American Shale Oil In High Demand

The narrative a while back was that the world would face a shortage of heavy crude because sanctions on Iran and Venezuela had reduced production and exports. Some also implied that shale oil would fill up U.S. storage because American refiners were designed to process the heavy, high sulfur crudes from Venezuela, Saudi Arabia, and the like.

But the light, sweet crude is in high demand for export, and that appetite is likely to continue to grow with the implementation of IMO 2020 around the corner, going into effect January 1st. Freight rates from the U.S. Gulf to Europe have surged to record highs.

Equinor ASA and Unipec, the trading arm of China's top refiner Sinopec, have provisionally chartered Aframax tankers for $60,700 per day, an increase of almost 30 percent in a week, a new record high, according to shipbroker Poten & Partners. Aframax tankers are the “workhorse” of the U.S.-Europe oil trade, which has risen more than 60 percent in 2019 compared to 2018.

The EPIC pipeline began service in August. It has the capacity to deliver 400,000 b/d from the Permian Basin to terminals on the Gulf Coast. The new Cactus II pipeline system also started shipping crude oil in August. It has the capacity to deliver 670,000 b/d of crude oil from the Permian.

And the Gray Oak pipeline began service in November and will be capable of delivering 900,000 b/d at capacity. This new takeaway capacity will effectively reduce the production breakeven costs of substantial Permian crude oil because the pipeline charges are significantly lower than trucking costs.

This should provide stimulus to shale oil production growth, which had slowed due to takeaway pipeline capacity constraints.

Exports Rising
U.S. crude oil exports averaged 3.412 million barrels per day for the weeks ending December 13, 2019. Crude oil exports were 33 percent higher than the same weeks last year. But in the year-to-date, exports are over 50 percent higher.

Exports of crude oil and petroleum products have surged to almost 9 million barrels per day. This makes the United States the largest petroleum exporting country in the world.

Net oil imports have recently dropped below zero, making the U.S. a net oil exporter for the first time in modern history. As a result, the U.S. economy is no longer vulnerable overall to a spike in oil prices, though such a development would hurt consumers while helping domestic oil producers.

The U.S. balance of payments and trade would not be adversely impacted. This is a positive tailwind for the value of the U.S. dollar.

It also has political and defense spending implications. For example, following the attacks on Saudi Arabia in September, President Trump did not put the U.S. military at risk to defend KSA. He also did not counter-attack Iran on behalf of Saudi Arabia. The Crown Prince of Saudi Arabia reportedly began talks with Iran to defuse the situation, something the Kingdom did not have to try when the U.S. felt obligated to protect its oil supply for economic reasons.

Conclusions
The U.S. shale revolution is being re-booted by the opening up of new pipes in the second half of 2019. Given strong foreign demand and lower effective breakeven costs, a new surge may be in the works. Market observers who saw growth slowing may be in for a wake-up call over the coming six months when the new economic conditions take hold.

Check back to see my next post!

Best,
Robert Boslego
INO.com Contributor - Energies

One Giant Powder Keg… and the Fuse is Already Lit

By Nick Giambruno

Their mission was to capture, or more likely, kill. Dozens of renegade commandos in three Blackhawk helicopters swooped in on the holiday residence of the president. Immediately, they engaged in a fierce gun battle with the president’s bodyguards and killed a number of them. Tourists in a nearby five-star resort fled for their lives. Their idyllic vacations had turned into a war zone in the blink of an eye.

The president, however, was nowhere to be found. He had been tipped off about the plot and made it to the safety of his private jet. He had cheated death by mere minutes. The renegade soldiers got wind of the escape. They commandeered a couple of F16 fighter jets and sent them to the skies to shoot down the presidential jet. Aware the rebel F16s were hunting them, the president’s pilots were able to obfuscate the identity of their aircraft by altering the jet’s transponder signal.

The transponder is an electronic signal that shows an aircraft’s identity. It’s used by air traffic controllers to keep track of planes in the air. Somehow, the pilots of the presidential jet were able to set their transponder signal to make it appear as if they were instead a civilian passenger jet. The confused rebel fighter jets ran out of fuel and had to return to base before they figured out what happened.

The president had cheated death for the second time that day. This story sounds like something out of a Tom Clancy novel or a Hollywood blockbuster. But it’s not. It happened in real life earlier this summer. In Turkey.
The country is one giant powder keg and the fuse is already lit. When the next global crisis explodes, there’s a good chance Turkey will be involved somehow.

Turkey was founded from the ashes of the Ottoman Empire. It’s where Europe meets Asia. Today, it’s at the epicenter of many crises that are destabilizing the world the migrant disaster in Europe, the ongoing carnage in Iraq and Syria, the battle with ISIS, a conflict with the Kurds, and the new Cold War with Russia. It could soon also play a big role in the collapse of the world’s largest economy, the European Union (EU).

It’s hard to think of another place that has more tripwires for a global meltdown. In light of all these potential triggers as well as the recent failed military coup d’état that killed over 290 people, I thought it was time to take a closer look at Turkey. Doug Casey and I just returned from the crisis stricken country, the latest destination we visited with (literal) blood in the streets.

We put our boots on the ground in the same area where that hit squad of rebel soldiers nearly assassinated Recep Tayyip Erdogan, the Turkish president. (In addition to all of the crises listed above, the Turkish military had invaded northern Syria just before our arrival.)

