Phillips 66 2nd Quarter Profit Falls 19 Percent

COT Fund favorite Phillips 66 announces earnings today and states that second quarter earnings plummeted 19 percent as it failed to get the price advantage it got previously from refining U.S. crude oil and dealt with refinery outages.

The refining division's adjusted earnings fell by nearly half partly due to outages at several refineries, including the Sweeny refinery built in Texas in 1942 and the Wood River refinery built in Illinois in 2003. Earnings from the chemicals division fell too.

The company said it earned $958 million, or $1.53 per share, compared with $1.18 billion, or $1.86 per share, a year earlier.

Excluding a gain on asset sales, adjusted earnings were $935 million, or $1.50 per share. Revenue fell 8 percent to $43.95 billion.

Analysts expected the company to earn $1.81 per share on revenue of $42.03 billion, according to FactSet.

Phillips 66 shares fell $1.32, or 2.3 percent, to $57.15 in premarket trading.

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Trading Tips from John D. Rockefeller

John D. Rockefeller was America's first billionaire. After the civil war Rockefeller had a good amount of money with which to invest. He (correctly) believed railroads would become the primary means to transport agricultural products and would open up the vast western lands to eastern markets, trends that didn't bode well for his own produce shipping. He began to look for other business ventures that could be profitable and found a fledgling sector poised to take off.....the oil industry.

However, where he and his partners entered was not in oil production, but its refining. The same railroads that would eclipse his shipping business would help launch his refining venture, as Cleveland enjoyed not the usual one rail line, but two. Transportation costs would be lower and thus his refinery products more competitive.

By the late 1860s, only five years after getting into the oil business, Rockefeller's refining company was the largest in the world. A major reason for his success was a business model that today we call vertical integration. Rockefeller knew that in order to keep costs down, he would have to control both the upstream and the downstream. For example, he even bought his own woodlands for lumber to make his own oil barrels, and built kilns on site to dry the lumber and save shipping weight on its way to (his own) cooperage. His attention to cost cutting was painstaking.

So, can we learn from Rockefeller and put the lessons he learned to work for us in our modern day trading?

Let's try.

Trading like Rockefeller.....

1. Lower your costs. Lower costs mean higher margins and much more resilience during bad times. Rockefeller famously reduced from 40 to 39 the number of drops of solder to close the lids of kerosene cans, saving the company hundreds of thousands of dollars in the long run. He'd also ask for financial statements down to three decimal places, the better to spot inefficiencies in his supply chain and fix them.As investors, follow in Rockefeller's footsteps by investing in companies with low costs, but also reduce the cost basis in the stocks you own.

2. Have you checked lately whether you're getting the best deal from your brokerage? Don't be afraid to take your business somewhere else. Every advantage counts in this fast moving world.

3. Also, are you making the most out of your portfolio? Could you do more with it? It's a good idea to invest a portion (and we do mean just a portion) of your portfolio in equities that can offer higher reward for higher risk. This is especially true if your portfolio is heavy in capital.

4. When the market is turning against you, move on. Had Rockefeller stuck to his grain shipping business, he'd likely not even made a ripple on the pages of financial history. When he spotted opportunity in the up and coming oil industry, he wasn't afraid to abandon what had been a good thing and to take the leap.For us, this advice means sometimes selling companies that are under performing. Knowing when it's time to cut our losses and to turn our capital toward more profitable ventures. The tricky part is knowing when to be patient and hold and when to recognize a true shift in the marketplace....and that comes from reading the signs from Mr. Market.

5. Vertical integration is a hallmark among many strong companies. Part of the reason Rockefeller could edge out his competitors was the fact that he controlled his own supply chain. He noticed very early on that if he did not control many aspects of his production, he would be at a disadvantage when it came to negotiations. And as he expanded his business, he purchased companies that could make the entire refinery process smoother, including pipelines, railroads, and even those woodlands we mentioned.Thus, if we want blue chip companies that will perform well for us over the long term, we should look for firms that are vertically integrated within their own sectors.

6. Patience is key. Rockefeller kept his discipline when he landed in a tough job market after school. As investors, we're looking for companies that can pay good dividends in the long run. However, we must be wary of overpaying for stocks. Being patient, letting the market come to us rather than chase it ourselves, will give us the best bang for our buck.

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Crude Oil Distillation and the Definition of Refinery Capacity

A crude oil refinery is a group of industrial facilities that turns crude oil and other inputs into finished petroleum products. A refinery's capacity refers to the maximum amount of crude oil designed to flow into the distillation unit of a refinery, also known as the crude unit.

The diagram below presents a stylized version of the distillation process. Crude oil is made up of a mixture of hydrocarbons, and the distillation process aims to separate this crude oil into broad categories of its component hydrocarbons, or "fractions." Crude oil is first heated and then put into a distillation column, also known as a still, where different products boil off and are recovered at different temperatures.

