Better Odds With Pipelines

The mood at the 2019 Midstream Energy Infrastructure Conference was noticeably more positive than in the past couple of years. Perhaps relocating from Orlando to Las Vegas helped. Hope for positive financial outcomes is in the local DNA, and pipeline investors could smugly remind themselves that the best odds were not in the casino. Attendance seemed to be higher than in the recent past, and demand for one-on-one meetings with management teams (the point of attending for many, including ourselves) was reportedly up sharply.

Investors keep pounding away on planned growth capex, and companies are generally responding by guiding to less spending this year and next while still emphasizing their slate of attractive opportunities. We checked our assumptions underlying The Coming Pipeline Cash Gusher in several meetings and still see a substantial jump in industry free cash flow over the next three years.

 

 

Henry & Simon MEIC

 

 

New pipelines are becoming harder to build. New York recently blocked a natural gas pipeline planned by Williams Companies (WMB) because of environmental concerns, although WMB plans to reapply. Canada is becoming a more difficult and expensive place in which to build (other than in oil-rich Alberta). Enbridge (ENB) went as far as to say they wouldn’t attempt a new, greenfield crude oil pipeline in Canada. They regard the permitting process as capricious, hijacked by a small minority of vocal environmental activists that don’t reflect the public interest.

Impeding new construction simply increases the value of the existing asset base. It also means that today’s dominant firms will maintain their market positions in the future; this is not an industry where a disruptive start-up has realistic prospects.

It also creates an unusual alignment of interests between anti-fossil fuel, environmental activists and investors who are clamoring for a greater return of cash to owners. Both are opposed to new spending, albeit for different reasons.

Tellurian (TELL) is developing a Liquified Natural Gas (LNG) export complex. Their unusual financing model involves raising equity capital from customers. In this way they share some of the project’s upside and create key long term partnerships. They see growing Permian crude production leading to a huge jump in associated natural gas output, creating the need for an additional 20 Billion Cubic Feet per day (BCF/D) of LNG export capacity.

Incidentally, in a panel on LNG, Andy Orekar of Gaslog Partners said that if all the world’s shipping converted to LNG (because of the impending IMO 2020 standards on maritime emissions) it would consume more than all of the current trade in LNG. Currently, gas-powered ships are limited to LNG tankers that consume a small portion of their cargo for power. It’s a theoretical point since the industry is installing sulfur scrubbers and switching to cleaner crude oil-based fuels, but an interesting one nonetheless.

Today the U.S. exports around 4 BCF/D. Because natural gas is an inevitable byproduct of crude production in the Permian, TELL expects the economics of oil to drive more gas output which will need to be sent somewhere. They believe the Permian may produce as much as 30BCF/D, creating a need for almost all proposed LNG projects. Increased domestic consumption and pipeline exports to Mexico will only soak up so much, with seaborne LNG exports being critical to avoid constraints on crude production. Flaring unwanted natural gas is limited, and the larger companies that are now dominating Permian activity are especially likely to avoid the negative publicity associated with such obvious waste.

Private equity has developed into an alternative source of financing for midstream infrastructure since public market valuations essentially render equity financing prohibitive. This highlights the contrast between how public and private markets view the sector. Although private funds can compete effectively for projects, it’s also made exits harder, leading to longer holding periods that can reduce returns. The traditional arbitrage, in which public buyers acquire assets at higher multiples than paid by private equity, is currently being reversed. This reflects the continued public market wariness of midstream energy infrastructure, and highlights currently attractive valuations.

Most firms now have a set of policies covering ESG (Environmental, Social and Governance). This is regarded by some as a requirement for drawing in generalist investor interest. One company noted that European investors were more likely to use ESG as a screening metric, and reported that they had seen a notable pick up in interest from non-traditional investors in response to their adopting ESG policies. Mentioning Energy Transfer (ET) in the context of ESG invariably draws a chuckle (see Why Energy Transfer Can’t Get Respect)

A meeting with Enterprise Products Partners (EPD) produced some useful insights. They regard U.S. crude oil export infrastructure as still catching up with volumes. Building a facility to accommodate Very Large Crude Carriers (VLCC) is an important objective for them. The application to build this terminal was 13,000 pages and weighed 100 lbs.

EPD also sees very strong Chinese demand for U.S. exports of ethane and propane, with the current trade dispute not regarded as a long-term problem.

The “War on Plastics” led them to point out the slide shown below, which highlights how much of global plastics pollution can be traced back to ineffective disposal among some Asian countries.

Poor Plastics Disposal

Overall, the news was good and growing free cash flows are beginning to draw interest from a wider pool of investors. We left with reinforced conviction that valuations are excessively pessimistic. Strong returns lie ahead.

We are invested in ENB, EPD, ET, TELL and WMB.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

Why Energy Transfer Can’t Get Respect

If Energy Transfer (ET) was a private company contemplating an IPO, the 15% Distributable Cash Flow (DCF) yield indicated by their underwriters would draw laughter. The bankers would be ushered out of the conference room.

