Weekly Futures Recap With Mike Seery for week ending March 21st

Natural gas prices are trading below their 20 day but above their 100 day moving average in the April contract telling you that the trend is mixed as prices have broken down recently hitting a 7 week low in last Fridays trade as warm weather is on the horizon. The trend has turned negative at least here in the short term as I would sell a futures contract at the break out of 4.40 and place my stop loss at the 2 week high which currently stands at 4.73 risking around $3,300 if your trading the large contract or $850 dollars in the mini contract as the chart structure is very solid allowing you to place a tight stop loss minimizing risk. The long term trend is higher in natural gas as prices rallied to 5.20 last month due to the cold weather however I am trading with the short term trend which is lower while making sure that the chart structure is solid before entering so currently this meets criteria.
TREND: LOWER
CHART STRUCTURE: SOLID

Coffee futures in New York finished lower for the 6th consecutive trading session finishing lower by about 2800 points for the trading week hitting a 4 week low in today’s trade and if you followed my recommendation in yesterday’s blog when prices hit 181 which was the 10 day low I was recommending to take profits and move on as this market remains neutral at this time so sit on the sidelines and wait for better chart pattern to develop. Prices are trading below their 20 day but above their 100 day moving average telling you the trend is mixed and as I stated yesterday I believe a possible good entry to get long this market is around 160 level which is about the 50% retracement from recent lows to highs as I don’t believe this bull market is over it was just overextended to the upside. I keep in contact with several Brazilian coffee producers and they still believe that the crop is devastated and prices eventually will move higher so look for a possible entry point below the market as prices still remain weak finishing down over 300 points this Friday afternoon right near session lows.
TREND: MIXED
CHART STRUCTURE: POOR

Sugar futures were down about 35 points this week hitting a 4 week low as prices continue to the downside and I still remain neutral this market as I’m waiting to see better chart structure as the trend currently is mixed so look for some other commodity that has a strong trend and just keep an eye on sugar at this time. The 50% retracement from contract lows of around 15.00 to the recent 4 month highs that were hit earlier in the month was 18.50 which is about 350 points divided by 2 equaling 175 points so currently the 50% retracement is at about 16.75 which is just an eyelash away so if you’re looking at possibly getting long this market look to buy around that level. Sugar futures are trading far below their 20 day and right at the 100 day moving average as the next support levels are all the way down at 16.00.
TREND: MIXED
CHART STRUCTURE: SOLID

The 10 year notes in Chicago this week sold off sharply due to the fact of Janet Yellen’s testimony stating that bond purchases that the Federal Reserve has been doing for several years now will come to an end in September with the possibility of rates rising 6 months after that date sending the yield on the 10 year note to 2.77% & in my opinion I think the bond market has started their bearish trend. Prices are trading below their 20 and 100 day moving average hitting an 8 week low and I’m recommending selling the futures contract at today’s price placing your stop above the 10 day high at 125 risking around $2,000 per contract as the trend has turned bearish and I think this could be a special situation as interest rates look to finally start to rise after years of record low rates.
TREND: LOWER
CHART STRUCTURE: EXCELLENT

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EIA: Low U.S. Injections Reflect Already High Natural Gas Storage Inventories

The increase in U.S. working natural gas inventories nearly half way through the 2012 injection season the period from April through October when most natural gas is stored underground to help meet heating demand during the upcoming winter was the lowest in 12 years. The slow start to the injection season reflects record high inventories at the end of this winter, leaving less space to be filled, and a large increase in natural gas use by the U.S. electric sector for power generation. EIA estimates that, by November, working natural gas inventories will hit a record high, exceeding 3,900 billion cubic feet (Bcf). U.S. dry natural gas production was up almost 7% from January through May of 2012 compared to the same period in 2011, so natural gas injections have not shifted lower due to a downturn in domestic natural gas production.

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The amount of working natural gas in underground storage increased 625 Bcf during April-June 2012, according to EIA's Weekly Natural Gas Storage Report. That is the smallest build since adding 564 Bcf, on a net basis, during the same period in 2000 (see chart above). While the increase in inventories is low, the amount of total gas in underground storage facilities is at a record high for this time of year, after topping 3,000 Bcf for the first time ever during any June month.

