transmission systems improved regulation and management
TRANSCRIPT
Spanish Fund for Latin America and the Caribbean
Consulting: Conceptual Frameworks Proposals
Thematic Line 4:Transmission Systems Improved Regulation
and Management, and InterconnectionsAlberto Pototschnig and Guido Cervigni
June 25th 2021
Presentation Session of Final Report
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Propose conceptual models and frameworks
for improving the regulation and
management of the Peruvian transmission
system
First stage towards a While Paper/Book for
the Reform towards the Modernization of the
Peruvian Electricity Sector
Project objectives
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Agenda
1Objectives pursued and variables of choice for the organization of the
electricity transmission sector
2 The regulatory framework and the organisation of Peru’s transmission sector
3 Issues with the current arrangements and recommendations
Appendix: lessons from the international experience
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Agenda
1Objectives pursued and variables of choice for the organization of the
electricity transmission sector
2 The regulatory framework and the organisation of Peru’s transmission sector
3 Issues with the current arrangements and recommendations
Appendix: lessons from the international experience
The relevant objectives
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Effective planningMinimum
investment costs
Efficient use of
existing assets• Technical capabilities
• Effective forecast of
demand and generation
• Unified view of the
entire network
• Procurement of network
components and
engineering services
• Cost of capital
• System operator has
full control of assets
• Optimal maintenance
strategy
Coordination among
multiple planners
Incentives for
sub-transmission
concession holders
Competition for the
market vs regulation
Incentives and
resources for
government-owned
distributors
Variales of choice for transmission organisation
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Perimeter of transmission
and sub-transmission
• Sub-transmission like distribution vs sub-
transmission like backbone transmission
Industry structure
• ISO vs TSO model
• Functional vs legal vs ownership unbundling from
generation, retail (and distribution)
Organisation of supply of
transmission services
• Auctions to select TOs and set allowed revenues
vs regulated monopoly
Network development
decisions• Planned vs merchant vs both models
Dimension Options
• Relative importance of coordination sub-
transmission/distribution or sub-transmission/transmission
• No clearly superior model between ISO and TSO
• Need for strong independence of SO-TSO
• Merits of competitions vis à vis regulation
• Coordination issues in case of fragmentation of asset
operations
• Planning is indispensable
• Interaction between planned and merchant development may
be complicated
• Merchant sensible way to address projects with uncertain value
Tariff structure• Congestion management via nodal electricity
prices vs other tariffication methodologies
• Relative importance of sending efficient price signals vs other
objectives pursued by transmission tariffs and electricity prices
(fairness among consumers at different locations)
Drivers of the choice
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Agenda
1Objectives pursued and variables of choice for the organization of the
electricity transmission sector
2 The regulatory framework and the organisation of Peru’s transmission sector
3 Issues with the current arrangements and recommendations
Appendix: lessons from the international experience
The institutions
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The institutional framework is in line with international practice (see Thematic line 1 on
issues reCOES independence)
Government
Independent regulator
Independent System Operator
Overview of the current regulatory and organisation framework
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Transmission
Sub-transmission
PlanningImplementation (default /alternative
mechanism)
COES
(Plan de transmisión)
Competitive tenders /
Iniciativa privada
Concession holders
(Planes de inversión)
Regulation: assigned
by OSINERGMIN /
Competitive tenders
Redes no
planificadasPrivate developers Private developers
Allowed revenues
(default /alternative
mechanism)
Tender’s bid /
Regulation: standard
cost
Regulation: standard
cost /
Bid in the auction
Private agreement /
OSINERGMIN in
case of disputes
The general logic of the model is sound
Issues in implementation
Industry structure: transmission
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Nombre de la compañía (Grupo)
KM de líneas (HV o HHV)
Capacidad del transformador MVA
Zona
ISA Perú (Grupo) 9,418 7,907 Norte
REDESUR (Grupo) 326 625 Sur
REDESUR (Grupo) 371 160 Norte
ATN S.A. 585 1,200 Sur
ABY Transmisión Sur S.A. 904 200 Sur
Compañía Minera Antamina Norte
San Gabán 325 Sur
Empresa de Generación Eléctrica Machupicchu S.A.