Yet that is the lowly valuation investors assign to perhaps the least loved pipeline company in a sector that investors find lukewarm at best. ET is priced far below where they’d take the company public, if it wasn’t already a listed company. CEO Kelcy Warren and his team continue to execute and beat expectations on earnings. Last August Kelcy joked that, “A monkey could make money in this business right now.” (see Running Pipelines is Easy). Inviting critics to find fault, they nonetheless still deliver good results. Unlike most MLPs, ET (legacy Energy Transfer Equity) has never cut its distribution.

The market prefers style over substance, for on the soft issues of PR and Investor Relations (IR), ET’s record is sharply at odds with their financial performance. From their ill-fated pursuit of Williams Companies (WMB), the dubious dilution of shareholders with management-only convertible preferreds (see Will Energy Transfer Act with Integrity?) and the optically poor dispute over the Dakota Access Pipeline, this is a company that cares little about its image. Pennsylvania’s huge natural gas boom has been helped by a generally pro-energy regulatory regime, but ET has even managed to make enemies there.

ET’s PR staff must get combat pay.

Warren Buffett recently explained how Berkshire’s (BRK) $10BN investment in Occidental (OXY) was negotiated with no contingencies (save that they acquire Anadarko). Buffett needs to trust his investment partners. On this basis, ET is an implausible candidate for a BRK investment.

On the 1Q19 earnings call, Kelcy commented on how he is listening to the market. He’s been, “…trying to understand what the market would like to see us to do. What causes our unit price to perform better, in other words.”

Our advice would be start behaving like the kind of company that would interest Buffett.

ET’s 1Q19 earnings included EBITDA of $2.8BN and distribution coverage was ample at 2.07X. This exceeded expectations, although the 8% yield suggests some fear a cut. They guided to $10.7BN in 2019 adjusted EBITDA. ET’s stock had weakened over the prior month, so expectations weren’t high. Nonetheless, on the day following earnings ET slumped 1.3%, twice the drop in the broad-based American Energy Independence Index.

Kelcy Warren might compare ET with another big pipeline company, Plains All American (PAGP). If ET has delivered consistently good operating results distorted by a bad corporate image, PAGP has done the opposite. Their distribution relied unwisely on a volatile business segment (Supply and Logistics, S&L) whose arbitrage margins virtually disappeared from 2013 to 2017. The narrative accompanying results changed from “it’s skill not luck” to “forces out of our control”. The 2016 sweetheart “One and Done” preferred deal to shore up finances was anything but.

DCF Yield Growth ET vs PAGP

PAGP’s 2017 acquisition of the Alpha Crude Connector was ill-advised, and along with other growth projects exposed too-high leverage when margins fell. As a result, investors in PAGP subsequently suffered two distribution cuts.  Back in 2010 when the shale oil boom was in its infancy, PAA yield seeking investors received $3.75/unit in distributions.  In 2018 they received just $1.20 per unit.  It’s why income-seeking investors often feel so betrayed by MLPs. Nonetheless, the market has not punished PAGP’s stock as much as ET’s, although it’s also cheap. Former CEO Greg Armstrong’s folksy style created sufficient goodwill among investors that PAGP has a distribution yield a third less than ET’s. Their DCF and free cash flow are growing, but not as fast as at ET.

PAGP’s 1Q19 results were also good, buoyed by their resurgent S&L segment. Their 10% DCF yield reflects some concern that past mistakes will be repeated, and arbitrage margins are hard to forecast because they rely on shortages of pipeline capacity which can be fleeting. But their IR people at least have a more positive corporate image against which to tell their story.

As if to punctuate attractive valuations, on Friday Buckeye (BPL) was acquired at a 32% premium to its recent average price. BPL’s foray into international storage terminals led to chronic underperformance in recent years that even the buyout hasn’t rectified. They have mismanaged themselves into a takeover, at pricing substantially higher than ET’s.

Both ET and PAGP are cheap. They each possess skills that would benefit the other. ET’s rebarbative management style contrasts with their efficient execution and strategic foresight, an area where PAGP needs to regain credibility after mis-steps in recent years. ET walks the walk, and PAGP talks the talk.

If each company can improve its weaknesses, they’ll continue to draw investors to an extremely cheap sector offering substantial growth.

We are invested in BRK, ET, PAGP, and WMB.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

Buffett Finds Value in Shale

Warren Buffett likes the Permian Basin. This was clear from Berkshire’s (BRK) proposed $10BN preferred investment in Occidental (OXY) should they buy Anadarko (APC). Berkshire’s annual shareholder meeting was followed as usual with a Becky Quick interview on CNBC.

