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Q4 Energy Market Outlook and 2015 Planning Energy Prices and Market Intelligence Q4 Update December 4, 2014
Presenters: Jonathan Lee, Senior Energy Market Intelligence Manager and Jeni Murphy, Senior Energy Procurement/Strategy Manager
After a relatively calm summer, energy prices are experiencing increased volatility as arctic air descends upon the U.S. − As the nation increases its reliance on natural gas-fired electric generation, wholesale gas prices
will play an even bigger role in the direction of electric prices.
Fundamental Drivers – Bulls and Bears • Winter Weather: A potentially chilly winter could boost natural gas demand and severely
deplete already below-average storage levels.
Natural Gas Production, Demand, Storage: Production continues to grow at a record pace, but with winter taking grip, demand for the fuel is also on the rise. Natural gas in storage is at a 6-year low even after posting a record-setting injection year.
Northeast/New England: Market volatility continues to soar in the Northeast and New England natural gas and electric markets.
– Root causes to the volatility: Power plant retirements, increased reliance on natural gas-fired generation, and pipeline constraints combine to increase wholesale price volatility.
– Timeline for potential relief: Pipeline completions to bring some relief to the Northeast in 2015, but New England will have to wait until 2016 and beyond.
– Strategies to consider
ENERGY MARKET INTELLIGENCE
MARKET FUNDAMENTALS 4 December 2014
Near Term Next 3 Months
Short Term 4 to 6 Months
Medium Term 7 to 12 Months
Long Term 1 to 5 Years
Storage
Production
Demand
Electric Power Sector
Weather
Tropical Storms
LNG
Economy
Storage
Production
Demand
Electric Power Sector
Weather
Tropical Storms
LNG
Economy
WINTER WEATHER OUTLOOK AccuWeather, Farmers’ Almanac, NOAA, Weather Trends 360
Another bitter cold winter ahead??
Potential El Niño patterns forming for late 2014 could help CA hydro next year, and keep the East drier and warmer this winter.
El Niño patterns, as shown below, primarily reach maximums during Dec-Feb and typically persist for 9-12 months.
EL NIÑO WINTER IMPACT NHC/NOAA; AccuWeather: December 2014
RECORD STORAGE REPLENISHMENT
Entered traditional injection season at an 11-year low, but peaked at just a 6-year low
Ended 6.2% below the 5-yr avg
35% (722 Bcf) above the average refill amount over the last 14 years
Avg 20 Bcf/week above last year
EIA: November 2014
RECORD: Gas production exceeded 75 bcf/day in August 2014
Continued growth seen through 2015
ROBUST NATURAL GAS PRODUCTION EIA: November 2014
Shale gas a major contributor to
production growth
SUPPLY AND DEMAND BALANCE EIA: November 2014
2014 gas production is outpacing demand, which led to
a strong injection season
Consumption expected to decline in 2015, especially in the Residential/ Commercial sector.
NATURAL GAS FORWARD CURVE (NYMEX) – 2 December 2014
$3.00
$3.50
$4.00
$4.50
$5.00
$5.50
$6.00 Ja
n-15
Feb-
15
Mar
-15
Apr
-15
May
-15
Jun-
15
Jul-
15
Aug
-15
Sep
-15
Oct
-15
Nov
-15
Dec
-15
Jan-
16
Feb-
16
Mar
-16
Apr
-16
May
-16
Jun-
16
Jul-
16
Aug
-16
Sep
-16
Oct
-16
Nov
-16
Dec
-16
Jan-
17
Feb-
17
Mar
-17
Apr
-17
$/M
MBtu
13-Oct
27-Oct
10-Nov
2-Dec
NATURAL GAS $MMBtu (12-Month Strip) – 2 December 2014 – Short Term Trading Channel
ELECTRIC WHOLESALE PRICES Ecova: 28 November 2014
IN FOCUS: NORTHEAST AND NEW ENGLAND
NV
WY
UT
AZ NM
ND
SD
NE
KS
OK TX
MO
AR
LA
CO
MN
IA
WI
IL
MI
IN OH
PA
WV VA
NC
SC
GA
NY
VT
NH
ME
RI CT
NJ MA
DE KY
TN
MS AL
FL
AK HI
ID
CA
OR
WA MT
NV
SPIKE IN WINTER DEMAND
Competition for constrained resources has resulted in significant price spikes in
past winters
Consumption in the Northeast reached its third-highest recorded November level this year, exceeding 24 Bcf, 10 Bcf higher than normal.
PIPELINE CONSTRAINTS The main choke points in
the Northeast and New England are the Algonquin and Transco Zone 6 pipelines
Due to the increased reliance on gas-fired generation, Algonquin pipeline utilization has remained constrained even during non-peak times of the year
Increased strain on the system has resulted in some of the highest and most volatile basis prices in the country
RELIEF COMING, BUT WHEN?