Here is the EIA injection and usage charts

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U.S. Dry Natural Gas Production Growth Levels off Following Decline in Natural Gas Prices

U.S. dry natural gas production has increased since late 2005 due mainly to rapid growth in production from shale gas resources. However, there have been two notable instances (see red ovals in the chart) in the last seven years when natural gas production leveled off during a period of falling spot natural gas prices. The first was during the recent economic recession and the latest began in the fourth quarter of 2011 and continued through the first quarter of 2012.



Weather events (see green ovals) have also affected U.S. natural gas production.
The major events over the past seven years that have caused dry gas output to level off or even decline include:

Hurricanes Katrina and Rita (Sep-Oct 2005) - Disrupted up to 12.2 billion cubic feet per day (Bcf/d) in offshore natural gas production.

Hurricanes Gustav and Ike (Sep 2008) - Disrupted up to 9.5 Bcf/d in offshore natural gas production.

Economic recession and falling prices (Oct 2008- Sep 2009), Reduced industrial and manufacturing activity, and lower electricity use eased demand for natural gas as a feedstock and a power generation fuel. Natural gas prices fell sharply as a result.

Winter well freeze offs (Feb 2011) - Disrupted up to 7.5 Bcf/d in natural gas production from Texas to Arizona, when water froze inside wellheads during extremely cold weather and blocked gas flows.

Supply overhang and falling natural gas prices (Oct 2011-Mar 2012) A warm winter that reduced heating fuel demand and record high gas inventories resulted in a nearly 50% drop in gas prices, causing some energy companies to postpone new drilling and cut back on some existing operations.

Natural gas production was relatively flat between October 2011 and March 2012, when Henry Hub spot gas prices declined from just above $3.50 to around $2.00 per million British thermal units in March. Preliminary EIA data indicate a slight drop in production during March, according to the Natural Gas Monthly report released on May 31.

Of the five large gas producing states tracked monthly by EIA Texas, Louisiana, New Mexico, Oklahoma, and Wyoming, New Mexico had the highest percentage decline in its March gross natural gas production, down 2.2 percent from the previous month, while Texas had the largest volumetric drop, down 150 million cubic feet per day. States that EIA does not presently track on a monthly basis, such as Pennsylvania, may have seen their gas output increase during March.

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NOAA Predicts a Near Normal 2012 Atlantic Hurricane Season

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On May 24, 2012, the National Oceanic and Atmospheric Administration's Climate Prediction Center said that, for the six month hurricane season beginning June 1, there is a 70% chance of 9 to 15 named storms in the Atlantic Basin, of which 4 to 8 may strengthen to hurricanes. Of those, 1 to 3 may become major hurricanes (Category 3, 4, or 5). During the hurricane season from 1981 through 2010, the Atlantic basin averaged 12 named storms and 6 hurricanes each year, 3 of which were major hurricanes.

As of June 1, 2012, there have been two named Atlantic Basin storms (Tropical Storms Alberto and Beryl).



Tropical storms and hurricanes can temporarily disrupt the U.S. oil and natural gas supply chain (producing fields, gathering, processing, refining, and transportation), especially in the Gulf Coast region. The U.S. Energy Information Administration's Federal Offshore Gulf of Mexico reporting region (GOM Fed) is a key component of U.S. crude oil and natural gas production.

The GOM Fed region provided nearly one quarter of total U.S. crude oil production in 2011, the highest share among Federal offshore regions and second only to Texas among individual states. Driven by increasing volumes associated with deepwater and ultra-deepwater development activity, the GOM Fed region helped to reverse a decades-long decline in U.S. crude oil production in 2009. GOM Fed region production declined in 2010 and 2011, largely the result of suspended drilling activity following the Macondo oil spill. Exploration and development operations have since resumed, however.

The potential impact of hurricanes on U.S. natural gas supply is comparatively muted, as the GOM Fed region accounts for a relatively modest portion of total U.S. natural gas production. The GOM Fed region supplied about 8% of total U.S. marketed natural gas production in 2011, down significantly from a decade ago, when the region had an approximate one quarter share. The GOM Fed region's relative contribution has diminished as a result of both gradually declining offshore production and significant increases in Lower 48 output, due primarily to expanding shale gas developments in several areas of the country.