Buffet OXY Deal

The 8% dividend on the preferred OXY will issue to finance their acquisition could be inducement enough for BRK to commit $10BN. When Becky commented on this Buffett responded “It isn’t great to have an 8% preferred if there isn’t any oil there.   It’s a bet on oil prices over the long term more than anything else and it’s also a bet on the fact that the Permian basin is what’s it’s cracked up to be. … You have to have a view on oil over time and Charlie and I have got some views on that.”

This led Becky to ask why BRK didn’t use some of its cash hoard to buy Anardarko for $35BN, to which Buffett replied “Well, that might have happened if Anadarko had come to us.”  Buffett was quick to clarify that he wouldn’t jump in to a bidding war with someone who has come to them for financing. Buffett wants more supplicants for similar deals. But it does show that they see value in the Permian Basin, OXY and APC.

The competition between Chevron (CVX) and OXY to buy APC provides further confirmation of a bullish production outlook among those with the best information. CVX and OXY were the two biggest producers in the Permian last year, each pumping over 300 thousand barrels per day (MB/D). APC did 100 MB/D. They know the region. Rystad Energy believes that a CVX/APC combination would reach almost 1.4 Million Barrels per Day (MMB/D) in output by 2025. A match-up of OXY/APC would get to 0.9 MMB/D. Permian volumes are growing fast, and the influx of additional capital makes this even more likely. Midstream energy infrastructure is a sure winner.

As always, Buffett had some wonderful folksy quips. In discussing his 60-year partnership with Charlie Munger, he noted that they’d often disagreed but never had an argument. Munger sometimes concludes such debates with, “You’ll agree with me soon, because you’re smart and I’m right.”

Try using that at home with your significant other. Let us know how it goes – we’ll publish any credible stories.

Buffett and Munger aren’t overly concerned about the latest ratcheting up of trade tensions. They believe both sides will benefit from concluding a deal. We agree that trade tensions are unlikely to be a factor entering 2020 when Trump is running for re-election (see The Trump Put).  One easy way to reduce the trade deficit is for China to increase it’s purchases of raw materials from the U.S. This could include huge amounts of LNG, natural gas liquids such as propane, and light crude oil that they desperately want and need.

If the dispute is drawn out, planned Chinese purchases of U.S. Liquified Natural Gas (LNG) are at risk. But LNG is fungible, and U.S. exports could displace trade to other Asian countries whose shipments would in turn head to China. Cheniere Energy (ticker: LNG) and Chinese energy firm Sinopec are planning a 20 year LNG deal once the trade negotiations are concluded.

While a full-blown trade war that severely damages global GDP growth can have a meaningful impact on oil demand and oil prices, a resolution should boost demand and clear the way for Chinese buyers to sign long-term contracts from U.S oil and gas exporters.

Moreover, the U.S. just dispatched aircraft carrier Abraham Lincoln to the Persian Gulf so as to, “send a clear and unmistakable message to the Iranian regime…” The Shale Revolution has improved America’s ability to press our interests since we are so much less dependent on Middle East oil. Trump is not one to shy away from a fight. We won’t forecast how events with Iran will play out – but domestic energy investments are one of the safer places to be if there is conflict with Iran.

With historically low valuations for the energy sector, record oil & gas production, and solid growth prospects, the weekend’s news is showing energy to be one of the most overlooked areas in the market.

We are long BRK.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

Pipeline Earnings Good; Investors Skeptical

We’re in the middle of earnings season, and last week several companies provided 1Q reports. The energy sector continues to struggle to excite investors. Although pipelines stocks delivered very strong performance through March, in recent weeks investors have started to question the rally’s resilience.

As a result, sentiment could use a boost from strong earnings. Of the companies we follow, results so far have been at or ahead of expectations. Enterprise Products Partners (EPD) generated almost $2BN in EBITDA during 1Q19, handily beating forecasts. On the earnings call they discussed the conversion of their Seminole pipeline to carry crude oil instead of Natural Gas Liquids (NGL) from the Permian to Mount Belvieu: “…given its location and interconnects, we will always have flexibility to convert this pipeline back to NGL service depending on the pipeline supply demand balances for crude oil and NGLs in the future. I doubt that anyone else will be able to offer this type of future flexibility to Permian producers and to markets.” We get some questions about the likelihood of excess pipeline capacity in the Permian, and this optionality is useful.

There was another interesting exchange on propane exports, where EPD conceded to a drop in market share from 80% to around 50%. They’ve concluded that their pricing was too high, and plan to be more competitive. Energy Transfer (ET) CEO Kelcy Warren complained on their fourth quarter call about spending to protect his turf from competition from fringe private equity projects.  EPD shares the same distaste for new, greenfield projects competing with more economic brownfield expansions on their existing footprint. EPD CEO Jim Teague commented that, “…we’re not going to make the mistake of having prices that (and) invite more competition.”