Source: U.S. Energy Information Administration.  

Lighter products, such as butane and other liquid petroleum gases (LPG), gasoline blending components, and naphtha, are recovered at the lowest temperatures. Mid-range products include jet fuel, kerosene, and distillates (such as home heating oil and diesel fuel). The heaviest products such as residual fuel oil are recovered at temperatures sometimes over 1,000 degrees Fahrenheit.

The simplest refineries stop at this point. Although not shown in the simplified diagram above, most refineries in the United States reprocess the heavier fractions into lighter products to maximize the output of the most desirable products using more sophisticated refining equipment such as catalytic crackers, reformers, and cokers.

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China's Top Refineries Cut July Output on Weak Demand

Top Chinese refineries will cut crude oil processing runs in July, following gains in the previous two months, as sluggish demand, poor refining margins and high fuel stocks hurt operations, a Reuters poll showed.

The 12 plants, which make up nearly a third of the capacity in China, the world's No.2 oil consumer, are located mostly in coastal areas, and plan to process 2.88 million barrels per day (bpd) of crude oil this month, the poll showed.

The daily rate, which accounts for about 84 percent of their refining capacity, is expected to be 2 percent, or roughly 60,000 bpd, lower than the actual 2.94 million bpd in June.

Oil demand in China posted in April its first yearly fall in at least three years and edged up only 0.8 percent in May as economic growth slowed.

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Williston Basin Crude Oil Production and Takeaway Capacity are Increasing

Crude oil production from the Williston Basin (primarily the Bakken formation) recently increased to more than 600 thousand barrels per day (bbl/d), according to Bentek Energy, LLC (Bentek), testing the ability of the transportation system, oil pipelines, truck deliveries, and rail to move crude oil out of the area (see chart below). The current price gap between Bakken crude oil and West Texas Intermediate (WTI) shows the effects of this constraint. Bentek projects more transportation capacity coming online in 2012, potentially alleviating this constraint.




 Due to pipeline capacity constraints, Williston Basin producers rely on rail and trucks to move additional crude oil out of the region. Because of these transportation constraints, Bakken crude oil currently sells at a discount of $7.50 per barrel to WTI. This discount was as much as $28 per barrel in February 2012 and is expected to continue as long as transportation constraints persist.

Currently, North Dakota has only one refinery, which processes about 58 thousand bbl/d of crude oil. Crude oil is delivered to other markets using a combination of pipeline, rail, and truck. Delivery capability as of April 2012 was: 450 thousand bbl/d by oil pipeline; 150 thousand bbl/d by rail; and small volumes by truck. However, in 2012, incremental additions to rail and oil pipeline capacity for the Williston Basin could total 350 thousand bbl/d.

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EIA: U.S. Imports of Nigerian Crude Oil Have Continued to Decline in 2012

The trend of declining crude oil imports into the United States continued in the first month of 2012. There has been a particularly sharp decline in imports from Nigeria due to the idling in late 2011 of two refineries on the East Coast, which were significant buyers of Nigerian crude, and reduced imports by refiners on the Gulf Coast. Prior to the idling of the refineries, Nigeria typically accounted for about 10% of the crude oil imported into the United States; in January, that share dropped to about 5%.



 In January 2012, imports from Nigeria totaled just 449 thousand barrels per day (bbl/d), a 54% (519 thousand bbl/d) decrease from January 2011, marking the lowest monthly import total from the country since 2002. One third of this decline was the result of two idled Philadelphia area refineries. ConocoPhillips' Trainer refinery (idled in September 2011) and Sunoco's Marcus Hook refinery (idled in December 2011) imported a combined 173 thousand bbl/d of Nigerian crude in January 2011. Most of the remaining decrease in Nigerian imports was the result of several Gulf Coast refiners reducing Nigerian imports in favor of domestically produced crude.

The idled refineries were suited to run light-sweet crude oils, and Nigerian crude oils tended to match well with that requirement. However, because of their quality, Nigerian crude oils are often expensive compared to heavier or more sour crude oils used by many of the Gulf Coast refineries.

 Additionally, Nigerian crudes are currently expensive compared to some of the inland domestic light sweet crudes of similar quality such as West Texas Intermediate (WTI), Bakken, and Eagle Ford. Given the growing production from the Bakken and Eagle Ford formations and associated transportation constraints, these inland crudes have been selling at a discount to waterborne crudes on the Gulf Coast, providing refiners in that area further incentive to switch from imported crude to inland, domestically produced crude when available.

Preliminary weekly data indicate the trend of decreasing Nigerian imports continued in February and March with March imports averaging just 301 thousand bbl/d, which, if confirmed in the monthly data, would represent a 64% decrease compared to March 2011.