Perhaps most importantly, Turkey is at the heart of the migrant crisis that is tearing Europe apart. The migrant crisis will be one of the main issues on the minds of Italians as they vote in the upcoming referendum, which could very well decide the fate of the EU and the euro currency. That’s why I’ve spent weeks on the ground in Italy, watching these events unfold.

The Financial Times commented on what would happen if the Italian referendum fails:

It would probably lead to the most violent economic shock in history, dwarfing the Lehman Brothers bankruptcy in 2008 and the 1929 Wall Street crash.

Like with the Brexit vote, the migrant issue and by extension Turkey may determine the outcome of the Italian referendum on December 4, 2016.

Turkey Holds the Keys to the EU’s Future

Parroting U.S. concerns about democracy and human rights, the EU has also harshly criticized Turkey’s response to the failed coup. This hasn’t endeared them to the Turkish government. It’s actually incredibly stupid for the Europeans. And by stupid I mean exactly that an unwitting tendency toward self destruction. The Europeans fail to see the indirect and delayed consequences of their decision to antagonize the Turkish government.

That’s because the Turkish government holds the trump card on what is perhaps the most explosive political issue on the continent right now: the migrant crisis. Concerns about the unprecedented flow of migrants into Europe over the past couple of years played a key role in the Brexit vote. It’s also acting as a political accelerant to the rise of anti-EU parties all over Europe. It’s a simple relationship. The more migrants come to Europe, the more popular anti-EU political parties become, and the weaker the EU itself becomes.

This is where Turkey holds the keys to the future political landscape of Europe. Turkey is a major transit point migrants use on their way to Europe. The Turkish government doesn’t want the migrants to stay in Turkey, so they haven’t really had much of a reason to stop them from leaving for Europe. They even enjoyed the situation because it gave them negotiating leverage with Brussels. The Turks essentially said “give us what we want or we’ll open the floodgates.”

What the Turks want is lots of money and to join the Schengen visa free zone, which allows unfettered access to most of Europe. Brussels partially gave in to the blackmail. They started giving the Turks money to the tune of $6 billion and agreed to hold talks about getting visa-free access to the continent. In return, the Turks would cut off the flow of migrants.

For a while this arrangement worked. But after the attempted coup and then the purge of suspected putschists, the EU cried foul. They deemed the purges to be an erosion of democracy and the rule of law.
They basically told the Erdogan government it can forget about joining the Schengen zone.

Unsurprisingly, the Turkish government not so subtly warned that if the EU walks away from its part of the deal, so will it. Specifically, the Turkish government has threatened to open the migrant floodgates just in time for the Italian referendum and other key European elections. The Italian referendum could very well lead to the end of the euro and the EU itself, while triggering a global financial meltdown of historical proportions.

Turkey sending a new wave of migrants into Europe just before this key vote will help seal its fate.
There are potentially severe consequences in the currency and stock markets. That’s exactly why I recently spent weeks on the ground in Italy getting the scoop on this explosive story that almost nobody else is talking about.

New York Times best selling author Doug Casey and I just released an urgent video with all the details.
Our video reveals how a financial shock far greater than 2008 could strike America on December 4th, 2016. And how it could either wipe out a big part of your savings or be the fortune building opportunity of a lifetime. 

The video describes specific ways to profit as well as which stocks to avoid like radioactive waste. You can get a first look at this video by clicking here.

The article One Giant Powder Keg… and the Fuse is Already Lit was originally published at caseyresearch.com.

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New Video: Kinder Morgan CEO "Sell Off in Stock Price Has Been Completely Indiscriminate"

Kinder Morgan CEO Steve Kean has released a video pitching KMI shares at an all to low price. Kean points out that those low prices are unreasonable due to the fee based nature of Kinder Morgans businesses. Kean points to numerous facts including the likelihood that new Kinder Morgan projects will not be cancelled during a period when the competition is seeing future projects being cancelled at an alarming rate.

Kean believes that the sell off in its stock price this year has been completely indiscriminate, which is creating a buying opportunity for investors. And insiders are backing up his opinion with their own money. Kinder Morgan has very little exposure to commodity prices as its cash flow is locked up while its growth is actually primarily driven by demand for inexpensive natural gas. That's why he remains confident that the company's current dividend is safe and so is the plan to grow the payout by 10% per year through 2020.

Watch the video below.



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Keystone XL Veto is Partisan Political Disaster for America

By Marin Katusa, Chief Energy Investment Strategist

The controversy over the Keystone XL pipeline is proof positive that American politics have gone from debate to pure partisan propaganda – at the expense of business and even common sense.  With over half a million miles of pipeline already, failing to replace that aging infrastructure only means more oil flowing via crumbling pipelines – some 50 years old – and dangerous rail cars, like the one that killed dozens in Quebec in 2013. 

NY Times Best-selling author of The Colder War, Marin Katusa, explains why President Obama’s veto of the Keystone legislation is far riskier than the pipeline itself in this riveting, short video:

For a better understanding of just how much political spin, and outright lies, now come along with news on global energy, read USA Today and Amazon.com best seller: The Colder War: How the Global Energy Trade Slipped from America's Grasp. Get a free sample chapter at www.colder war.com.

The article Keystone XL Veto Is Partisan Political Disaster for America was originally published at casey research

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EIA: Mexico's Energy Ministry Projects Rapid Near Term Growth of Natural Gas Imports from U.S.

