Oil & Gas Exploration & Production

Pocketing Gains in Oil/Gold Pair Trade Pocketing Gains in Oil/Gold Pair Trade Our reinstated long XOP / short GDX pair trade hit its rolling 10% stop intraday yesterday, forcing us to crystalize 32% gains in just over a month. While our original thesis for this pair trade that was outlined in the April 27th Weekly Report has not changed, we adhere to the risk management tool we put in place and act on our profit-taking stop. We will be looking to reopen this trade later in the summer at a better entry point, especially if as we highlighted on Monday’s Weekly Report the rise in (geo)political risks serve as a catalyst for a much need broad equity market breather. Bottom Line: Crystallize 32% gains in the long XOP / short GDX pair trade, but stay tuned. ​​​​​​​

Oil/Gold Update Oil/Gold Update Our reinstated long S&P oil & gas exploration & production (E&P)/short global gold miners pair trade is up again near the 20% mark. This parabolic rise compels us to re-institute a 10% rolling stop in order to protect gains. Importantly, neither the macro backdrop nor relative profit fundamentals have changed. A rising number of states and countries are setting the groundwork to reopen their economies. This should absorb some of the excess oil supply and help to further steepen the yield curve. Taken together, this will cement the handoff from liquidity to growth and thus further propel the pair trade (see chart). In addition, the Fed’s determination to quash volatility was another reason underpinning this intra-commodity pair trade. The lower the VIX falls, the higher the share price ratio goes. Bottom Line: Institute a 10% rolling stop in the reinstated long S&P oil & E&P/short global gold miners pair trade, today. For a full discussion on the rationale behind the trade, please refer to the following Weekly Report.  

Reinstate The Long S&P E&P/Short Global Gold Miners Trade Reinstate The Long S&P E&P/Short Global Gold Miners Trade Yesterday our 10% rolling stop got triggered on the long S&P oil & gas exploration & production (E&P)/short global gold miners pair trade. We are compelled to reinstate this intra-commodity pair trade, despite the explosive one week return, as neither the macro backdrop nor relative profit fundamentals changed. Importantly, the Fed’s determination to quash volatility is a powerful source of further gains in the relative share price ratio as the oil/gold ratio should regain its footing (volatility shown inverted, bottom panel). In addition, more and more states and a rising number of countries are setting the groundwork to reopen their economies. This should absorb some of the excess oil supply and also push real yields higher, both of which are a boon for relative share prices.  Bottom Line: While we locked in gains of 10% in a mere week on the long S&P E&P/short global gold miners pair trade, we are compelled to reinstate this intra-commodity pair trade. When it hits the 20% return mark anew, it will trigger a 10% rolling stop as a way to protect profits for our portfolio. For additional details please refer to the April 27th Weekly Report.  

Highlights WTI futures contracts delivering into Cushing, Oklahoma, in June could trade or go off the board below $0.00/bbl next month, just as the May contracts did this month, when they changed hands at a low of -$40.32/bbl last week.  Oil storage at this critical hub is approaching its practical limit of 80% full, raising the odds of sub-zero pricing (Chart of the Week). Pricing pressures will accelerate the rate of oil-supply destruction in the US, particularly in the prolific shale-oil basins.  We are revising our estimate of US production losses upward to 1.6mm b/d this year, and to 2.3mm b/d from January 2020 to December 2021. Retail speculation – in the US via ETFs and long-only index exposure, and in China via bank wealth-management products – is compounding WTI price volatility. The CME Group, which operates the NYMEX WTI futures and options markets, will be forced to address storage constraints in Cushing, and will have to better manage retail-spec positioning: These factors increase the probability of negative pricing and exacerbate price volatility as contracts go off the board. Feature The stunning -$40.32/bbl print for May 2020 WTI futures last week marks the first time this global oil benchmark has traded below $0.00/bbl. Negative prices are nothing new to non-storable commodities. In electricity markets, for example, wholesale prices go negative to force generation offline to balance supply and demand so that markets clear.1 Negative pricing also is seen in natural gas markets. It is occurring in the Permian basin with greater frequency, due to insufficient