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Refinery Utilization Rates React to Economics in 2011

The divergence of West Texas Intermediate (WTI) and Brent crude oil prices in 2011 affected refinery utilization in the United States, particularly in the East Coast (PADD 1) and Midwest (PADD 2) regions. Historically, refineries in these districts operated at 80-90% of their capacity. Changes in refining economics last year contributed to real contrasts in refinery utilization in some of the PADDs (see Overview chart).

Source: U.S. Energy Information Administration, Refinery Utilization and Capacity.

 Some key findings by PADD include:

• PADD 1. East Coast refining typically relies on imports of crude oil based on the Brent crude price, which, on average, increased to a $16-per-barrel premium over WTI spot prices in 2011. As a result, two East Coast refineries idled capacity due to poor economics, while another is considering selling or shutting down. PADD 1 utilization averaged only 68% of operable capacity in 2011, which includes the idle capacity of closed refineries. This utilization rate reflects both the drop in East Coast refining capacity and lower crude oil inputs.
• PADD 2. Midwest refineries benefitted from supplies of less expensive crude oil coming from Canada and increased production in the Bakken formation. Thus, PADD 2 refineries averaged about 91% utilization in 2011, even with increased refining capacity. As a result, PADD 2 average crude oil inputs of nearly 3.4 million barrels per day were at the highest level since 2000.
• PADD 3. Gulf Coast (PADD 3) continued capacity expansions as refineries upgraded infrastructure to maximize yields. Growing oil production in Texas and the Midwest contributed to increased inputs. The Gulf Coast refineries were able to use different types of crude oil to maximize production. Refineries in this region used cheaper sources of crude compared to the rest of the country.
• PADDs 4 and 5. Refinery closures, outages, and a lack of access to less expensive crude oil reduced inputs in 2011 to refineries in PADDs 4 and 5 and helped drive down utilization rates.

 

EIA: U.S. Refineries and Blenders Produced Record Amounts of Distillate Fuels

Source: U.S. Energy Information Administration, Weekly Petroleum Status Report.
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U.S. refiners produced historically high volumes of distillate fuels (a category that includes both diesel fuel and heating oil) and motor gasoline in 2011. By fine-tuning their production mix, refineries consistently set record levels of distillate production, most recently topping 5 million barrels per day (bbl/d) for the weeks ending December 2 and December 16, 2011.

In 2011, weekly distillate production was above the five-year historical range 25 times, and ranked second highest an additional 19 times. Finished motor gasoline production was robust over the same period, but was slightly more in line with production volumes at comparable times of year since 2006.

Because of its chemical composition, crude oil run through a refinery typically yields roughly twice as much motor gasoline as distillate fuels. Therefore, regardless of economic or other incentives, refiners cannot completely stop making some finished petroleum products in favor of others. However, by adjusting downstream processes and the types of crude oil used, refineries can optimize production to fine-tune the balance of their finished products output. For much of 2011, refiners saw favorable margins and robust global demand for distillate fuels. In order to benefit from these trends, refineries:

• Increased crude runs to maximize overall output. This explains why both motor gasoline and distillate fuels production levels are high relative to the five-year historical ranges.
• Shifted production mix. This explains why the distillate fuels production levels exceeded historical ranges in more weeks than motor gasoline production did.
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Since early October, the spot price for ultra-low-sulfur distillate fuel oil rose, while the spot price for motor gasoline (as measured by New York RBOB spot prices in the chart below) declined, widening the spread between these two petroleum product prices. On November 14, 2011, the spot price for ultra-low-sulfur distillate was nearly 65 cents per gallon higher than the spot price for RBOB. The spread between these product prices had not been more than 60 cents per gallon since November 2008.

Source: U.S. Energy Information Administration, based on Bloomberg.

Note: Ultra low sulfur distillate spot prices shown as New York ultra low sulfur distillate spot prices; motor gasoline prices reflect New York RBOB spot prices.

Along with high domestic prices, strong international markets for distillate fuel oils have spurred increased production. In the United States, refineries have typically optimized production for finished motor gasoline to meet high U.S. demand. European refineries, on the other hand, tend to produce higher percentages of distillate fuel oils, as diesel is used more broadly there for transportation.

 Due to crude supply disruptions to European refineries for much of this year, the region has imported more finished products. Weekly U.S. gross distillate export estimates (bound primarily for European and South American markets) were at record levels in the fourth quarter of 2011, topping more than 0.9 million bbl/d in October and November, and exceeding 1 million bbl/d in December.

Robust global distillate demand has led to a significant inventory draw, despite heightened U.S. production. From the end of September to the end of December, U.S. distillate inventories fell by more than 13 million barrels.