 A combination of higher natural gas demand from Mexico's industrial and electric power sectors and increased U.S. natural gas production has resulted in a doubling of U.S. pipeline exports of natural gas to Mexico between 2009 and 2013. Mexico's national energy ministry, SENER, projects that U.S. pipeline exports to Mexico will reach 3.8 billion cubic feet per day (Bcf/d) in 2018. This would be more than double U.S. pipeline exports to Mexico in 2013, which averaged 1.8 Bcf/d. This projected growth is driven mainly by higher demand from Mexico's electric power sector in both the north and interior of the country.



Nearly three quarters of the projected growth in Mexico's natural gas consumption between 2012 and 2027 is projected to occur in the electric power sector (see graph). This growth is largely driven by private and independently operated power plants, whose natural gas consumption is expected to rise at a 7.9% average annual rate, from 1.6 Bcf/d in 2012 to 4.9 Bcf/d in 2027. By contrast, natural gas consumption from plants operated by national energy company CFE grows at just 0.4% per year, from 1.1 Bcf/d in 2012 to 1.2 Bcf/d in 2027. The growth comes largely from new combined cycle plants, which benefit from greater operational efficiencies and lower emission levels compared to other generation sources. Growth sharply accelerates over the near term but continues through 2027, when power sector consumption reaches 58% of total gas consumption, compared to 47% in 2012.

Mexico's projected growth in natural gas consumption occurs in each of its five market regions: Northeast, Northwest, Interior-West, Interior, and South-Southeast. According to SENER, demand growth is particularly strong in the northern and interior regions of the country.



All natural gas pipeline imports from the United States into Mexico enter the country's Northeast and Northwest regions. Some of these imports enter the country as logistical imports on pipelines owned by private entities, as well as by Pemex's natural gas subsidiary PGPB. The term logistical imports refers to imports that arrive in areas with no other form of access to natural gas. The largest growth in projected pipeline imports takes place from nonlogistical imports on PGPB owned pipelines in the Northeast. An increasing portion of this gas flows through the Northeast south to the interior regions, but much of it also serves increased consumption from the Northeast's industrial and electric generation facilities. Higher natural gas pipeline imports from the United States into the Northeast region meet both higher demand from consumers there and the increased pipeline flows from the Northeast to regions further south.

About three quarters of Mexico's natural gas production comes from associated gas that is produced at Pemex's offshore oil platforms in the South-Southeast region. Natural gas production in the South-Southeast is expected to grow by only 0.4% per year through 2019. Pemex consumes increasing amounts of this production in the near term for its exploration, production, and refining activities. With stagnant growth in the production of associated gas in the South-Southeast and limited capacity for future growth in LNG imports, pipeline imports from the United States become the primary means for Mexico to satisfy national demand growth.

SENER has previously made projections that assumed more robust investment in the development of new gas fields, and a more aggressive and diverse range of well productivity rates. SENER's high natural gas production growth projections included the undertaking of an initiative to enhance recovery rates in the South-Southeast of both gas and oil extracted from offshore fields in the Yucatan Peninsula, as well as development in the Northeast of the Sabinas Basin's La Casita shale gas play and Mexico's portion of the Eagle Ford shale play.

However, there are significant factors that could inhibit the development of shale gas and other basins in Mexico, including the geologic complexity and discontinuity of its shale gas areas, the availability of required technology and water resources, security concerns, and a focus on development of crude oil resources. Even if additional development did occur, Mexico's northern regions would likely still see high growth in pipeline imports from the United States, particularly in areas that lack pipeline connectivity to other parts of the country.

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New LNG Plant in North Dakota will Supply Oil and Gas Producers

A new natural gas liquefaction plant is slated to come online this summer in North Dakota to reduce the flaring of gas in the Bakken Formation and provide fuel for Bakken oil and gas operations. The developer, Prairie Companies LLC subsidiary North Dakota LNG, announced earlier this month that the plant would provide an initial 10,000 gallons per day (gal/d) of liquefied natural gas (LNG), and could expand to 66,000 gal/d. Assuming a 10% processing loss, the plant would take in a maximum of 6 million cubic feet per day (MMcf/d) once expanded. In 2012, North Dakota vented and flared 218 MMcf/d of natural gas because of record high oil production and insufficient pipeline takeaway capacity for natural gas produced as a byproduct.

Hess Corporation will supply the natural gas for liquefaction at Prairie's Tioga natural gas processing location. After the LNG is produced, it will be sent via truck to storage sites at drilling locations, where – once regasified – it can be used to power rigs and hydraulic fracturing operations as well as LNG vehicles. LNG itself cannot burn; in its liquefied state, its temperature is minus-260 degrees Fahrenheit. However, as a liquid, it takes up only 1/600th of its volume as a gas, so LNG is an excellent form to store or transport natural gas. Currently, most drilling operations run on diesel, and converting to natural gas provides potentially significant cost savings given the current differential between diesel and natural gas prices. In 2012, EIA estimated that nationally oil and gas companies consumed more than 5 million gal/d of diesel in their operations, representing a significant expense.

While conversion to natural gas might not be possible in many cases, in the past few years, several companies have developed and are marketing technologies that would allow drilling rigs and fracturing pumps to run in both dual fueled and or single fueled modes.