Takeaway infrastructure for Permian crude production often comes with associated natural gas. Inadequate takeaway infrastructure has led to flaring, and recently pushed prices at the Waha hub collection point negative. On April 3rd, some Exploration and Production (E&P) companies paid $9 per MCF to dispose of natural gas.  Forward price remain negative through 2021.  The crude oil that they’re seeking is sufficiently profitable to cover this additional overhead. Under the circumstances, one might think E&P companies would be pushing for additional natural gas takeaway infrastructure. However, Williams Companies (WMB) CEO Alan Armstrong reported that few were willing to commit volumes on terms to support such an investment.

Earnings reported so far support our free cash flow bridge below, first published last week.

Pipeline Sector Free Cash Flow

WMB earnings were in-line with expectations, and their 2019 growth capex guidance was lowered by $200MM to a range of $2.3BN to $2.5BN.

Capex guidance was generally among the more keenly examined numbers, given past years’ focus on growth projects. Last week we noted that such investment peaked last year, which is supporting growing free cash flow (see The Coming Pipeline Cash Gusher).

Oneok (OKE) logged 12% year-on-year distribution growth, with Distributable Cash Flow (DCF) providing 1.43X coverage while continuing to advance key projects on schedule. Lower payout ratios are the new normal, to provide more flexibility and reduced need to issue equity.

Enlink (ENLC) disappointed with lowered guidance for 2019 natural gas output from Oklahoma, although their overall report was within expectations. Its 14% DCF yield is very attractive and we like the management team.

Crestwood (CEQP) raised 2019 EBITDA and DCF guidance with continued strength from their Bakken assets,and expects 20% DCF growth through next year. Their 13% DCF yield seems unreasonably high.

Western Gas (WES) reported 7% annual distribution growth, but the competition to buy parent Anadarko (APC) will dominate their performance until it’s resolved.

With Occidental (OXY) outbidding Chevron (CVX) for APC, many are surprised that the consolidation and implied vote of confidence in shale from a major oil company isn’t drawing in more support for the energy sector. Berkshire’s (BRK) proposed $10BN investment in OXY via 8% preferred securities with warrants for 80 million shares at an exercise price of $62.50 represents either (a) a valuable endorsement of growing U.S. oil production, or (b) proof of the high cost of capital facing a still unloved energy sector. Whichever it is, the APC M&A saga can surely only be good for midstream energy infrastructure.

More earnings reports are due next week. So far, what we’ve seen is increased capital discipline, lower leverage, growing cash flows and higher coverage ratios. This is consistent with our overall, constructive outlook for the sector.

We are invested in BRK, CEQP, EPD, ENLC, ET, OKE, WES and WMB.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

 

The Coming Pipeline Cash Gusher

Pipeline company earnings are being scrutinized for capital investment plans.  The energy sector’s pursuit of growth has been well covered. Investors would prefer less excitement and more return on capital through dividends and buybacks. Company management teams are for the most part grudgingly co-operating.  Targa (TRGP) CEO Joe Bob Perkins defiantly described growth projects as “capital blessings”. TRGP promptly dropped 5%. Owners want more cash returned.

Distributable Cash Flow (DCF) is the cash return from existing assets. REIT investors know it as Funds From Operations (FFO), an equivalent measure. Because DCF excludes spending on new projects, it reflects steady-state cash earned before growth initiatives. This is why DCF or FFO are commonly used in evaluating businesses whose returns come from large fixed assets, such as infrastructure and real estate.

Free Cash Flow (FCF) is the net cash generated (or spent) after considering DCF, growth projects and any financings and asset sales (i.e. after everything). It’s common for companies that are investing heavily to have little or negative FCF. Investors in such stocks ultimately expect FCF commensurate with sums invested.

Exploiting the Shale Revolution has boosted growth capex by billions of dollars, both for upstream companies as well as the midstream infrastructure sector. It’s why FCF has substantially lagged DCF in recent years. Although today’s income statements don’t show it, a combination of slowing growth capex and rising DCF will cause pipeline companies to produce vastly more FCF.

We examined all the names in the American Energy Independence Index (AEITR), which provides broad exposure to North American midstream corporations along with a few MLPs. On a bottom up basis, FCF was just over $1BN last year, a paltry figure given the industry’s $514BN market cap.

The need for growth capital broke the MLP model (see It’s the Distributions, Stupid!). Their narrow set of income-seeking investors wasn’t willing to support the growing secondary offerings of equity without higher yields. Companies needed to find the cash somewhere, so four years of distribution cuts followed – for example, the Alerian MLP ETF (AMLP) has cut its payout by 36% since 2014, reflecting reduced distributions by the names in its index.

The industry is over the hump of its spending on growth projects. Analysts look carefully for “capex creep” whereby annual guidance for new spending gets revised upward during the year. But based on current bottom-up guidance for the AEITR, we expect such spending to be down 4% this year, with >20% reductions in 2020 and 2021.