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Natural Gas Spot Prices Near 10 Year Lows Amid Warm Weather

 Natural gas prices have continued their downward trend this winter as a result of warmer than normal temperatures, ample natural gas in storage, and growing production. Population weighted heating degree days since November 1, 2011 are down 12% nationally from the 30 year average. Total working natural gas in underground storage in the lower 48 states was 3,098 Bcf for the week ending January 20, 21% above the storage levels from one year ago. Daily dry gas production averaged about 64.2 billion cubic feet per day (Bcfd) in January, up almost 10% from last January.

Click on the tab headers below to see charts highlighting factors affecting natural gas prices.

Spot Prices      Weather       Storage         Production       Weather Outlook        Futures Prices

Average spot natural gas prices for January were $2.68/MMBtu. Spot natural gas prices in January 2012 reached their lowest level in 10 years except for a 4-day period over the Labor Day weekend in 2009.


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Spot Natural Gas Prices Dipped to Two Year Low in November

Spot natural gas prices at the Henry Hub in Erath, Louisiana fell to $2.83 per million British thermal units for delivery on November 24, 2011, the lowest price since November 17, 2009. Henry Hub is the benchmark location for key natural gas financial instruments on the New York Mercantile Exchange and the IntercontinentalExchange such as futures contracts, swaps, and options.
Key factors affecting natural gas prices include:

• Growing domestic production. U.S. domestic marketed production averaged 65.4 Bcf/d through September, based on EIA data, an increase of about 7% from the same period in 2010, while demand for the corresponding period was up 2% this year.
• High natural gas storage levels. For the week ending November 25, 2011, natural gas storage inventories were 3,851 billion cubic feet (Bcf), down one Bcf from record inventory levels set the prior week but over 7% above the five-year average.
• Seasonal weather. Warmer-than-average weather across most of the United States has delayed the start of winter weather and the corresponding increased natural gas demand for heating. Through November 28, cumulative U.S. population-weighted heating degree-days in the 2011-2012 winter season are 8% below the 30-year average and are down 16% in the natural gas heating-intensive Northeast region.

Spot prices at Henry Hub rose about $0.70 per million British thermal units after the Thanksgiving Holiday weekend due to cooler temperatures and higher demand.

Source: U.S. Energy Information Administration, based on Bloomberg.
Note: Data included through November 30, 2011.

  

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EIA: Summer 2011 Electricity Prices Were Mostly Down Compared to Summer 2010

Source: U.S. Energy Information Administration, based on data from SNL Energy.

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Except for Texas, California, and the Southwest, average on-peak, wholesale electricity prices at trading points across much of the country declined during the summer (May 15 to September 15) of 2011 when compared to the summer of 2010. Wholesale power prices generally mirrored changes in wholesale natural gas prices. One stark exception was in the system operated by the Electric Reliability Council of Texas (ERCOT) where extreme, sustained, widespread heat as well as insufficient capacity resulted in wholesale prices over 100% higher compared to the summer of 2010.

Electric system demand typically increases in the summer months as a result of residential air-conditioning demand. This increased demand usually drives up wholesale electricity prices compared to the spring and fall.

Some key drivers of price changes this summer included:

Weather: Mild temperatures throughout the Northeast and Central United States drove significant declines in average power prices in New England, New York, and the Midwest. The sustained heat wave in Texas resulted in record-breaking load levels. The map below shows the percentage change in cooling degree-days between the summer of 2010 and the summer of 2011, by state. Texas had a 13% increase in cooling degree-days, while Oklahoma and New Mexico had 15% and 13% increases, respectively. August 2011 was the warmest August recorded by the National Oceanic and Atmospheric Administration for New Mexico, Oklahoma, Colorado, Arizona and Louisiana.

Source: U.S. Energy Information Administration, based on data from the National Oceanic and Atmospheric Administration.

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Natural Gas Prices: Because natural gas is the marginal fuel for electricity generation in many regions of the country, natural gas prices can have a significant impact on the wholesale price of electricity. Overall, wholesale natural gas prices this summer were little changed compared to prices in the summer of 2010; wholesale natural gas prices at the Henry Hub in Louisiana fell about 1% to $4.30 per million British thermal units. There were some regional changes, however. In the Northeast, wholesale natural gas prices were down between 2% and 15%, reflecting both lower regional demands and growing natural gas production from the Marcellus shale play. Natural gas prices were about 4-7% higher than last summer in the Southwest and California markets and supported modestly higher wholesale power prices in those markets.