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Residual Fuel Consumption in the U.S. Continues to Decline

After reaching a high point of over three million barrels per day (bbl/d) in the late 1970s, demand for residual fuel oil in the United States has steadily declined (product supplied as seen in the chart above is a proxy for demand). Residual fuel is used as fuel for large ships and for electricity generation, industrial process and space heating, and other industrial purposes. Between 2000 and 2010, average annual residual fuel use fell from approximately 900,000 bbl/d to 500,000 bbl/d. It averaged nearly three times that in the 1940s and 1950s. As its name implies, residual fuel oil is the remaining fraction resulting from the crude oil refining process. Because residual fuel is a heavy product, it has limited uses and relatively high emissions.

Source: U.S. Energy Information Administration, Petroleum Supply Monthly.
Note: Product supplied is a proxy for demand.
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Changes on both the residual fuel supply and demand side of the equation are contributing to the downward trend.

Demand The demand-side landscape for residual fuel has changed over the course of the past few decades, particularly in the electric power sector. From 2000 to 2005, natural gas and oil prices tracked closely. Since 2006, the prices of these two fuels decoupled, as rapidly increasing supply drove natural gas prices down. As a result, the power sector began relying more on natural gas and less on residual fuel, except in circumstances where spot natural gas prices soared due to weather-related constraints. Other exceptions include Hawaii, which relies on residual fuel for much of its power generation (58% in 2010). To a lesser degree, Alaska and Florida use residual fuel, and in-city generators in New York City must use a minimum of residual fuel to meet reliability requirements. Other factors accounting for declining generation at residual-fired plants include: the availability of more efficient natural gas combined-cycle units, increased stringency of air emissions, and at times rising sulfur dioxide emissions costs.

Aside from the electricity sector, other major demand sectors, such as transportation, have not seen much change in residual demand over the same period. Residual fuel, often called bunker fuel in this context, continues to power large ships.

Source: U.S. Energy Information Administration, Fuel Oil and Kerosene Sales.
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Supply The supply of residual fuel oil from domestic refining has also declined. U.S. refinery yield for residual fuel oil dropped from 5.8% in 1993 to 3.8% in 2010. Refinery yield represents what finished petroleum products are made from crude oil run through refineries' crude distillate units and other downstream processes. Lighter petroleum products, such as motor gasoline and ultra low sulfur distillate, command higher market prices. Therefore, refineries focus their operations to maximize production of those products. By investing in more sophisticated downstream unit capacity, refineries can increase the amount of lighter products from each barrel of crude, and, as a result, lessen the production of heavier products such as residual fuel oil.

Due to rising gross exports and falling gross imports, the United States became a net exporter of residual fuel oil in 2008 (see chart below). U.S. gross exports of residual fuel oil increased steadily since the early 1990s. Additionally, after a sharp decline in gross imports from a high of more than 1,800 thousand barrels per day in 1973 to a low of less than 200 thousand barrels per day in 1995, gross imports have averaged about 350 thousand barrels per day over the last 10 years.

Source: U.S. Energy Information Administration, Petroleum Supply Monthly.
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ExxonMobil 3rd Quarter Profits Soar 41%

ExxonMobil's third quarter earnings surged 41% as the oil giant continued to benefit from high oil prices and stronger refining margins. Shares were up 1.4% at $82.20 in premarket trading as the results topped estimates.

The world's largest publicly traded oil company by market value has reported stronger results in recent quarters thanks to high oil prices and improved refining performance. Investors are watching this week to see how much of a drag, if any, recent oil price volatility and renewed concerns about the global economy will put on the sector's recent surge in profits.

ConocoPhillips posted a jump in adjusted third quarter profits on Wednesday, though charges weighed down the bottom line. Chevron is expected to post strong profits on Friday.

ExxonMobil reported a profit of $10.33 billion, or $2.13 a share, up from $7.35 billion, or $1.44 a share, a year earlier. Revenue increased 32% to $125.33 billion. Analysts polled by Thomson Reuters most recently forecast earnings of $2.12 a share on revenue of $113.56 billion.

Exploration and production earnings grew 54% amid higher prices for oil and natural gas, partly offset by a production decline of 4%. Refining and distribution business earnings were up 36% amid stronger refining margins. ExxonMobil said it spent $5.5 billion for stock repurchases, buying back 72 million shares. The total included $5 billion of buybacks to reduce shares outstanding.


Posted courtesy of Rigzone.Com


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China Cashes In On Overseas Shopping Spree

The second largest energy consumer, China is quickly becoming one of the most significant energy players in the world. Increasingly in need of fossil fuels to power its burgeoning economy, China's state owned oil companies have sought to acquire oil and gas access rights beyond its borders, snapping up additional reserves that span both hemispheres. Already this year both offshore oil and gas producer China National Offshore Oil Corp. (CNOOC)and refining heavyweight China Petrochemical Corp. (Sinopec) have purchased international assets that will bulk up its already hefty cache of petroleum resources. Respectively, the two companies have acquired stakes in overseas portfolios that include blocks in West Africa and the Middle East.....Complete Story