SUNDAY EDITION

September 24th, 2017

ICONS Home :: Archives :: Contact  
321energy



Suez Weekly Market Monitor

Derek Mumford
Derek.mumford@suezenergyna.com
January 17th, 2007

ERCOT Power

ERCOT power prices shifted drastically as the week progressed. Prices were driven by the NYMEX gas market in the early week but retarded late in the week, only to rise again.
ERCOT Prompt month deliveries closed at $49.84/MWh, increasing $3.00/MWh or 6.02%.
ERCOT ‘08 finished the week at $72.39/MWh up 1.54%.
ERCOT ’09 closed the week at $70.68/MWh up 1.50%.
The prompt month for the Houston Zone finished at $51.84/MWh an increase of 4.58% and the prompt month North Zone finished at $51.77/MWh up 4.93%.

NYISO—NEPOOL Power

Northeast power prices saw a great deal of movement this week as cold weather and high gas prices drove the market prices in an erratic pattern.
Prompt month prices for the Northeast are 21% to 30% less than 3 months ago for the same trading month. NYISO Zone J prompt month close
d the week at $86.10/MWh increasing $1.10/MWh a change of 1.28%.
NYISO Zone A prompt month finished at $57.10/MWh a gain of $2.60/MWh or 4.55% Massachusetts NEMA prompt month closed up at $78.10/MWh a change of 4.29% or $3.35/MWh.
Massachusetts SEMA prompt month finished the week at $71.10/MWh, increasing 4.71%.

PJM Power

PJM power prices also received a boost this week as gas prices and cold weather gave the reported indices a boost. Prices still remain close to their 52-week low.
Cinergy prompt month finished the week at $45.25/MWh, a change of 3.87% increasing $1.75/MWh.
NI Hub prompt month finished up $1.99/MWh to close at $47.00/MWh, a change of 4.23%.
PJM West Hub prompt month gained $1.90/MWh closing at $55.00/MWh, a change of 3.45%.
PSEG prices for the prompt month closed at $59.53/MWh, a change of 3.19% or $1.90/MWh.
Compared to 3 months ago, PJM prices are 21% to 25% less for the same trading period.

Natural Gas Market

Natural gas prices saw major volatility this week as prices climbed through midweek then fell off only to climb again late in the week.
NYMEX prices for the prompt month finished the week at $6.60/MMBtu an increase of 6.32% or $0.42/MMBtu.
February 2007 prices are 19.35% lower than 3 months ago for the same delivery period.
NYMEX Bal. ‘07 closed at $7.18/MMBtu a change of 3.66%, down $0.26/MMBtu.
NYMEX Cal ‘08 finished the week at $8.09/MMBtu; NYMEX Cal ‘09 closed at $7.90/MMBtu. Algonquin, Transco Z6, and Tetco M3 prompt month closed at $1.41/MMBtu, $1.43/MMBtu, and $1.06/MMbtu respectively.

Natural Gas Storage: Gas in Storage Decreased 49 Bcf

Working gas in storage was 3,025 Bcf as of Friday, January 5, 2007, according to EIA estimates.
This represents a net decline of 49 Bcf from the previous week.
Stocks were 401 Bcf higher than last year at this time and 461 Bcf above the 5-year average of 2,564 Bcf.
In the East Region, stocks were 241 Bcf above the 5-year average following net withdrawals of 28 Bcf.
Stocks in the Producing Region were 182 Bcf above the 5-year average of 751 Bcf after a net withdrawal of 9 Bcf.
Stocks in the West Region were 38 Bcf above the 5-year average after a net drawdown of 12 Bcf. At 3,025 Bcf, total working gas is above the 5-year historical range.

(Source: EIA)

Natural gas production delays drive up prices

Chevron Corp. and Royal Dutch Shell Plc are delaying construction projects from Australia to Nigeria, and that may raise natural gas prices for years to come.

None of the world's biggest energy companies approved developments last year to increase production of liquefied natural gas, which helps heat homes and run power plants from Tokyo to Boston. The main reason is the cost to build LNG plants has tripled in six years, according to Bechtel Group Inc., the biggest U.S. contractor.

Natural gas prices are three times higher than during the 1990s and consumption of the fuel will outpace the 1.6 percent annual gain in energy demand for the next 25 years, according to the International Energy Agency. Gas is also becoming more popular because it emits 29 percent less carbon dioxide than oil and 45 percent less than coal burned in power stations.

"Costs are going up and they're going up far faster than anybody expected," said Andy Flower, a U.K.-based consultant to the LNG industry and a former BP Plc executive. He forecasts that the world LNG shortage will last until at least 2011.

Gas may become more important than oil in the next 50 years because crude supplies are running out faster, according to the Paris-based IEA. Global oil and natural gas reserves were about the same at the end of 2005, equal to 1.2 trillion barrels of crude, according to data compiled by BP. Oil reserves are being burned almost twice as quickly as gas.

LNG sales rose about 11 percent last year to 157 million metric tons, according to Wood Mackenzie Consultants Inc. in Edinburgh. It may jump about 66 percent to 261 million tons in 2010 and another 87 percent to 488 million by 2020, the group said.

Record LNG prices won't fall for "years to come," said Ari Soemarno, president of Indonesia's state energy company, PT Pertamina, until 2005 the world's largest LNG exporter. Prices under multiyear contracts, excluding freight and insurance, range as high as about $10 per million British thermal units in Asia, assuming $60 a barrel for oil, part of LNG price formulas.

Natural gas deposited near industrialized nations is typically transported through pipelines. The challenge is getting gas from the biggest producers -- Russia, Qatar and Iran -- to consumers worldwide who aren't linked by those networks. Now, gas that can't be transported is pumped back underground to force more crude to the surface, or burned off.

Two of the newest and biggest LNG projects have been overbudget and late. Shell's Sakhalin-2 LNG in Russia has doubled in cost to more than $20 billion. Stavenger, Norway-based Statoil ASA's Snohvit LNG plant will cost $9.5 billion, almost 50 percent more than first anticipated in 2002.

Building LNG plants now takes four years, rather than three, because contractors are stretched, said Flower, the consultant.

San Ramon-based Chevron, the U.S.'s second-biggest oil company, last year abandoned its timetable for approving the Gorgon LNG project in Australia. Developing the fields, which hold $400 billion of natural gas, would cost $10 billion and increase world supplies by 7 percent. The driller and partners Shell and Irving, Texas-based Exxon Mobil Corp. are studying ways to reduce construction costs.

The project is "large, complex and faces considerable cost challenges," Colin Beckett, Gorgon area manager for Chevron said in an interview last month.

Politics and violence also hold back LNG developments. In the seas between Australia and East Timor, development of the $3.7 billion Sunrise LNG project has been stalled for more than two years as the nations resolve how to split royalties.

(Source: Bloomberg)

 

Derek Mumford
Energy Analyst
Suez Energy Resources
Derek.mumford@suezenergyna.com



Home :: Archives :: Contact  

SUNDAY EDITION

September 24th, 2017

© 2017 321energy.com



Visit 321gold.com