pipeline take-away capacity for all of the associated gas being produced there as oil output in the basin soars. This leaves no alternative to producers but to either shut in oil production or flare the associated gas. Indeed, forward natgas prices at the Waha Hub in Pecos County, Texas, recently have traded below zero for prolonged periods, owing to the surge in Permian oil production (Chart 2).2 Chart of the WeekCushing Approaches Crude Storage Limit Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Chart 2Lack Of Storage Pushes Natgas Prices Below Zero Lack Of Storage Pushes Natgas Prices Below Zero Lack Of Storage Pushes Natgas Prices Below Zero   Markets once again were reminded WTI futures are far more than electronic blips on computer screens: They are binding legal contracts to physically deliver light-sweet West Texas Intermediate (WTI) crude oil into the Cushing, Oklahoma, pipeline and storage hub. The stunning -$40.32/bbl print for May 2020 WTI futures last week marks the first time this global oil benchmark has traded below $0.00/bbl since the 1983 introduction of the NYMEX crude oil futures (Chart 3). Markets once again were reminded WTI futures are far more than electronic blips on computer screens: They are binding legal contracts to physically deliver light-sweet West Texas Intermediate (WTI) crude oil into the Cushing, Oklahoma, pipeline and storage hub. Going off the board long requires contract holders to take delivery into a pipeline or storage facility; going off short requires contract holders to make delivery. Chart 3WTI June Futures Could Go Below $0.00/bbl WTI June Futures Could Go Below $0.00/bbl WTI June Futures Could Go Below $0.00/bbl Owing to structural flaws in the delivery mechanism for WTI futures, and what appears to be a lapse in monitoring positions in the spot-month contract as May 2020 WTI was going off the board last week, the likelihood June 2020 WTI contracts pricing below $0.00/bbl is high. These flaws must be addressed by the CME Group’s NYMEX division and federal regulators, given the WTI futures contract’s importance to the global physical market and the capital at risk. Implications Of Negative WTI Prices Storage at Cushing is, for all intents and purposes, full. Cushing accounts for ~ 15% of the total 653mm barrels of US crude oil storage, which was only at 60% of capacity in mid-April, based on the US EIA’s reckoning. However, Cushing is the delivery point of the physically settled WTI futures contracts traded on the NYMEX. With close to 80% of capacity filled – ~ 58mm barrels of the total capacity of ~ 76mm barrels – the operational limit of storage has been reached at Cushing. This is amply seen in the June-vs-July intermonth spread between futures, which, earlier this week, settled at more than $5/bbl – i.e., more than 10x the then-elevated 50 cents/bbl/month being charged to store oil in Cushing in March (Chart 4). Intermonth spreads are used as proxies for the cost of storage for physically delivered contract that actually can be stored, like oil. If physical surpluses cannot be moved out of regions where storage is full – and pipelines also are full – prices are forced lower and lower until enough production is shut in to allow storage to drain and inventories to return to normal levels. This is happening now in Oklahoma and the prolific Texas shale basins, and other shale basins in the US where horizontal rigs are being laid down and drilling crews are being laid off (Chart 5). Chart 4Intermonth-Spread Blow Out Indicates Full Cushing Storage Intermonth-Spread Blow Out Indicates Full Cushing Storage Intermonth-Spread Blow Out Indicates Full Cushing Storage Chart 5Texas Horizontal Rig Counts Collapse Texas Horizontal Rig Counts Collapse Texas Horizontal Rig Counts Collapse We are revising our estimate of US production losses upward for this year, and to 2.3mm b/d from January 2020 to December 2021. In our most recent modeling of US shale-oil production, we expect these pricing pressures to accelerate the rate of oil-supply destruction, particularly in the prolific shale-oil basins. In fact, we are revising our estimate of US production losses upward for this year, and to 2.3mm b/d from January 2020 to December 2021 (Chart 6). Depending on how long WTI prices stay depressed in the key producing basins, this supply destruction could be even more pronounced. The same is true of global storage: Kpler, the oil-storage tracker, last week estimated global onshore inventories were 85% full.3 Until sufficient supply destruction occurs to offset the COVID-19-induced demand destruction, inventories cannot draw. Floating storage also is surging, as the crude and product forward curves fall deeper into contango, and incentivize