Recently completed projects are starting to show up in higher DCF, which we estimate will grow by 8% this year and 12% in 2020. A 90% completed pipeline isn’t much use, and multi-year construction projects only generate cash when they’re completed and paid for.

Making more money from existing assets, while spending less on new ones, is a potent combination. By 2021, FCF is set to be close to what DCF was in 2018. Moreover, much of today’s growth is internally funded, meaning little reliance on issuing equity. Based on current guidance, Transcanada (TRP) is the only company likely to tap the equity markets meaningfully, as construction of the perennially delayed Keystone XL gets under way.

As a result, last year’s sector-wide $1BN in FCF is set to jump eightfold this year, more than triple in 2020, and increase by two thirds again in 2021. It’s why dividend growth is back (see Pipeline Dividends Are Heading Up). Our analysis assumed no new debt issuance, which therefore assumes leverage will continue to decline. To the extent that the industry maintains current Debt:EBITDA ratios by issuing more debt, FCF will grow more than our forecast.

The “bridge” chart illustrates annual FCF 2018-21 with the changes in DCF and growth capex forming the bridge from each year’s FCF to the next.

Pipeline Sector Free Cash Flow

The Shale Revolution has long been described as a huge boost for America, including on this blog. Investors often complain that it’s been a far better story than an investment. The strong start to the year has been a welcome surprise to many long-suffering holders. And yet, a substantial jump in FCF is still not widely expected. The sector has plenty of upside.

We are invested in TRGP and TRP. We are short AMLP.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

Investors Look Warily at the Persian Gulf

The Shale Revolution has certainly provided America with more geopolitical freedom. The 1973 Arab oil embargo punished the U.S. for supporting Israel, as it fought Egypt and Syria. Shortages of gasoline visibly demonstrated the limits to U.S. actions. As a result, every president since Nixon has called for energy independence.

Swaggering energy dominance is the new goal, since independence has, by some measures, already been achieved. But reduced dependence on imports doesn’t bring immunity from price spikes, given that oil is a global commodity easily moved to the most eager buyer.

A benefit of investing in midstream energy infrastructure that we rarely hype is its domesticity. There are pipelines all over the world, but we stick to North America where property rights and rule of law are secure. Weakness in, say, the Turkish lira is of no concern.

Energy markets today are sanguine, in that there is little risk of disruption priced in. Meanwhile, global crude oil demand is growing at around 1.5 Million Barrels per Day (MMB/D). Saudi Aramco’s recent bond offering disclosed production capacity that’s more limited than many had thought.

Venezuela’s output continues to collapse, with U.S. sanctions kicking a chronically mis-managed economy already on its knees. Libya is on the verge of civil war, placing more output at risk. And now the waivers on Iranian exports are about to be cancelled, with the U.S. stated goal of reducing their oil exports to zero.

The 1941 U.S. embargo on Japanese imports of oil and gasoline products led within six months to Pearl Harbor. Today’s Iranian sanctions are similarly intended to heap more pressure on the regime. U.S. warships patrol the Strait of Hormuz, assuring the flow of oil from Iran’s neighbors. Conflict is not inevitable and is hardly a viable proposition for Iran’s leaders. Economic pressure may yet induce Iranian change in policy, or even regime. That’s clearly our goal. But a miscalculation, or the conclusion that no good options remain, are possible.

Global Chokepoints for Crude Oil

In The Absent Superpower, Peter Zeihan’s book on the shifting gepolitical balance caused by U.S. shale, he notes, “Iran has a phalanx of varied missile systems that could reach any point within the strait itself, with many of them capable of reaching the Saudi shoreline even across the wider points of the Persian Gulf.”

Militarily there’s no doubt about the winner, but oil supplies could still be disrupted. A third of global seaborne crude passes through the Strait of Hormuz. In addition, Qatari exports of Liquified Natural Gas (LNG) account for a third of global LNG trade, with Kuwait importing LNG that travels north through the Strait.

Strait of Hormuz

Brent crude exhibits modest backwardation, of around $4 per barrel between June ’19 and June ’20 futures. Conflict with Iran would surely provoke a much bigger jump.

Energy has sunk to around 5% of the S&P500. It’s one of the few sectors (along with Defense) likely to perform well if U.S. military action occurs. Energy stocks, like crude oil, reflect little price premium for geopolitical uncertainty. Through last year pipeline stocks were sufficiently out of favor that their correlation with the S&P500 was sometimes negative. That’s just the relationship a hedge needs with its target portfolio.

Investors who are concerned about increasing geopolitical risks should overweight midstream energy infrastructure. It’s cheap, immune to war damage and provides good protection against Middle East conflict.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

AMLP’s Shrinking Investor Base

The Alerian MLP ETF (AMLP) remains the largest ETF in the sector, in spite of its ruinous tax drag (see MLP Funds Made for Uncle Sam) and long term returns that are less than half of its index. It’s been a commercial success for its promoters but unfortunately, a disastrous investment for many holders.

