Reliable Power

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Status of Canadian Markets

APEX Conference – Sydney, Australia

October 13, 2008

Warren Frost,

Vice President

Operations & Reliability

Reliable Power

Reliable Markets

Reliable People

Alberta's Electricity Market

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AESO - Our Core Business

• Markets: develop and operate Alberta’s real-time wholesale energy market to facilitate fair, efficient and open competition

• Transmission System Development: plan and develop the transmission system to ensure continued reliability and facilitate the competitive market and investment in new supply

• Transmission System Access: provide system access for both generation and load customers

• System Operations: direct the reliable operation of Alberta’s power grid

• Settlement: accountable for administration of the provincial load settlement

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Quick Facts - Alberta’s Electric Industry

• 9,710 MW peak & 80% LF

• 12,085 MW total generation

• Over 280 generating units

• Wholesale market with ~ 200 market participants

• > 21,000 km of transmission

• Interties BC (up to 780 MW) & Sask. (up to 150 MW)

BC

AltaSask

5,893 MW

4,635 MW(Other renewables)

178 MW

(Wind)

510 MW

869 MW

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Electric Utilities Act

Minister of Energy Appoints Board members & MSA

MarketSurveillance Administrator

BalancingPool

Wholesale Energy Market

Transmission Planning

Alberta Electric System Operator

Real-timeOperation of

Electric System

AUC

Load Settlement

Industry Structure

Alberta Utilities Commission Act

Cabinet Appoints Commission

Members and Chair of AUC

ComplianceSurveillance

Consumer Financial accts

PPA Obligations

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AESOSystem

ControllerNeighbouringBA and TOP

TFO/GFO

ReliabilityCoordinator

Generators

AncillaryService

Providers

Marketers

Operate the Grid Operate the Market

Grid & Market Operations

SC Support 24/7OperationsEngineering

EMS/IT

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• Real-time energy only market

• Clearing market – one price for all

• No capacity payments

• Price cap @ $1,000

• Day-ahead operating reserve market

• Supply shortfall procedures

• Postage stamp transmission rates paid by load

• Siting signals for generators Loss factors

System contributions for interconnections

Wholesale Markets

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Market Operations

• Participants submit bids/offers by noon day ahead – can restate price up to two hours before delivery (T- 2 hours)

• Each asset can use 7 price-quantity pairs for each hour

• AESO creates an Energy Merit Order (EMO) for each hour from the bids and offers

• SC Dispatches up and Down the EMO

• Schedules inter-provincial energy schedules hourly

• Imports offered at $0

• Exports bid at $999.99

• Highest dispatched asset sets SMP

• Ex-post pool price is the arithmetic average of the 60 one minute system marginal prices

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Setting System Marginal Price (SMP)

MW

SMP

Generation units dispatched

$ per MW Demand

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Ancillary Services

• AESO is the buyer of reserves - procured 5 days to 1 day ahead of delivery

• Contingency reserves Replaces unexpected lost supply

500 MW of spinning and non-spinning reserves

Must be able to provide in 10 minutes

• Regulating Reserves Normally use 130 to 225 MW

Responds to instantaneous fluctuations in supply/demand balance

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Adequacy

• No centrally planned generation - market signals to encourage generation investment

• Established a threshold where stop-gap action will be taken by AESO to ensure adequacy until investors can build

• Threshold looks at supply two years out• If 2 year supply picture appears to breach threshold AESO will

procure: Demand products and/or emergency generation• Out of market actions invoked when energy market merit order is

exhausted using Supply Shortfall Procedures: Curtail exports, loads Cut reserves Acquire emergency energy from neighboring jurisdictions Curtail firm load

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Transmission and Interties

• Market Policy Transmission is required for reliability and to facilitate a competitive

market ISO must create long term plans – 10 and 20 year

• Transmission Must Run Generally expected to be short-term solutions Using dispatch down service to remove pool price impact

• Congestion management rules

• Interties – essential to a well functioning market Reliability – reserves, frequency, stability Market – imports during scarcity and export during surplus Merchant Interties - TransCanada NorthernLights (NL) and MATL

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Major Initiatives in the Alberta Market

• Wind integration

• Congestion Management Rules and Procedures

• Market Power Mitigation Market share and a pivotal supplier test

• Dispatchable Interties

• Operating Reserve Market Redesign

• Demand Response

• New Intertie Capacity

Reliable Power

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Ontario’s Electricity Market

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Ontario at a Glance(year-end 2007)

Installed Capacity 31,000 MW

Record Summer Peak

27,005 MW (August 1, 2006)

Record Winter Peak

24,979 MW (December 20, 2004)

Total Annual Energy Consumed

152 TWh

Customers 4.5 million

Ontario Import Capability

4,000 MW

Transmission Lines 30,000 km (18,600 miles)

Average Price

(2008 to date)

5.23¢/kWh

The IESO is the reliability coordinator for Ontario and works closely with other jurisdictions to ensure energy adequacy across North America.