holding stocks on the water (Chart 7). Chart 6Lower Prices Will Push US Oil Output Lower Lower Prices Will Push US Oil Output Lower Lower Prices Will Push US Oil Output Lower Chart 7Floating Storage Volumes Surge Floating Storage Volumes Surge Floating Storage Volumes Surge Price will go low enough – negative if needs be – to clear surplus supply to rebalance markets. Storage acts as a shock absorber for physical commodities like crude oil – when there is more supply than demand, the physical surplus is moved to storage until it is needed, and vice versa when there is a physical deficit. When inventories fill in Cushing – arguably the most important crude-oil delivery hub in the world, given WTI is the most liquid crude oil futures contract in the world – it is as if there is no storage at all there. At this point, market for WTI behaves a lot like electricity, which cannot be stored (at least at utility scale), or natgas at Waha, where storage and pipeline takeaway capacity are in very short supply. In such circumstances, price will go low enough – negative if needs be – to clear surplus supply to rebalance markets. This appears to be what spooked markets last week when WTI futures for May delivery traded as low as -$40.32/bbl. Retail Specs Push WTI Volatility Higher Speculators perform a vital and necessary function in futures markets – they willingly accept risk hedgers want to shed. Natural longs – i.e., producers – do not want to sell when prices are low, which is when natural shorts want to buy. Likewise, natural shorts – i.e., consumers – don’t want to buy when prices are high, which is when natural longs want to sell. Speculators provide the liquidity that allows producers and consumers to hedge. When prices are relatively high, they can provide a bid to oil producers looking to hedge production – they may be short-term traders or have a view prices are going higher, or they may be getting out of short positions they put on earlier. When prices are low, speculators provide offers – selling futures because they are short-term traders, or have a view prices are going lower, or they are getting out of long positions. Speculators trade on information and typically never stand for delivery of futures like WTI, which means they typically are out of prompt-month contracts before they are getting ready to go off the board. At that point, only physical-market participants – producers, consumers and physical traders – are left in the market balancing their physical books. When speculators find themselves trading WTI futures as they are getting ready to go to delivery, something in their risk-management systems has gone terribly wrong. Not only do they not trade the physical oil, but they don’t know who to call to take them out of their risk. Something also has gone terribly wrong at the regulatory level: At the CME, which, as the operator of the NYMEX oil trading markets, and at the US Commodity Futures Trading Commission (CFTC) in Washington, D.C. The CME is the self-regulatory organization responsible for ensuring its rules are followed and markets trade in an orderly fashion, and, at the federal level, the CFTC exercises oversight and enforces laws and regulations. It appears Bank of China (BOC), the fourth largest bank in China and the world, has found itself holding long positions in WTI futures delivering in May on the last two days of trading last week. These contracts supported wealth-management products – known as “bao” or treasure – the state-owned bank offered its retail clients.4 Other banks in China also offer such products, but it appears BOC was the only one that did not roll out of its delivery exposure in a timely manner.5 The exposure BOC was trying to trade out of was not huge by normal standards, but after settling its open May futures at -$37.63/bbl, BOC clients apparently lost close to $1.3 billion.6 How the CME or the CFTC allowed a commercial bank with no capability to take delivery of WTI in Cushing against a long NYMEX WTI futures contract as it was going off the board is a mystery. Markets will have to wait for a detailed post-mortem to determine what exactly happened, and how. Retail Piles Into WTI Exposure The experience of BOC – and, most likely, the shock of such deeply negative WTI prices realized upon settlement of these contracts – and a change in US regulations on spot-month position limits for futures used by commodity-pool operators prompted a wholesale exodus from spot-month WTI futures – the June 2020-delivery WTI futures that deliver in Cushing – this week. As a result, the commodity-pool operator running the United States Oil Fund (USO) ETF and S&P Dow Jones, which designs and markets long-only commodity index products for