalty points
25% outage (1 cable) = 1 penalty point
Comparison
100% outage (4 cables) for 1 hour = 25
penalty points
Vs.
4x 25% outages (1 cable) for 1 hour each = 4
penalty points
Example: 4 parallel export cables of equal capacity.
Planned and unplanned outages differential
www.ofgem.gov.uk
Feedback and analysis suggests that there may be merit in differentiating
between planned and unplanned outages, where unplanned outages were
penalised more than planned outages.
We do not currently propose to introduce a differential in penalties between
planned and unplanned outages, but we would welcome feedback on whether
this could be of benefit in the future.
We are particularly keen to understand your views on whether a mechanism
such as this could and would have a positive impact on OFTO behaviour, and
also what impact it may have on the bids at tender stage.
Use of TEC as measurement of maximum availability
www.ofgem.gov.uk
As outlined in our November 12 consultation, TEC may not be an appropriate
measure of maximum availability in the future. This applies to the more
integrated networks in particular.
Although we do not currently propose to move away from using TEC, we would
welcome your views on what the key issues and benefits are for using TEC as
the measure for maximum availability.
This includes what additional considerations (if any) should be made to more
integrated networks.
We also welcome views and comments on what other measures could be used
instead of TEC in the future.
Future plan
www.ofgem.gov.uk
Consultation closes on 22nd February
Position statement due in Spring 2013
First draft of licence, including availability incentive algebra due later in 2013
Model to be published alongside the draft licence
Ongoing work on integrated networks considerations (including use of TEC)
Overview of key points for discussion
www.ofgem.gov.uk
What are your views on whether to introduce a penalty differential between
planned and unplanned outages?
What should the penalties be for differing capacity outages?
i.e. Do you have any views what are the optimum/possible values of the
intercept point (a) and the steepness of the curve (b)?
How might the availability incentive need to change (if at all) to take account of
integrated offshore networks?
Going forward, do you think that the use of TEC for maximum availability will
remain appropriate?
Increasing steepness (b)
Increasing intercept point (a)