Although the liquefaction plant will be the first LNG project in the Bakken, some producers have begun using natural gas to power their operations, citing cost savings, access to natural gas, and environmental benefits. Statoil uses compressed natural gas (CNG) to fuel some of its drilling equipment. The natural gas is produced in the Bakken and compressed using General Electric's CNG in a Box system.

Additionally, outside of the Bakken, other companies have successfully used natural gas to power drilling operations. In 2012, Seneca Resources and Ensign Drilling installed GE LNG fired engines on drilling rigs in the Marcellus Shale. Apache, Halliburton, and Schlumberger have successfully used CNG and LNG to power hydraulic fracturing operations in the Granite Wash formation in Oklahoma.

Some of these companies have estimated fuel savings on the order of 60% to 70% compared to diesel, as well as payback on the conversion investment in about a year. The basic economics that have driven the recent interest in converting or manufacturing more heavy duty trucks to run on LNG are driving some of the interest in converting to natural gas for fueling stationary oil and gas operations.

Posted courtesy of the EIA


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Obama’s Secret Pipeline

By Marin Katusa, Chief Energy Investment Strategist

Isn’t it odd that an 800 mile pipeline that runs across environmentally sensitive land has been permitted without any mention in the media? Not a word about it from President Obama either.

Obama’s Secret Pipeline will be built over land that’s much more sensitive than that of the Keystone XL pipeline, which gets nothing but front page coverage. It will actually be 17% (six inches) larger in diameter than Keystone XL (36 inches) and it will transport natural gas, not oil.

Bill 138

The Senate of Alaska, the state in which the pipeline will be built, has just passed Bill 138, which makes the state a partner of three of the world’s largest oil companies, including one that has a horrible environmental track record on U.S. soil. In a nutshell, Alaska’s government is now partners with BP, ExxonMobil, and ConocoPhillips.

Only one more signature is required—Governor Sean Parnell’s—and it’s expected that he will sign the deal.

Not Even the US Government Wants US Dollars

For more than 100 years, the U.S. government has been receiving a royalty and tax revenue paid on the amount of oil or natural gas produced on American soil—a fee that is paid in U.S. dollars. Bill 138 has changed this forever.

Instead of Alaska receiving its dues in U.S. dollars, the state legislature has decreed through Bill 138 that the state will be paid “in kind.” In other words, the state will be getting its share of royalty and tax revenue in natural gas instead of U.S. dollars.

For the record, this is the first time ever that a US state has entered into a partnership like this. Essentially, Alaska is now a 25% equity partner with BP, ExxonMobil, and ConocoPhillips—which also requires the state to cough up cold, hard cash to build the entire project, including the 800 mile long, 42 inch wide pipeline.

Overall, the project is currently estimated to cost north of U.S. $50 billion, and we expect that when all the capital expense overruns and government inefficiencies are accounted for, the whole project will come in at more than U.S. $75 billion, using the total costs of similar projects for comparison.

But it will be 2015 before the final negotiations and the specific details of the partnership are agreed on, and remember, the devil is in the details. Who do you think will get the better end of the deal—a bunch of government bureaucrats with zero oil and gas experience, or the world’s top oil and gas producing companies? I know whom I’m betting on.

Which leads us to the point of this weekly missive.

And the Winner of Obama’s Secret Pipeline Is…

We already know which company will be building and operating Obama’s Secret Pipeline. The company I’m talking about has a lower price to earnings (P/E) ratio and a better yield than all of its peers. That’s good, because shareholders get paid a monthly yield for owning the stock while sitting back and watching the share price rise as well.

The Ultimate Oil Toll Booth

Think of it this way: this company charges the world’s most powerful oil and gas producers for every barrel of oil that passes through its “road network,” and now it can also charge the state of Alaska. Regardless of the price of oil or natural gas, this company gets its fee.

It’s a low-risk way to benefit from a high risk enterprise. This company is a current Buy in our Casey Energy Dividends portfolio. The Energy team is currently working hard on the upcoming issue, which will in detail cover the company that’s bound to gain big from Obama’s Secret Pipeline.

I know you haven’t heard about this pipeline yet, but you will soon enough.

That’s what we do here at the Energy Division of Casey Research: We’re the first to uncover breakthrough stories, and the first to uncover the best energy investment opportunities in the world. Doug Casey and I just got back from a whirlwind European tour, where we visited many of Europe’s most promising energy projects.

Here’s a picture of Doug Casey and me at Europe’s largest onshore drill site. This drill rig is 15 stories high and uses about 16,000 liters of diesel a day to turn the drills—which Doug and I are holding in this picture. As a side note, just the crank shaft that we’re holding costs U.S. $2 million—this rig is expensive and gigantic.

For you to get a better perspective on the true size of Europe’s largest onshore drill rig, here is a picture of Doug Casey and me with our friends Frank Holmes, Frank Giustra, and Matt Smith.

(From far left to right: Frank Holmes, Doug Casey, Marin Katusa, Frank Giustra, Matt Smith)

 

Do Your Portfolio a Favor and Try Out the Casey Energy Report

Doug Casey and I have done all the hard work for you. The current issue of the Casey Energy Report is a compilation of our Europe trip, including in-depth descriptions of our site visits and a new recommendation with a hugely promising project in an out-of-the-way European country that we personally checked out. The company is backed by mining giant Frank Giustra, and you bet he knows what he’s doing.