However, there are signs that AMLP’s fan base is slipping. Its share count’s steady growth abruptly stopped last summer. Since then, shares outstanding are down over 8%. Half of that drop has come this year.

AMLP Share Count

Midstream energy infrastructure has been a frustrating sector to be sure, and to some degree AMLP flows reflect broader investor sentiment. Through 2014 assets grew, and even during the 2014-16 energy collapse AMLP’s share count increased.

But since last summer, there’s increasing evidence of lost market share. Figures from JPMorgan show AMLP experienced 2H18 outflows of $942MM, a disproportionate share of the sector’s $2.9BN outflows during that period.

Market direction doesn’t seem to make much difference. Last year’s outflows coincided with sector weakness, but outflows have continued this year even though midstream energy infrastructure has been a leading market performer. AMLP’s 2019 outflows have roughly cancelled out inflows to other funds.

Back in 2010 when AMLP was launched, there was clearly investor demand for MLP exposure that avoided K-1s. The corporate tax drag meant AMLP, an index fund, could never come close to matching its index. Buyers overlooked or were unaware of this weakness.

Much has changed over the years. MLPs used to be synonymous with pipelines, but the limited investor base has led many large companies to convert to corporations. Today, North American midstream energy infrastructure is two thirds corporations by market cap (see Pipelines’ New Look).

The MLP structure remains tax-efficient, but its income-seeking investor base has proven to be a fickle source of equity capital. So those MLPs that remain, such as Enterprise Products Partners (EPD), do so because they don’t need to issue equity. There were no MLP IPOs in 2018. Blackstone recently announced plans to convert from a partnership to a corporation, concluding that the K-1s were not worth the trouble.

The shrinking pool of MLPs reflects this change (see Are MLPs Going Away?). AMLP’s 100% MLP exposure omits many of the biggest pipeline corporations.

AMLP also holds an ignominious position on the Top Ten “Money Burned” ETFs posted on Twitter recently. The sector’s poor performance has a lot to do with this, but the corporate tax drag on top of poor results was enough to gain AMLP entry to the list.

The steady erosion of AMLP’s investor base suggests that investors are starting to acknowledge the ruinous tax drag and the switch away from MLPs to corporations.

Since AMLP holders are deciding to exit, it suggests that MLP prices will continue to experience downward pressure relative to corporations, a trend that has been well established this year. The sector is cheap, but broad energy infrastructure exposure that includes corporations will continue to deliver better results than a narrow, MLP-only approach. AMLP owners should sell, probably taking a tax loss, and move into a more diversified product.

Regular readers will be familiar with our blog posts on the topic, and so now are many investors.

 

We are invested in EPD and short AMLP.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

Chevron Writes Shale’s Next Chapter

In the 1990s U.S. bankers were consolidating. My own career spans several bank mergers. Manufacturers Hanover merged with Chemical Bank in 1992, followed by Chase Manhattan in 1996 and JPMorgan in 2000. Other smaller deals occurred along the way, such as Hambrecht & Quist in 1999, and  Robert Fleming in 2000.

I remember then-CEO of Chemical Bank, Bill Harrison, discussing the inevitable consolidation of the banking industry, and how he had a team that was constantly evaluating the synergies of potential combinations. Relative pricing was an important consideration. Weakness in one bank’s stock could attract others who had already assessed a potential fit. Harrison had a mixed record at mergers until the combination with JPMorgan led to Jamie Dimon eventually running the company. Bill’s final deal left investors in good hands.

Chevron’s (CVX) acquisition of Anadarko (APC) last week reminded me of this. The relative pricing chart that CVX CEO Mike Wirth used in Friday’s call provided a useful insight into how they approached the deal.

Chevron Anadarko Acquisition Relative Pricing

Over the past year, stock prices for the integrated oil companies (IOCs) have outperformed the independent U.S. shale drillers. In terms of CVX’s currency (its stock), APC became cheaper. In effect, the market was pushing for this deal, by steadily improving its attractiveness to CVX. Investors want the world’s biggest companies managing shale oil and gas output.

It wasn’t always this way. In the early days of the Shale Revolution, independent companies like Pioneer Resources (PXD), EOG and others led the way. They had a willingness to experiment with different approaches while the industry sought the most effective techniques to unlock this new resource. Observers felt at the time that IOCs were poorly suited to the type of constant disruptive innovation at which smaller companies can excel.

Recognizing the unconventional thinking required to exploit this unconventional resource, huge companies like Royal Dutch Shell (RDS) created new divisions with considerable autonomy to innovate. It echoed the “skunkworks” popularized by Clayton Christensen in The Innovators Dilemma. His premise was that big companies were too often so invested in their existing products and processes that they were unable to see the threat posed by more nimble innovators. And in the early years of the Shale Revolution, IOCs were generally absent because unconventional plays didn’t fit their conventional thinking.