Hydroelectric Output: Power prices in the Pacific Northwest were driven down by the availability of inexpensive hydroelectric generation and mild temperatures in the early part of the summer. The average on-peak wholesale electricity price at Mid-Columbia zone (along the Washington/Oregon border) decreased 6% as hydroelectric output increased above five-year highs.

Rigzone: Crude Oil Climbs to a Three Week High in Tuesdays Trading

Crude futures climbed to a three week high Tuesday as concerns eased over Europe's debt crisis.

July's oil prices gained $2.11 Tuesday before settling at $102.70 a barrel on the New York Mercantile Exchange. The greenback fell against the euro as the European Union debated on sending additional financial aid to boost Greece's economy. Luxembourg Prime Minister Jean-Claude Juncker said a new aid package will be decided on by the end of June. A weaker dollar increases the appeal of the dollar denominated commodities making it cheaper for foreign buyers.

After noticing a 40 barrel spill at a pump station in Kansas, TransCanada temporary closed down its Keystone pipeline further pressuring oil prices Tuesday. The Keystone pipeline carries half a million barrels of crude per day from Alberta to Cushing, Okla., the largest oil storage hub in the U.S.

Oil prices peaked at $103.39 a barrel and bottomed out at $99.60 on Tuesday.

Natural gas for July delivery traded up Tuesday, adding 15 cents to settle at $4.67 per thousand cubic feet. Prices rose to their highest in four weeks on forecasts predicting above average weather. Hotter weather increases demand for fuel which is required for air conditioning. The intraday range for natural gas was $4.525 to $4.71 per thousand cubic feet.

Gasoline prices also ended higher Tuesday. After fluctuating between $3.07 and $3.165, gasoline settled at $3.15 a gallon, 5.84 cents higher from the previous trading session.


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Phil Flynn: Weather or not?

I guess we can talk about the cold but I think it's already talking for itself. Heating degree days are piling up in the energy complex but to get the full picture on this New Year surge of bullishness, you really have to look beyond your frost-bit nose. It is not so much the transitory issue that we are freezing that inspired the big move but a growing sense that interest rates will be frozen for a longer time than the market anticipated. You see, weather was a major factor that drove oil and heating fuels and orange juice yet other markets like gold and silver and copper soared as well. Ok, I know some people think gold can keep you warm at night but this rally was about more than just weather. This was about the changing attitudes of when the Fed will raise rates and the resumption of the dollar carry trade that helped drive last year Fed inspired commodity rally.

The dollar got whacked in the aftermath of weekend comments by Fed Chairman Ben Bernanke on his talk of an aggressive exit strategy. The markets seemed to not take his comment seriously or at least they had the perception that rates may stay lower longer than they thought. This perception grew stronger when Federal Reserve Board Governor Elizabeth Duke said she sees inflation remaining subdued. Fed Fund futures rallied, lowering expectations of an interest rate hike in June to a mere 58% chance, down from 78% chance at the close last week. This significant change and could have a significant impact on commodity prices.....Read the entire article.

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Heating Oil Hits 13 Month High as Frigid Weather Cuts Supplies

Heating oil reached a 13 month high as the frigid weather that has drained distillate supplies was projected to extend into January, increasing demand for the motor fuel.
The U.S. Climate Prediction Center forecast below normal temperatures from Texas to Maine from Jan. 5 to Jan. 13. Distillate stockpiles fell to the lowest since July, the Energy Department reported yesterday. “Heating oil is going out stronger for the year primarily because they keep extending the cold weather forecast,” said Gene McGillian, an analyst and broker at Tradition Energy in Stamford, Connecticut.

Heating oil for January delivery rose a seventh straight day, gaining 0.95 cent, or 0.5 percent, to settle at $2.1188 a gallon on the New York Mercantile Exchange, the highest settlement price since Nov. 4, 2008. Futures advanced 4.1 percent this week and gained 5 percent in December. January contracts for heating oil and gasoline expired at the end of trading today. The more actively traded February heating oil contract fell 0.46 cent to settle at $2.1156. January flipped to a 0.32 cent premium to February, from a discount of 2.06 cents on Dec. 24, indicating tighter supplies.....Read the entire article.

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