The Casey Energy Report comes with a free one year subscription to Casey Energy Dividends (a $79 value), including, of course, the upcoming May issue with our “Obama’s Secret Pipeline” pick.

There’s no risk in trying it: You have 90 days to find out if it’s right for you—love it or cancel for a full refund. You don’t have to travel 300+ days a year (as we do) to discover the best energy investments in the world—we do it for you.

If you don’t like the Casey Energy Report or don’t make any money within your first three months, just cancel within that time for a full, prompt refund. Even if you miss the cutoff, you can cancel anytime for a prorated refund on the unused part of your subscription. Click here to get started.

The article Obama’s Secret Pipeline was originally published at Casey Research

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Heather Ingrassia: Kinder Morgan Energy Partners: A Few More Reasons Why I'm Staying Bullish

One of our favorite energy writers is Heather Ingrassia. A 28 year old stay at home mom who writes on Seeking Alpha. Today she shares a great article on Kinder Morgan Energy Partners, and yes...we are long. Way long KMP.....

On Tuesday, November 12, a number of Deutsche Bank's MLP analysts pointed out several significant trends which indicate an improved outlook for the natural gas and MLP sectors. According to the analysts at Deutsche Bank, "the annualized rate of dividend growth among the natural gas companies rose to 13.9% from ~12% earlier this year, and the MLPs' annualized rate of distribution growth rose to 8.7% from a previous estimate of 7%".

In the wake of Deutsche Bank's findings, I wanted to highlight a number of the reasons why I remain long on shares of Kinder Morgan Energy Partners LP (KMP), especially since the MLP is considered to be a top pick at DB.

Recent Performance & Trend Behavior

On Wednesday shares of KMP, which currently possess a market cap of $35.09 billion, a beta of 0.39, a forward P/E ratio of 29.32, and a current dividend yield of 6.69% ($5.40), settled at a price of $80.67/share.

Based on their closing price of $80.67/share, shares of KMP are trading 0.56% below their 20 day simple moving average, 1.40% above their 50 day simple moving average, and 2.02% below their 200 day simple moving average. These numbers would normally indicate a short term and long term downtrend for the stock and generally translate into a moderate selling mode for most near term traders and some longer term investors.

That being said, and as a long term investor, I plan on highlighting a number of reasons why I think investors should buck the current trend and establish a long term position at current levels.....Read "A Few More Reasons Why I'm Staying Bullish"

 

How to Beat the Market Makers at Their Own game

Federal Railroad Administration tightens crude oil regulations

In an effort to improve safety, the Federal Railroad Administration discussed plans to begin asking shipping companies to provide its supply data for crude oil shipments, according to The Wall Street Journal. The FRA believes that some crude oil shipments are transported in unsafe tanker cars.

By using the supply data, the FRA will investigate whether certain oil companies are shipping crude oil with chemicals that would make the transport more hazardous than their current classification.

Some tanker cars have been reported to show "severe corrosion," possibly as a result of the dangerous chemicals included in the mixture.

If shipping companies are unable to provide their supply data, the FRA will work with the Pipeline and Hazardous Materials Safety Administration to independently test specific cars.

The aggressive approach by the FRA comes after a runaway train derailed and exploded in the Quebec town of Lac-Mégantic. The train was carrying 72 crude oil tanker cars. Forty seven people were killed in the blast.

"They seem to be saying, 'Get your house in order or we'll do it for you,'" said Grady Cothen, a former FRA safety official.

More information about integrity management issues in the United States can be found at PennEnergy's research area.

Posted courtesy of our friends at PennEnergy


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Kinder Morgan Energy Partners (NYSE: KMP) today increased its quarterly cash distribution per common unit to $1.32 ($5.28 annualized) payable on Aug. 14, 2013, to unitholders of record as of July 31, 2013. This represents a 7 percent increase over the second quarter 2012 cash distribution per unit of $1.23 ($4.92 annualized) and is up from $1.30 per unit ($5.20 annualized) for the first quarter of 2013. KMP has increased the distribution 48 times since current management took over in February 1997.

Chairman and CEO Richard D. Kinder said, “KMP had a strong second quarter as our stable and diversified assets continued to grow and produce incremental cash flow. Our five business segments produced approximately $1.337 billion in segment earnings before DD&A and certain items, up 39 percent from the second quarter of 2012. Growth was spearheaded by the drop downs from Kinder Morgan, Inc. associated with its acquisition of El Paso Corporation last year, contributions from the midstream assets we recently acquired in the Copano Energy transaction, strong oil production in our CO2 segment and good results at our Products Pipelines business.

Looking forward, we see exceptional growth opportunities across all of our business segments, as there is a need to build additional midstream infrastructure to move or store oil, gas and liquids from the prolific shale plays in the United States and the oilsands in Alberta, along with increasing demand for CO2, which is used for enhanced oil recovery. We currently have identified approximately $13 billion in expansion and joint venture investments at KMP and we are pursuing customer commitments for additional projects.”

Read the entire KMP earnings report.



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Kinder Morgan Completes Acquisition of Copano Energy KMP CPNO

COT fund favorite Kinder Morgan Energy Partners (NYSE: KMP) today closed its previously announced acquisition of Houston based Copano Energy (NASDAQ:CPNO). KMP has acquired all of Copano’s outstanding units for a total purchase price of approximately $5 billion, including the assumption of debt. The transaction, which was approved by the Copano unitholders on April 30 (with more than 99 percent of the units that voted voting in favor of the transaction) and previously by the boards of directors of both companies, is a 100 percent unit for unit transaction with an exchange ratio of .4563 KMP units per Copano unit.