NE PA Dry 9.1 Bcf/day
West Marcellus/Utica
23.9 Bcf/day
An estimated 33 Bcf/day of takeaway capacity expansions
by 2018
3.1 Bcf/day of expansions in 2014 to benefit Northeast
4.9 Bcf/day of expansions planned for 2015 to benefit Northeast
New England to see additional pipeline capacity in 2016
POWER PLANT RETIREMENTS EIA and NERC
1,827 MW combined shutdowns since last winter to challenge operations in the New England market − Vermont Yankee Nuclear Plant (605 MW) and Salem Harbor Station (745 MW) among largest
− New gas-fired plants, renewable generation, and hydro power from Quebec to make up for lost generation
− 1,520-MW Brayton Point coal- and gas/oil-fired power plant, expected to be shut down in 2017
REAL-TIME ELECTRIC PRICE VOLATILITY
Natural Gas Pipeline Constraints During High
Demand Periods Result in Market Volatility. Real Threat
Heading into Winter 2014/2015
Daily average real-time electric prices soared to nearly $350/MW in New England and over $400/MW in New York.
NEW YORK CITY WHOLESALE ELECTRIC $/MWh (ATC 12-Month Strip)
NEW ENGLAND WHOLESALE ELECTRIC $/MWh (ATC 12-Month Strip)
GAS PRICES ELEVATED FROM HISTORIC RANGE
New pipeline capacity to the Northeast has helped NYC winter gas prices
decline to historical levels.
However, Boston winter gas prices are experiencing must slower relief.
EIA – 24 November 2014
BASIS MARKETS UNDER PRESSURE
27%
WINTER RELIABILITY PROGRAM 14/15 Second year in a row ISO-NE has implemented the Winter
Reliability Program − Objective is to maintain reliability during cold winter months
− Program responds to concerns for upcoming winter:
− Generators’ difficulty in replenishing oil mid-winter
− Severe constraints on gas pipelines
− Retirements of non-gas fired generating units
− Offset carrying cost of unused fuel purchased by generators for winter period
Similarities to 2013/2014: − Charges for 3 month period, cost allocator will be same as 2013/14 pro-rata on Real Time Load
Obligation, instead of net billing, charges will be collected, and then credits will be paid in a subsequent bill
Differences to 2013/2014: − Estimated charges will be billed out monthly for 3 months, and then a true up reflecting final
actual unused inventories will be calculated and billed; charge estimates based on 75% of eligible inventory on Dec 1st; payment to generators for unused fuel inventory will take place on one bill
How does your business define its success as it relates to energy risk management?
– Do you have a predetermined benchmark?
– Does your energy risk management strategy align with your company’s corporate goals?
KNOW YOUR GOALS
Low-Risk Tolerant Clients – May take shorter term positions at a premium
– Set targets in anticipation of seasonal softening
– Keep pulse on market opportunities for long-term budget certainty
Medium-Risk Tolerant Clients – Consider Volatility & Load:
• Low Load & Low Volatility; Consider Index
• High Load High Volatility; Consider fixed
• Hybrid
High-Risk Tolerant Clients – Know your VaR and be prepared for seasonal volatility
– Keep a pulse on good value-buy opportunities
KNOW YOUR RISK PROFILE
KNOW OTHER RISK FACTORS
PJM ISO – VOLATILTY ISN’T ISOLATED TO NEW YORK/NEW ENGLAND − During the frigid winter in early 2014, market-based electric rates also saw significant upward
pressure in Maryland, New Jersey, and Pennsylvania
− Capacity increases across the PJM footprint, with the largest capacity increases in northeast Ohio
TEXAS – SUMMER VOLATILITY IN THE SPOTLIGHT − ERCOT raising System Wide Offer Cap (SWOC) to $9,000/MWh in June 2015
CALIFORNIA – STEADY CLIMB IN WHOLESALE ELECTRIC PRICES − Persistent drought conditions have reduced hydropower output and increased the reliance on
natural gas and renewable energy sources. California has aggressive plans to reach 33% Renewable Portfolio Standards by 2020
EPA REGULATIONS – LED TO INCREASED COAL-PLANT RETIREMENTS − Power plant operators must come under the Mercury Air Toxic Standards (MATS) rule by April
2015. Already, about 60 GW of coal power plants are scheduled to permanently retire
OTHER REGIONAL FACTORS: Winter 2014/Summer 2015 Outlook
NATURAL GAS AND WHOLESALE ELECTRICITY ARE LIKELY TO EXPERIENCE ANOTHER VOLATILE WINTER Market volatility will continue for the foreseeable future as the nation relies more on gas-fired
power plants to generate electricity
ENOUGH GAS IN STORAGE TO MEET WINTER DEMAND? With end of injection season supplies at a six-year low, market participants are concerned
over the winter of 2014/2015
NORTHEAST/NEW ENGLAND ENERGY MARKETS Energy prices among the highest and most volatile across the nation during the winter
Root causes to the volatility: Power plant retirements, increased reliance on natural gas-fired generation, and pipeline constraints combine to increase wholesale price volatility
Pipeline completions to bring some relief to the Northeast in 2015, but New England will have to wait until 2016 and beyond
Develop a clear, concise strategy on procurement activities
MAJOR TAKEAWAYS
Q&A
Thank you!