136 Sur
Ownership structure of Peru’s transmission system Major transmission investments in Peru since 2006
Some of the largest investments have been awarded to
parties different from the incumbents
The current arrangements
have not resulted in large
fragmentation of transmission
ownership in Peru
Industry structure: sub- transmission
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• High concentration of assets’
ownership in each Demand
area
• Distributors are the main
owners of sub-transmission
assets
The current ownership
structure is consistent with
the technical and economic
characteristics of sub-
transmission
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Agenda
1Objectives pursued and variables of choice for the organization of the
electricity transmission sector
2 The regulatory framework and the organisation of Peru’s transmission sector
3 Issues with the current arrangements and recommendations
Appendix: lessons from the international experience
Issues: subtransmission plannig and implementation
Sub-transmission
planning
• Some sub-transmission concession-holders show poor commitment to sub-
transmission planning
• Osinergmin ends up acting as network planner, which is beyond the typical
regulator’s responsibilities
• Measures for coordination with transmission planning (ITC planning) not yet
fully tested
Implementation
of sub-
transmission
investments
• The tender mechanism is not a suitable model for sub-transmission assets,
as it results in ownership fragmentation
• Government-owned distributors are reluctant / slow to invest in sub-
transmission. They are not committed to support the tender mechanism
Area Issues
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Options for the sub-transmission integration
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Sub-transmission planning
• Planning responsibility on Reference
distributor for the demand area
• COES to provide technical assistance
• Osinergmin supervision / approval
Implementation of sub-
transmission investments
• Implementation responsibility to distributor
• Reference distributor has last-resort role
• Incentive regulation
Sector’s organisation &
structure
• Current process and regulation retainedTransmission planning and
implementation
Area of intervention Option 1: Integrated sub-TO and DSOOption 2: Transmission model
extended to sub-transmission
• Sub-transmission assets treated
like transmission assets
• Planning responsibility on COES
• Osinergmin supervision / approval
• Current process and regulation
retained
• Current regulation retained,
except for sub-transmission
responsibilities
Public-sector distributors
• Explore long-term financial architectures
compatible with Peru’s national accounts
• Streamline cost-benefit assessment
• Performance-based mgmnt compensation
• Distributor/Reference distributor is the
monopolistic sub-TO
• Auctions as currently done for
transmission
Option 3: Integrated TSO and
sub-TO
• Transmission moves from ISO to
TSO model; TSO in also sub-TO
in the monopoly area
• Planning responsibility on TSOs
• Osinergmin supervision / approval
• Implementation by (regulated)
TSOs
• Current regulation retained, but
for sub-transmission
responsibilities
• Implementation by (regulated)
TSOs
Options for the sub-transmission integration
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Sub-transmission planning
• Planning responsibility on Reference
distributor for the demand area
• COES to provide technical assistance
• Osinergmin supervision / approval
Implementation of sub-
transmission investments
• Implementation responsibility to distributor
• Reference distributor has last-resort role
• Incentive regulation
Sector’s organisation &
structure
• Current process and regulation retainedTransmission planning and
implementation
Area of intervention Option 1: Integrated sub-TO and DSOOption 2: Transmission model
extended to sub-transmission
• Sub-transmission assets treated
like transmission assets
• Planning responsibility on COES
• Osinergmin supervision / approval
• Current process and regulation
retained
• Current regulation retained,
except for sub-transmission
responsibilities
Public-sector distributors
• Explore long-term financial architectures
compatible with Peru’s national accounts
• Streamline cost-benefit assessment
• Performance-based mgmnt compensation
• Distributor/Reference distributor is the
monopolistic sub-TO
• Auctions as currently done for
transmission
Option 3: Integrated TSO and
sub-TO
• Transmission moves from ISO to
TSO model; TSO in also sub-TO
in the monopoly area
• Planning responsibility on TSOs
• Osinergmin supervision / approval
• Implementation by (regulated)
TSOs
• Current regulation retained, but
for sub-transmission
responsibilities
• Implementation by (regulated)
TSOs
We recommend Option 1 because it is:
- consistent with technical features of
subtransmission
- coherent with an expanding role of
distributor as ‘system operator’
but the possibility to overcome the limits
of publicly-owned distributors needs to be
verified in order to assess feasibility
Recommendations
Sub-transmission
planning
• Planning responsibility assigned to a
‘Reference distributor’ for each demand area
• COES to provide technical assistance
• Open and transparent planning process
• Osinergmin’s role limited to supervision /
approval
Implementation
of sub-
transmission
investments
• Assign implementation responsibility to
distributor
• Reference distributor has last-resort role
• Consider introducing incentive regulation
• Discontinue optional tendering system
Area Measure Expected benefits
• More effective sub-
transmission (and
distribution) planning
• Exploit synergies of
distribution and sub-
transmission operations
• Prevent network ownership
fragmentation
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Transmission planning and implementation
Area Issues
Transmission
planning and
implementation
• Plan de transmisión, plans ex-Contractos-ley, rural electrification plans and
sub-transmission plans are poorly coordinated (relaying only on ITC planning)
• Lack of information on large connection requests may result in (avoidable)
sub-optimal planning decisions
Reinforcements• Tendering system is ineffective
• Delays (and possibly sub-optimal investment) result from arbitrage between
regulatory regimes by the owner of assets needing reinforcement
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Recommendations
Area Measure Expected benefits
Transmission
planning and
implementation
• A structured process to coordinate Plan de
transmisión, plans ex-Contractos-ley, rural