“We are delighted to complete this transaction, which will enable us to significantly expand our midstream services footprint and offer a wider array of services to our customers,” said KMP Chairman and CEO Richard D. Kinder. “We will now pursue incremental development in the Eagle Ford Shale play in South Texas, and gain entry into the Barnett Shale Combo in North Texas and the Mississippi Lime and Woodford shales in Oklahoma. The transaction is expected to be modestly accretive to KMP in 2013, given the partial year, and about $0.10 per unit accretive for at least the next five years beginning in 2014”......Read the entire Kinder Morgan press release.


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Monday's Earnings Reports.....Atlas Pipeline Partners [APL] and Ensco [ESV]

Atlas Pipeline Partners (NYSE: APL) today reported adjusted earnings before interest, income taxes, depreciation and amortization ("Adjusted EBITDA"), of $67.7 million for the first quarter of 2013, driven primarily by a continued increase in volumes across the Partnership's gathering and processing systems. Processed natural gas volumes averaged 1,033 million cubic feet per day ("MMCFD"), a 63% increase over the first quarter of 2012.

Distributable Cash Flow was $43.5 million for the first quarter of 2013, or $0.67 per average common limited partner unit, compared to $35.2 million for the prior year's first quarter. The Partnership recognized a net loss of $27.5 million for the first quarter of 2013, which included a $26.6 million loss on the early retirement of the Partnership's 8.75% Senior Notes due 2018, compared with net income of $6.5 million for the prior year first quarter.

Adjusted EBITDA and Distributable Cash Flow are non-GAAP financial measures, which are reconciled to their most directly comparable GAAP measures in the tables included at the end of this news release. The Partnership believes these measures provide a more accurate comparison of the operating results for the periods presented......Read the entire Atlas Pipeline Partners earnings report.

Ensco plc (NYSE: ESV) reported diluted earnings per share from continuing operations of $1.36 in first quarter 2013, compared to $1.20 per share in first quarter 2012. Discontinued operations primarily related to rigs and other assets no longer on the Company’s balance sheet resulted in a loss of $0.05 per share a year ago. Diluted earnings per share increased 18% year to year to $1.36 from $1.15 in first quarter 2012.

Earnings increased $52 million to $317 million and operating income grew 17% to $402 million on record revenues of $1.150 billion in first quarter 2013. These increases were driven by a $28,000 increase in the average day rate and a 6% increase in floater rig days as new rigs were added to the active fleet......Read the entire Ensco earnings report.

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Spot Natural Gas Prices at Marcellus Trading Point Reflect Pipeline Constraints

How To Position Yourself for a 10 Year Pattern Breakout

Daily natural gas spot prices between Tennessee Gas Pipeline (TGP) Zone 4 Marcellus and Henry Hub have diverged recently largely due to rising Marcellus production, which has outpaced the growth of available take away pipeline capacity in northern Pennsylvania. As a result, the spot price of natural gas at the TGP Zone 4 Marcellus trading point has fallen, at times considerably, below the spot price at Henry Hub in Louisiana, and is currently the least expensive wholesale natural gas in North America.

To address this rapid growth in natural gas production, several Northeast interstate pipeline projects were completed in 2011, adding nearly 1.5 billion cubic feet per day (Bcf/d) of capacity in Pennsylvania. Many additional pipeline projects have been proposed or are in various stages of completion in the Northeast to reduce transportation constraints caused by growing Marcellus natural gas production. EIA's website has information on the status of some of these pipeline projects.



Dry natural gas production in Pennsylvania, a key part of the Marcellus supply basin, continues to grow and according to Bentek Energy is now approaching 6 Bcf/d. Estimated June 2012 Marcellus dry natural gas production (5.7 Bcf/d) has nearly doubled since June 2011 (2.9 Bcf/d) and represents about 9% of overall U.S. dry natural gas production. Further, Bentek Energy estimates that there are over 1,000 natural gas wells that have been drilled in northern Pennsylvania but which are not yet producing natural gas because there is not enough interstate and gathering pipeline infrastructure to accommodate the new production.

Source: U.S. Energy Information Administration based on Bentek Energy, LLC.

Note: Reflects monthly averages of Bentek Energy's daily estimates of dry natural gas production for the state of Pennsylvania. These figures exclude a small amount of natural gas production received directly by local distribution companies and end users via gathering lines that are not subject to Federal Energy Regulatory Commission posting requirements for interstate natural gas pipelines.     

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New Pipeline Project Could Lower Natural Gas Transportation Costs to New York City

Future natural gas transportation costs to New York City could be reduced with the expansion of the existing Texas Eastern Transmission pipeline from Linden, New Jersey to Manhattan, New York (see map above). On May 22, 2012, the Federal Energy Regulatory Commission (FERC), the main jurisdictional authority over the construction of interstate natural gas pipelines in the United States, approved an 800,000 million British thermal unit (MMBtu) per day, or 800,000 dekatherms per day, expansion of the pipeline.