Frequent failures with their associated learning curve were protected from the centrally-imposed financial discipline that usually prevails. RDS enjoyed sufficient success with this approach that they applied some of the lessons across the company.

The CVX/APC deal highlights how things have changed. IOCs are no longer focused on trying to act like a small company practicing rapid innovation. Instead, they’re applying the scale and efficiencies of a big company to drilling techniques that are now well established. It’s the next stage in the Shale Revolution.

Equity markets accelerated this development, by assigning higher valuations to larger companies versus independents. CVX exploited this in their APC acquisition. It’s likely to spur consideration of other match-ups. Pipeline customers will be increasingly well-capitalized with properly funded, long term production plans. This should only be good news for investors in midstream energy infrastructure.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

Shale Cycles Faster, Boosting Returns

Chevron (CVX) CEO Mike Wirth must have used the term “short-cycle” at least half a dozen times on Friday’s conference call discussing their $33BN acquisition of Anadarko (APC). It’s a feature of the Shale Revolution that’s still unappreciated by investors, even while it’s highly valued by upstream companies. A faster capital cycle boosts returns.

The U.S. Shale Revolution has upended global energy markets, and not only because of cheap, new supply. which is already turning America in to the world’s biggest exporter of hydrocarbons. A decade ago Cheniere (LNG) was building facilities to import natural gas, and energy independence was a pipedream.

Conventional oil and gas projects used to require many $BNs in upfront capital, with a payback over a decade or more. Global GDP growth, production costs and future demand all have to be considered before a final investment decision is made. Climate change and public policy response have added to long term uncertainty for an already cyclical business.

The power of shale extraction is that capital spend is spread out and cash returns come sooner. It costs less than $10MM to drill a well, and in America we drill thousands every year. The high initial production and sharp decline rates return capital invested far more quickly. Output can be hedged because the 2-3 year liquidity of futures aligns with the cashflow cycle of shale far better than with conventional projects. If oil falls, drilling slows. It’s just less risky, which is why investment dollars continue to flow into North America.

CVX isn’t alone in recognizing this. ConocoPhillips (COP) places U.S. unconventional, or tight (as shale is often called) in the upper right of a chart with the best combination of capital flexibility and returns.

Shales Capital Flexibility

This chart from IHS Markit links high capital flexibility with fast initial production.

Tight Oil is Short Cycle

We have often commented on this aspect of growing domestic oil and gas output. See our short video America’s Energy Renaissance: The Short Cycle Advantage of Shale and a piece in Forbes The Short Cycle Advantage Of Shale.

Conventional projects are becoming much smaller. North America, which offers substantial short cycle opportunities, continues to draw investment. The result is that America is gaining share in the world’s energy markets. This is likely to remain the case in almost any scenario, because of shale’s lower risk profile.  Wirth went so far as to highlight that not only is shale among some of the highest return projects in their portfolio, but it’s also among the lowest risk both below and above the ground.

A slide from Enterprise Products Partners’ recent investor day highlights strong growth in Asia over the next couple of decades.

Asia is Driving Hydrocarbon Demand

For pipeline owners, this is enormously positive. North American upstream companies are our customers. The Shale Revolution has plenty of critics who argue that Wall Street continues to provide capital, illogically, to unprofitable activities. And yet well informed investors such as CVX are concluding it’s a very attractive place to be. Last year ExxonMobil (XOM) announced plans to invest $50BN in North America over the next five years. CVX was already planning 900 thousand barrels a day of oil production by 2023 in the Permian before the APC acquisition. XOM expects to produce a million barrels per day there. These companies bring scale and stability, which makes them the most attractive customers possible for midstream energy infrastructure.

This was also positive for Western Midstream Partners (WES), since their business with APC is now likely to grow substantially. In response to a question about its new MLP, Wirth pointed to the Waha basis spread, which is negative, meaning producers are paying to get rid of their natural gas. He noted the importance of offtake and high quality midstream infrastructure, and clarified that WES was a strategic asset for them.

CVX is taking advantage of relative weakness in APC’s stock price compared with their own. Nine months ago they would have had to offer almost twice as big a premium. There were also reports that Occidental Petroleum (OXY) had offered APC $5 per share more, but that CVX’s offer was preferred because it’s regarded as a better partner.

Chevron Anadarko Acquisition Relative Pricing

The bottom line is that the CVX/APC deal is great news for midstream energy infrastructure. CVX’s lower cost of capital and merger synergies can only lead to higher oil and gas production than would otherwise have been the case. Pipeline stocks are poised for a significant rally. Over four years of weakness have led to distributable cash flow yields above 10% that are growing 10-15%. Dividends are rising for the first time since 2014. The sector remains over 30% below its all-time high, even while the S&P500 flirts with a new record. CVX provided further affirmation of the enduring value in U.S. unconventional production.