electrification plans and sub-transmission
plans
• Integrate large connection requests in
transmission planning
• Efficient network
development
Reinforcements
• Discontinue tendering system for
reinforcements
• Implement regulated model, possibly with
incentive features
• Timely implementation of
reinforcements
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Publicly owned distributors
Public-sector
distributors
• Limited access to long-term financing
• Cumbersome cost-benefit assessment of network investments
• Lack of technical competencies on sub-transmission
Area Issues
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Recommendations
Area Measure Expected benefits
Public-sector
distributors
• Explore long-term financial architectures
compatible with Peru’s national accounts
• Streamline cost-benefit assessment of
network investments
• Performance-based management
compensation
• Correct incentives and
adequate resources to
invest in sub-transmission
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Unplanned network systems (Redes no planificadas)
Area Issues
Redes no
planificadas
• Third party access regime is not effective (disputes)
• Planning by private parties of shared resources might result in inefficient
choices (e.g. on dimensioning)
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Recommendations
Area Measure Expected benefits
Redes no
planificadas
• Limited to assets that are unlikely to be
shared; otherwise implement an appropriate
connection regime
• Integrate authorisation to build redes no
planificadas with sub-transmission planning
process
• The implementation mechanism selected
must ensure that connection rights for the
party that seeks authorisation to build a
private line be ensured, irrespective of
whether the asset is built and owned by that
party or by the distributor
• Efficient network
development
• Avoid disputes related to
third-party access
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Tariffs
Transmission
tariffs
• Generators bear the risk that tariff revenues turn out to be lower than
allowed transmission revenues; this is not justified, as the generators do not
have any obvious advantage in managing or reducing that risk
• Energy based transmission charges on generators, to cover the cost of SCT
SST assets, add to their variable cost. This might have distortive effects
when bid-based dispatch is implemented.
Area Issues
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Recommendations
Area Measure Expected benefits
Transmission
tariffs
Any consistent set of connection charges,
transmission charges and capacity allocation
mechanism:• Shallow connection charges
• Nodal electricity prices
• Flat transmission tariff on consumers for revenue
adequacy
• Fair cost allocation
• No or minimal redispatch-
cost
• Hedging possibilities for
generators
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Cross-border interconnection
Cross-border
interconnections
• Multiple studies suggest that cross-border interconnectors would deliver
positive net benefits to Peru (benefits greater than costs)
• Market fundamentals and organisation in Peru and in neighboring countries
change over time, requiring
• regular reassessment of the benefits and costs of additional cross-border
capacity
• a robust model for cross-border exchanges
Area Issues
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Recommendations
Area Measure Expected benefits
Cross-border
interconnections
• Regularly assess the benefits of further
interconnection capacity (through cost-benefit
analysis)
• Designate entity for cross-border commercial
exchanges
• Agree with neighbouring jurisdictions and
implement a robust cross-border exchange
mechanism (e.g. SIEPAC)
• Once wholesale markets in interconnected
countries develop, move to more dynamic
capacity allocation mechanisms (explicit or
implicit capacity auctions)
• Maximise the net benefits
from interconnection
• Address different market
structures /organisation in
neighboring countries
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Appendix
Available options based on the international experience
Industry organisation
SO and TO organisation
SO/TO vs other
business
Topic International experience
No clearly superior approach. Rare cases
of ISO to TSO or TSO to ISO switch
Ownership unbundling is the prevalent model
Sub-transmission assetsUsually managed by distributors and
regulated as distribution assets Functional criterion is the main driver
Notes
Main models• ISO - US
• TSO - EU
Legal unbundling not uncommon.
Sometimes it is turned into ownership
unbundlieng
Regulatory framework
Regulatory institutions
Regulatory mechanism
Topic International experience
Cross-border issues in EU are disciplined
at Union level, but implemented by NRAs
with ACER stepping in if NRAs fail to agree
• Risk of approved investments borne by
consumers
• RB_ROR regulation prevalent (except
where auctions are implemented)
Incentive systems
• Limited examples of incentive based
regulatory mechanism on network
development (Italy) and system
operations (GB)
They do not appear to be a ‘major’ feature
of the regulatory regime (or source of
revenues for SOs)
Notes
• US: FERC (interstate transmission
development and access), PUCs
• EU: ACER (coordination), NRAs
Brazil, Argentina, Peru select TOs via
auctions; Countries with monopoly TO use
auctions to build network assets
Network planning and allocation of transmission rights
Allocation of
transmission rights
Topic International experience
Congestion rents/ FTR revenues cover a
relatively small share of total transmission
cost
Notes
• US: nodal electricity prices and financial
transmission rights
• EU: uniform nationwide electricity prices,
few cases of zonal prices (and financial
transmission rights)
Network planningMerchant investment is allowed both in the
US and in Europe (for cross-border
capacity only)
• Typically, SO responsibility. Regulators
approve SO’s proposals
Trasmission tariffs - 1
Generation /
Consumption charges
Topic International experience
Some of those jurisdictions which do it,
convey (long term) locational signals to
generators
Notes
Less than half EU Countries charge
generators for transmission
In the US charging demand is the typical
approach
Energy / capacity
charges
Energy charges applied to generators may
be distortive of the merit order
Different mixes of energy and capacity
charges
Time differentiationQuestionable that time-of-use-like schemes
correctly capture transmission scarcity
situations
Not infrequent especially for withdrawal
charges (seasonal/day and night/peak ..)