This project is slated to begin service in November 2013 and represents one of the biggest transportation service expansions in the Northeast during the past two decades. The project could have the following effects on the New York City market: reduce reliance on oil fired generators, enhance the reliability of natural gas supplies, and lower transportation costs especially in the winter. Spectra Energy secured firm transportation agreements for this expansion with these customers: Consolidated Edison (170,000 MMBtu per day); Chesapeake Energy Marketing, Inc. (425,250 MMBtu per day); and Statoil Natural Gas LLC (204,750 MMBtu per day).

         

Read the entire post at EIA.com

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Crude Oil May Fall as Seaway May Prove Insufficient to Ease Glut

Here is the simple truth about trends

Crude oil may decline next week on concern that the reversal of the Seaway Pipeline will not be enough to alleviate a record supply glut in the central U.S., a Bloomberg survey showed.

Nineteen of 34 analysts, or 56 percent, forecast oil will drop through May 25. Nine respondents, or 26 percent, predicted prices will rise and six estimated they will be little changed. Last week, 48 percent of surveyed analysts expected a decrease.

Enbridge Inc. (ENB) and Enterprise Products Partners LP (EPD) completed the pipeline reversal yesterday and plan to start shipping oil this weekend from Cushing, Oklahoma, the delivery point for West Texas Intermediate oil futures traded in New York, to the Gulf Coast. U.S. oil inventories rose to a 22 year high and Cushing stockpiles peaked in the week ended May 11 as domestic output increased, according to the Energy Department.....Read the entire Bloomberg article.


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TransCanada Re-Applies for Keystone XL Pipeline Permit

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TransCanada Corp. (TRP) has re-applied for a U.S. permit for the Keystone XL oil pipeline, seeking permission to build a $5.3 billion portion of the original project from the Canadian border to Steele City, Nebraska.

The application uses already reviewed routes through Montana and South Dakota and will add an “alternative” path through Nebraska determined by the state’s Department of Environmental Quality, according to a statement from the Calgary based company today.

“There is no win by denying this pipeline,” TransCanada Chief Executive Officer Russ Girling said today in a telephone interview. “There are several wins, energy security, economic development, jobs, wealth creation and less of an environmental impact, as a result of approving the pipeline”.....Read the entire Bloomberg article.

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Don’t Count Your Easter Eggs Before They Hatch and do not Count......

From guest blogger Phil Flynn......

Don’t count your Easter eggs before they are hatched and do not count your barrels of oil until they come into port. A supply side surge in oil and a seemingly faltering Eurozone sent oil prices crashing back down to earth. The Energy Information Administration sent oil on a big ride by reporting that U.S. commercial crude oil inventories increased by 9.0 million barrels from the previous week. At 362.4 million barrels, U.S. crude oil inventories are above the upper limit of the average range for this time of year.

The build came after a surge of delayed imports. The EIA reported that U.S. crude oil imports averaged nearly 9.8 million barrels per day last week, up by 505 thousand barrels per day from the previous week. Over the last four weeks, crude oil imports have averaged about 9.0 million barrels per day, 59 thousand barrels per day above the same four week period last year. We saw a supply surge into the Gulf Coast as all of the crude that was lost in the fog showed up all at once. We also saw supply increase into Cushing, Oklahoma.

In an excellent article the EIA says that, “Crude oil inventories at the Cushing, Oklahoma storage hub, the delivery point for the NYMEX light sweet crude oil futures contract, have risen by 12.0 million barrels (43%) between January 13, 2012 and March 30, 2012. This was the largest increase in inventories over an 11 week period since 2009. The inventory builds can be partly attributed to the emptying of the Seaway Pipeline, which ran from the Houston area to Cushing, in advance of its reversal. While Cushing inventories are now approaching the record levels of 2011, the amount of available storage capacity at Cushing is much greater now than it was a year ago, relieving some of the pressure on demand for incremental storage capacity.

Historically, the Seaway Pipeline delivered crude oil from the U.S. Gulf Coast to Cushing, where it then moved to the refineries connected by pipeline to the storage hub. In November 2011, Enbridge Inc. acquired a 50% share in the pipeline from ConocoPhillips; at this time, Enbridge and joint owner Enterprise Product Partners announced they would reverse the direction of the pipeline to flow from Cushing to the Gulf Coast. Currently, the pipeline is expected to deliver 150,000 barrels per day (bbl/d) from Cushing to the Gulf Coast beginning in June 2012. The companies plan to expand Seaway's capacity to 400,000 bbl/d in 2013 and to 850,000 bbl/d in 2014."

"In early March, approximately 2.2 million barrels from the Seaway pipeline was emptied into Cushing storage in order to prepare for the pipeline's reversal. This accounts for about 20% of the build in inventories during this period. However, even without the emptying of Seaway, inventory builds over the past months have been particularly steep compared to the five year average. As of January 13, Cushing inventories stood at 28.3 million barrels, slightly below their seasonal five year average. After the 12.0 million barrel increase, inventories were almost 11 million barrels above their average level, the largest such variation to average since June 2011. This is largely due to flows into Cushing as a result of increasing production in the mid-continent region."

If you thought the euro crisis was solved with the Greek bailout then you were counting your Easter Eggs before they were hatched. Of course oil will focus on demand and the fear it may slow. The euro zone looks like it is headed back into a crisis. Weaker than expected data and concerns about Spain. A weak Spanish bond auction is raising fears that Spain is on a path to economic crisis bringing the EU and the world down with it. Here we go again.