investors – e.g., the S&P GSCI index – rolled their June WTI futures into July and later months in an effort to avoid holding length in the June contract out of fear these futures could trade negative.7 USO is geared to retail investors, and inflows are negatively correlated with front-month WTI futures prices – when prices tank retail investors pile into the ETF (Chart 8). This can dramatically increase the number of futures the fund has to buy to provide its product to retail investors. Chart 8Retail Piles Into WTI Futures Exposure Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Markets were exceptionally volatile early in the week as these fire sales were being executed. The $3.6 billion USO ETF, in particular, apparently was ordered to spread its spot-month exposure (June WTI) across the forward curve by the CME over the first three days of this week. This action was taken to keep the USO ETF from exceeding new position-limit levels in the spot-month contract, which go into effect May 1, and state no entity can have more than 25% of total open interest in the WTI spot contract.8 Markets were exceptionally volatile early in the week as these fire sales were being executed. This rolling out of June WTI exposures should reduce – but not eliminate – the selling pressure on front-month WTI futures contracts by providers of retail and institutional commodity exposure as June goes off the board next month. However, if storage at Cushing remains at tank tops, the rolling by these ETFs that source futures liquidity to hedge their exposures could again push spot prices below $0.00/bbl as the June WTI futures go off the board May 19.9 That said, it is difficult to ascertain exactly what exposure retail investors are getting now when they buy the USO ETF – its WTI futures now span contracts into next year, based on news reports. This could prompt investors to jettison positions, setting up another round of fire sales in WTI futures. Markets also will expect a post-mortem explaining how the CME and CFTC allowed this retail-focused fund could exceed position limits in spot-month WTI futures contracts so significantly at any point in time, let alone when Cushing infrastructure is so extraordinarily taxed. WTI Futures Contract Flaws Contribute To Volatility The CME has failed to find a way to ensure those holding futures that are going off the board are bona fide hedgers capable of making and taking delivery, as the BOC experience showed. The CME Group has not acquitted itself well in the termination of May 2020 futures trading. And, as researchers at the Oxford Institute for Energy Studies note, the past couple of weeks have exposed deep flaws in the WTI futures contracts’ physical-delivery mechanisms, which have been persistent.10 The lack of sufficient storage at Cushing to accommodate the volume of trading in WTI futures is not a new problem. In 2009, the Kingdom of Saudi Arabia changed its pricing benchmark for US sales to the Argus Sour Crude Index for its crudes sold into the US Gulf, because the WTI contract detached from fundamentals then owing to infrastructure constraints at Cushing. The CME has failed to find a way to ensure those holding futures that are going off the board are bona fide hedgers capable of making and taking delivery, as the BOC experience showed. In addition, the CME has shown it has no institutionalized automatic delivery procedures that kick in when Cushing storage is full – e.g., making and taking delivery, say, in the US Gulf using a WTI contract loaded for export, as the OIES researchers observe. Lastly, as of April 22, the CME is using an options-pricing model based on the original theory on random walks developed by the great Louis Bachelier in 1900, which assumes prices are normally distributed and can go below zero, vs. its previous methodology using Fischer Black’s commodity option pricing model, which assumes prices are log-normally distributed and have a lower boundary of zero.11 We’ll be exploring this in further research.   Robert P. Ryan Chief Commodity & Energy Strategist rryan@bcaresearch.com     Commodities Round-Up Energy: Overweight Exports from OPEC countries increased by more than 2mm b/d in April – led by Saudi Arabia and UAE – according to Petro-Logistics – a seaborne oil trade analytics company. This is flooding global markets while global demand is expected to drop to its lowest level since 2Q03 this month. Separately, we are revising up our Canadian oil sands shut-in estimates to ~ 800k b/d in 2Q20 from ~ 500k b/d, as US demand for Canadian oil will be hit more severely than we previously anticipated and local storage is filling rapidly. Rystad Energy now expects Canadian capex to fall 41% y/y in 2020. This will have