Trasmission tariffs - 2
Locational differentiation
/ Uniform
Topic International experience
Long-run incremental cost pricing is not
efficient. Placing transmission cost risk on
generators is a questionable regulatory
approach (in a planned system).
Notes
Locational differentiation is not common
(exception GB). Some countries use ‘deep’
connection charges for generators.
Losses
Recovered through general transmission
tariffs, ad hoc charges or by correcting
consumers’ withdrawals and possibly
generators’ injections.
Ancillary services In addition to imbalance chargesRecovered through general transmission
tariffs, ad hoc charges
Trasmission tariffs - 3
Timing
Topic International experience
Multi-annual regulatoryb period essential
for enabling RPI-X-type incentive-based
regulation
Notes
Tipically, tariff methodology is set for 4-5
years and tariffs are updated yearly based on
predefined rules
Annex
Issues raised by commenters and referees
On the role of distributors in sub-transmission
Comment Our reply
Poor sub-transmission
investment performance
depends on the (publicly
owned) distributors It is
not a good idea to enlarge
their responsibilities.
For the same reasons it is
not a good idea to limit the
scope for private investment
in Redes no planificadas
Our recommendation is based on the assumption (to be verified at a later stage of the assessment)
that it is possible to remove the obstacles that impair the publicly-owned distributors’ ability and
incentives to invest in sub-transmission assets.
We note incidentally that the issues highlighted as possible causes of the distributors’
underperformance in sub-transmission are likely to affect also the distributors’ investment
performance in distribution. For that reason, addressing them should be a matter of priority for
Peru.
We argue that in case public ownership is identified as the source of the distributors’
underperformance, privatisation should be considered as an option to improve the industry’s
performance.
On cross-border interconnection
Comment Our reply
Long-term cross-border
transmission rights should
be allocated, to support long-
term cross-border supply
contracts
Agree
No basis for prohibiting
COES from planning cross-
border interconnections
Report was meant to stress the need for high level of transparency and neutrality of cost-benefit
analysis.
On transmission tariffs
Comment Our reply
Recommendation based on
a wrong understanding of
the current tariffication
mechanism
Generators should not be
charged the negative
difference between tariff
revenues and allowed
revenues to SPT/SGT
owners
We have revised our recommendations based on improved understanding of current tariff
systems:
• We see no reason to place demand risk on generators, since they don’t have any obvious
advantage in managing or reduce it.
• Transmission charges on generators to cover SCT/SST cost should be based on capacity, to
avoid distorting their offers in the market when moving to bid-based dispatch
On redes privadas - 1
Comment Our reply
Role of Osinergmin
Possible conflicts of interests
of distributors (that are also
retailers and possibly
generators) in connecting
additional generators
We see Osinergmin’s role in approving (or setting guidelines on) the distributor’s decision on
whether to implement the development proposed by a private party as part of the development of
the public network
Regulation should be able to mitigate the effects of distributors’ integration in generation on
discrimination of third-party generators seeking connection.
We consider that this conflict of interest is easier to address compared to the one due to
distributors being also electricity retailers.
On redes privadas - 2
Comment Our reply
How to:
• Decide if an infrastructure
is to be developed
privately or as an element
of the public networks? (in
particular for generation)
• Address financial
problems of the
distributor?
Some hints (tentative):
• Distributor should have the last word on whether he believes a new item is going to be shared, based
on available information
• One could think of moving ownership and management of the asset to the distributor (as the sub-T
operator) while granting to the generator a volume of transmission rights equal to his capacity (to be
negotiated when the infrastructure is built) for the assets lifetime.
• Alternatively, one could think of a mechanism where management and ownership of the asset is
moved to the distributor as soon as a connection request is submitted ba new would-be user.
• The problem of “unused capacity being not made available” would be solved by transferring
operations to distributors (but transmission rights granted in exchange of the asset’s ownership should
be firm, otherwise we would be expropriating the generator who built the asset).
Back-up
Transmission – Sub transmission – Distribution
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