Phil can be reached at 800-935-6487 or email him at pflynn@pfgbest.com

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Natural Gas Pipeline Capacity Additions in 2011

The U.S. Energy Information Administration estimates that U.S. natural gas pipeline companies added about 2,400 miles of new pipe to the grid as part of over 25 projects in 2011. New pipeline projects entered service in parts of the U.S. natural gas grid that can be congested: California, Florida, and parts of the Northeast (see map above). Only a portion of this capacity serves incremental natural gas use; most of these projects facilitate better linkages across the existing natural gas grid.

By convention, the industry expresses annual capacity additions as the sum of the capacities of all the projects completed in that year. By this measure, the industry added 13.7 billion cubic feet per day (Bcf/d) of new capacity to the grid in 2011. The six largest projects put into service in 2011 added 1,553 miles and about 8.2 Bcf/d of new capacity to the system. Much of this new capacity is for transporting natural gas between states rather than within states. Golden Pass, Ruby Pipeline, FGT Phase VIII, Pascagoula Expansion, and Bison Pipeline projects added 6.1 Bcf/d, or about 80%, of new state to state capacity.

Natural gas pipeline capacity additions in 2011 were well above the 10 Bcf/d levels typical from 2001-2006, roughly the same as additions in 2007 and 2010, but significantly below additions in 2008 and 2009 (see chart below). Capacity added in 2008 and 2009 reflected a mix of intrastate and interstate natural gas pipeline expansions, related mostly to shale production, liquefied natural gas (LNG) terminals, and storage facilities.

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EIA: Market Changes Contribute to Growing Marcellus Area Spot Natural Gas Trading

Marcellus-area spot natural gas trading (InterContinentalExchange (ICE) day-ahead transactions) has more than doubled from under 1 billion cubic feet per day (Bcfd) to almost 2 Bcfd on average since 2005 (see chart). The largest gains in Marcellus area trading volumes were at the Tetco M3 trading point, up 178% to 0.5 Bcfd and at the Dominion South trading point, up 168% to 0.7 Bcfd since 2005. Key factors likely contributing to increased natural gas spot trading in the Marcellus area include: rapid increases in Marcellus shale gas production; direct deliveries of Wyoming gas to the Ohio/Pennsylvania border through the Rockies Express Pipeline; and increased use of natural gas for power generation.

Source: U.S. Energy Information Administration, based on Ventyx's Energy Velocity Suite.

Note: New Marcellus in the graph includes the Leidy, TGP 219, TGP 313, and TGP Zone 4 Marcellus trading points. 2011 includes data through November.

 Several factors are likely contributing to increased natural gas spot trading in the Marcellus area:

• Marcellus production gains. Bentek Energy, LLC estimates that Marcellus natural gas production now exceeds 4 Bcfd, up significantly in recent years.
• New trading points. In addition to several new Marcellus production area trading points, the extension of the Rockies Express Pipeline (REX) to Clarington, Ohio led to new natural gas trading points formed to facilitate commercial transactions. REX deliveries to Clarington, Ohio averaged over 1 Bcfd from January through December of 2011.
• Greater reliance on natural gas for electricity generation. Falling natural gas prices coupled with historically high spot coal prices created incentives for generators to use more natural gas to fuel their plants. Pennsylvania is one state that has seen significant growth in natural gas-fired electric generation.

Source: U.S. Energy Information Administration, based on Ventyx's Energy Velocity Suite. 

Proposed KMI and El Paso Merger Would Create Largest U.S. Natural Gas Pipeline Company

The proposed merger of Kinder Morgan Inc. (KMI) and El Paso Corp. (El Paso) announced on October 16, 2011 would create the nation's largest natural gas pipeline company. If approved by state and federal regulatory officials, the combined company would operate about 67,000 miles of natural gas pipelines (see the blue and red lines in the map), or about 22% the U.S. natural gas pipeline network. Upon closing, the proposed $38 billion transaction would be one of the biggest natural gas pipeline mergers in United States history.

El Paso's natural gas pipeline network complements Kinder Morgan's natural gas system. By adding El Paso's network to its own, KMI increases its access to natural gas markets in the Southwest, Southeast, Northwest, and Northeast. El Paso has been extending its reach into these markets. In 2011, El Paso completed three major pipeline projects: Ruby Pipeline, Florida Gas Transmission Phase VIII, and Tennessee Gas Pipeline 300 Line, in total adding around 1,200 miles and 2.6 billion cubic feet per day of capacity to its network.

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

Note: The labeled brown bars represent the four largest deals since 1996. Total transaction value only includes completed and pending deals based on the announcement year.
*Pending transaction

As measured by total dollars, 2011 has been a significant year so far for mergers and acquisitions in the natural gas transmission sector compared with previous years. The proposed merger between Kinder Morgan and El Paso could be the largest U.S. pipeline related merger and acquisition since 1996, representing about 54% of the total transaction value of proposed or concluded mergers so far in 2011, according to SNL Financial.

On June 15, 2011, Energy Transfer Equity agreed to acquire Southern Union for $9.2 billion, making it the second largest pending natural gas pipeline-related deal in 2011. Since 1996, three natural gas transmission mergers and acquisitions deals over $20 billion were concluded according to data from SNL Financial: a $22 billion deal between El Paso and Coastal Corp in 2000; a $21 billion leveraged buyout deal of Kinder Morgan by a group of private investors in 2006; and a $20 billion deal between Enterprise Products Partners and Enterprise GP Holdings in 2010.


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