We are invested in EPD and WES.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

Enlink CEO Talks Strategy

Sharply higher commodity prices shouldn’t be a major source of concern for pipeline investors. But that was the answer Enlink (ENLC) President and CEO Michael Garberding gave to a question we’re often asked – what could go wrong. His reason was that it would induce midstream infrastructure to add excess capacity. “Our industry has shown it knows how to overbuild” was heard more than once during a recent investor dinner hosted by MUFG Securities. This set the tone for the evening’s conversation. Adrianne Griffin, Director of Investor Relations and whom we interviewed last year (see Discussing the Shale Revolution with Enlink Midstream), smoothly guided Mike to expand on issues of most interest.

Enlink Midstream

Promoting the CFO to CEO doesn’t always guarantee a culture of financial discipline. For example, Kinder Morgan’s distribution cuts and taxing simplification, all to support their growth plans, took place while President Kimberly Dang was CFO. But we felt Mike Garberding had a good grasp of the company’s financial profile when he held that role, and hope to see it woven more fully into Enlink’s culture.

Any discussion with energy sector management is likely to cover the spread between cost of capital and project returns, prudent leverage and improved returns to shareholders. This dinner was no exception. ENLC expects their $1.2-1.5BN in growth capex to generate $250MM in annual EBITDA when completed, an attractive 5-6X build multiple if they achieve it.

Last year Devon Energy (DVN) sold their Enlink interest to Global Infrastructure Partners (GIP), and then Enlink consolidated their GP and MLP into a single LLC entity that is taxed as a corporation. Given ENLC’s current valuation and attractive projects, you might think GIP would want to buy the whole company, with the substantial pool of private equity dedicated to infrastructure investments. GIP’s role remains something of a mystery. Garberding noted that they were “very aligned with GIP” and that “they give us huge strategic advantages”. But specifics are few, and one investor asked when the benefits of GIP’s strategic role would become clearer. More detail would be welcome. Mike noted that there had been little opportunity to provide more clarity since last summer’s deal, given the just completed simplification. Hopefully, we’ll learn more in the future.

Another investor asked whether ENLC would sell their Barnett shale assets to a potential acquirer of DVN’s acreage, if the buyer was seeking more vertical integration. This was thought unlikely (though “every asset has a sale price”), and Garberding noted that if the new owner adds one more rig that would double the rig count on a play that requires very little annual capital, albeit with output currently declining 4-5% annually.

Upstream customers seem to be showing more stability – ENLC expects rig counts to be maintained across a wider range of oil and gas prices than in the past, which probably speaks to improving balance sheets across the energy sector. Drillers are showing, “a better capability to live within their cashflows.” It’s why he believes gathering and processing businesses are less risky than sometimes believed.

Vertical integration increases the number of opportunities to earn a fee from a molecule, and ENLC regards that as a critical means of competing with bigger firms such as Plains All American (PAGP) and Enterprise Products Partners (EPD), both of whom offer integrated solutions. Providing shippers with optionality and affording customers a choice of where to direct their output to maximize profits remains a key focus.

Connecting with other networks adds choices, and ENLC does this extensively with Oneok’s (OKE), for whom they are a top five customer.

CFO Eric Batchelder was jokingly referred to as the “C-F-No” as if to emphasize C-suite financial discipline. There was an interesting exchange on the balance between returning cash to shareholders via buyback versus distribution growth. The 9% yield on ENLC’s equity suggests that too few investors are attracted to the stock, and therefore a planned 5% increase in payout is unlikely to entice them. Some investors, including ourselves, would prefer that excess cash be returned through buybacks. Since buybacks reduce the sharecount, there’s the added benefit of raising coverage on the dividend

However, Batchelder noted that opinions varied and a significant number of long-time holders still favor dividend growth. ENLC reports fairly low investor turnover in the past couple of years, and clearly a great many original MLP holders (i.e. older, wealthy Americans) have retained their holdings. We think if ENLC investors fully understood the improving coverage inherent in buybacks, they’d prefer them to an increased payout.

An anonymous Twitter contributor well-versed in the capital mis-steps of the sector ran a hilarious NCAA-style tournament of pipeline stocks, which was still ongoing at the time of our dinner (see MLP Humor — A Target-Rich Environment). Voters determined the result of each match-up, based on which visited the more egregious abuse on investors. This was a brief topic of conversation. ENLC progressed through the first two rounds, and must have been relieved to have been eliminated at the “Sour Sixteen” stage.

ENLC is an overweight long position across our portfolios. It’s cheap, with good growth prospects and we like the management. Dinner reaffirmed our conviction.

We are invested in ENLC, EPD, OKE and PAGP.

SL Advisors is the sub-advisor to the Catalyst MLP & Infrastructure Fund.  To learn more about the Fund,  please click here.

SL Advisors is also the advisor to an ETF (USAIETF.com).

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