a lasting impact on the industry’s production capacity. Base Metals: Neutral The LMEX rose 3% since the start of April – led by nickel and copper prices moving up by ~ 6%. Base metals – chiefly aluminum and copper – are poised to rebound in 2Q20 if China’s economy continues to improve and is not hit by a second wave of COVID-19 infections. According to BCA’s China Investment Strategy, the country’s fiscal response is now expected to reach 10% of its GDP this year. This will support further upside in base metals prices (Chart 9). Precious Metals: Neutral Despite the record fiscal and monetary stimulus deployed globally, consumer and market-based inflation expectations remain low, as markets focus on the deflationary effects of the COVID-19 shock and the uncertainty about the speed of the recovery (Chart 10). The low realized inflation post-GFC stimulus could influence investors’ expectations down. We see inflation risks as materially higher which will warrant larger protection in a diversified portfolio over the coming year. Inflation expectations will normalize later this year and next, boosting inflation hedges. Nominal bonds’ protection will remain expensive as rates in major DM countries are expected to stay low for a prolonged period. Chart 9 Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Chart 10 Inflation Expectations Remain Low Inflation Expectations Remain Low       Footnotes 1     Please see Bajwa, Maheen and Joseph Cavicchi, “Growing Evidence of Increased Frequency of Negative Electricity Prices in U.S. Wholesale Electricity Markets.” IAEE Energy Forum, 4th Quarter 2017. 2     Please see U.S. Gas Prices Turn Negative at Texas Waha Hub published by the Pipeline & Gas Journal March 3, 2020. The article notes, “The first swing to negative spot prices in almost seven months occurred due to pipeline constraints and as mild weather cut heating demand. Prices in the forward market have been trading below zero for weeks on expectations there will not be enough pipelines to transport record amounts of gas from the region’s shale oil fields. That gas that comes from oil wells, called associated gas in the industry, helped propel U.S. gas output to record highs, driving prices to their lowest in years as production outpaces demand for the fuel. Analysts expect gas prices in 2020 to fall to their lowest since 1999.” 3    Please see Oil prices sink as world runs low on storage capacity amid frail demand published by reuters.com April 28, 2020. The IEA estimates total onshore storage globally at close to 7 billion barrels, according to the Center for Strategic & International Studies in Washington, D.C. Please see The Oil Inventory Challenge published by the CSIS April 20, 2020, which notes the US has ~ 1.3 billion barrels of storage, while China has an estimated 1.5 billion barrels. Of that ~ 7 billion barrels of nameplate capacity, ~ 80%, or ~ 5.6 billion barrels, represents the operational limit. 4    Please see The world's 100 largest banks published by S&P Global Market Intelligence April 5, 2019. 5    Please see China's ICBC closes commodity-linked products to new investment published by reuters.com April 27, 2020. 6    Please see Bank of China says main investors to settle crude oil product at -$37 published by reuters.com on April 22, 2020. 7     Please see Futures contract moves endangering WTI prices again published by worldoil.com April 28, 2020. 8    Please see USO ETF pushes oil futures exposure out to June 2021 published by etfstrategy.com April 27, 2020. Earlier this month, the USO ETF has accounted for close to 30% of June WTI futures. Please see Biggest Oil ETF Shakes Up Structure published by etf.com April 17, 2020. 9    The USO ETF is not the only fund sourcing futures liquidity to provide retail exposure to WTI, but it is by far the largest. Please see Oil ETF roils already volatile crude markets published April 27, 2020, by investmentnews.com. 10   Please see Oil Benchmarks Under Stress published by OIES April 28, 2020. 11    Please see Davis, Mark, and Alison Etheridge. Louis Bachelier's Theory of Speculation: The Origins of Modern Finance. Princeton University Press, 2006; and Black, Fischer, “The Pricing of Commodity Contracts,” Journal of Financial Economics, Vol. 3, (1976), pp. 167-79, reprinted with permission in Interrelations Among Futures, Option, and Futures Option Markets (1992), the Board of Trade of the City of Chicago publisher.     Investment Views and Themes Recommendations Strategic Recommendations Tactical Trades Trade Recommendation Performance In 2020 Q1 Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Commodity Prices and Plays Reference Table Trades Closed In 2020 Summary of Closed Trades Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl Stand By For Heavy Rolls: June WTI Could Go Below $0.00/bbl