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Ontario’s Electricity Market

$ $

BillingPayments

Dispatch Dispatch

Offers/Schedules Bids

Suppliers

Generators45

(e.g. Shell, Constellation)

Wholesale Sellers

68(e.g. Shell,

Constellation)

Consumers

Local Distribution Companies

78(e.g. Toronto Hydro, Hydro Ottawa, Hydro

One)

WholesaleConsumers

98(e.g. Dofasco,

Norampac, De Beers)

Transmitters(Hydro One, Great Lakes Power, Canadian

Niagara Power, Five Nations Energy)

Tariffs $

Contracted/Regulated Prices$

Ontario Energy Board

Electricity

Direction

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Fixed or Capped Prices in Ontario

• More than 75 percent of the generation in Ontario has a contract or fixed price for example:

Non utility generator (NUG) contracts

Contracts for new (selected under RFP) and existing plants based on market price

Fixed rates for ‘heritage’ generation owned by the monopoly generator (nuclear and 85% of baseload hydro)

85% of coal and peaking hydro output from monopoly generator pays a rebate if market price exceeds a set rate

Fixed rates for renewable generation – Standard Offer Program for small-scale renewable

• In addition, Ontario is initiating a large volume of conservation and demand response contracts

• All Ontario consumers pay an adjustment to the Hourly Ontario Energy Price to cover these contracts

Adjustment fluctuates between a credit and debit depending on the market price

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Major Initiatives in the Ontario Market

• Government RFP for new nuclear

• Smart Meters for all Ontarians by 2010 (4 million customers) 1.3 million installed to date

27,000 customers now billed on time-of-use rates

• Day-ahead mechanisms planned for 2010 Assessing an energy forward market

• Day-ahead price forecast implemented this summer

• Ontario’s target for renewables is over 10,400 MW by 2010

• Coal replacement strategy being implemented, with shutdown complete in 2014

• Significant conservation and demand response programs launched and under development

Target 6,300 MW reduction through CDM by 2025

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New Brunswick’s Electricity Market

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New Brunswick System Operator(Independent Not-for-Profit System Operator)

NBSO is 1 of 17 Reliability Coordinators

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Reliability

22

Interconnections

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Market Design

• Market activity through physical bilateral contracts Competitive supply must match load obligation

• Open access transmission by FERC 888 and compatible tariff operated through FERC 889 compatible OASIS

• NBP Genco responsible to backstop delivery of Standard offer services for supply and backup

All ancillary transmission and market services

• Central system operator to be responsible for market

• PUB to have regulatory authority

• Remove embedded generation barriers

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HQ/NS MarketersNBPGenco

SJ/Ed/PA PEI/NMNBPDisco

Large Industry

IPPs

NBPTransco

Suppliers

Market Delivery

Loads

NBSO

NBPNuclear

Market Structure

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Market Implementation

• Contracts between two parties (supplier and load) terms, conditions and price negotiated privately scheduled every day through system operator OASIS imbalance & transmission settled after the fact by system operator

• Eligible loads are Large Industry at transmission voltage (about 50) Wholesale municipals (SJ, Ed, P-A) NB Power Disco

• Eligible suppliers are NB generators (NBP Genco, NBP Nuclear, WPS, Bayside, others?) Industrial self generation (existing, new?) External utilities (HQ, NS, MPS/EA) Others (Marketers, Aggregators, brokers)

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Transmission Tariff

• FERC 888 compatible open access tariff Point to point service

Network service

Unbundled ancillary services

• System Dispatch and Voltage Support (mandatory)

• AGC and Operating Reserves (optional)

• Energy Imbalance (mandatory settlement)

• Billing determinants Net non coincident demand by delivery point

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Ongoing Work

• Continue to pursue efficiencies in dispatch, market administration, and operations.

• Seek details on the standard service rates, terms, and conditions that would apply in the case of a customer serving all or a part of its load from an alternative supply (e.g. exit fees, partial service policies).

• Enhance automated market assessment and monitoring tools.

• Increase system flexibility and competitiveness of balancing energy supply by increasing levels of participation in the balancing energy market.

• Pursue additional supplies of capacity-based ancillary services and competitive pricing of those services.

• Simplify and fine tune the market rules where appropriate (especially with respect to wind power integration).

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Ongoing Work (cont.d)

• Actively monitor transmission planning studies in adjacent jurisdictions and their potential impacts on the New Brunswick market.

• Pursue regional cooperation on issues such as transmission planning, reducing inter-market barriers, and easing wind power integration.

• In keeping with the intent of some aspects of FERC 890 the NBSO will consider the expansion of the regional transmission planning function beyond reliability and ten year time frames to include overall system needs inclusive of economics.

• Review of the overall approach to transmission investment, usage and tariffs given the magnitude of the potential generation, the non-dispatchable nature of proposed generation, and the requirements for significant transmission investments.

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Questions