Highlights Portfolio Strategy We remain comfortable with a 3,000 SPX fair value estimate backed up by our DDM, forward ERP and sensitivity analyses. The path of least resistance remains higher for the SPX on a 9-12 month cyclical time horizon. The oil price collapse is eliciting a massive supply response that should help rebalance the oil markets, and coupled with glimmers of hope on reopening the economy, it should put a floor under oil prices. CB are injecting unprecedented amounts of liquidity in the markets and at some point this will lead to a growth revival which is negative for gold prices. Taken together, and given all-time lows in relative valuations and technicals, we are compelled to go long US oil & gas exploration & production stocks at the expense of global gold miners. We are putting the S&P managed health care index on downgrade alert to reflect the risk that rising unemployment poses to health care enrollment. Falling interest rates also weigh on industry profitability at a time when relative valuations are perky and technicals are overbought. Recent Changes Initiate a long S&P oil & gas exploration & production/short global gold miners pair trade, today. Table 1 Gauging Fair Value Gauging Fair Value Feature Equities marked time last week, despite the passage of a fresh mini fiscal 2.0 package and efforts to restart the economy in parts of the globe. In contrast, news that President Trump may delay reopening the economy along with negative crude oil prices weighed heavily on the S&P 500. Nevertheless, energy equities fared very well, defying the oil market carnage and impressively relative energy share prices have led the SPX trough (Chart 1). We remain constructive on the broad equity market on a cyclical 9-12 month time horizon. Following up from last week’s SPX dividend discount model (DDM) update, we complement our research with two additional ways of approximating the SPX fair value: EPS and multiple sensitivity analysis and a forward equity risk premium (ERP) analysis. While at the nadir the stock market priced in a collapse in EPS close to $104 for the current year (please refer to our analysis here1), in 2021 EPS can return to their long-term trend line near $162. At first sight this spike in EPS seems unrealistic. However, here are two salient points: Chart 1Energy As A Leading Indicator Energy As A Leading Indicator Energy As A Leading Indicator First, hard-hit COVID-19 subsectors are a small fraction of SPX profits and market capitalization. In other words, the S&P 500 is a market cap weighted index and has already filtered out hotels, cruises, restaurants, homebuilders, autos, auto parts, airlines, and even energy as they comprise a small part of the SPX. Second, historical precedents show an explosive year-over-year growth increase in EPS from recessionary troughs. In fact, the steeper the collapse the more violent the rebound. Hence, our recovery EPS estimate is more or less in line with empirical evidence (Chart 2). Chart 2Violently Oscillating EPS Violently Oscillating EPS Violently Oscillating EPS For comparison purposes, the Street is still penciling in EPS near $135 and $170 for 2020 and 2021, respectively. Table 2 shows our sensitivity analysis and an SPX ending value of just above 2,900 using $162 EPS and an 18x forward multiple as our base case. This multiple is slightly below the historical time trend using IBES data dating back to 1979, and represents our fair value PE estimate (please see page 17 of our April 6, 2020 webcast2 available here). Table 2SPX EPS & Multiple Sensitivity Gauging Fair Value Gauging Fair Value With regard to the forward ERP analysis, our starting point is an equilibrium ERP of 440 basis points (bps). The way we derived this number was using the last decade’s average observed forward ERP (middle panel, Chart 3). We used to think equilibrium ERP was closer to 200bps. However, if the Fed’s extraordinary – and unorthodox – measures since the onset of the GFC did not manage to bring down the ERP (middle panel, Chart 3), then in the current recession with uncertainty on the rise, it only makes sense to model a higher than previously thought equilibrium ERP (middle panel, Chart 4). Chart 3The Forward Equity Risk Premium… The Forward Equity Risk Premium… The Forward Equity Risk Premium… Chart 4…Will Recede …Will Recede …Will Recede And, just to put the forward ERP in perspective, keep in mind that it jumped from 350bps to just below 600bps year-to-date (Chart 4)! A doubling in the 10-year US treasury yield to 120bps is another assumption we are making along with using our trend EPS estimate of $162 for calendar 2021. Backing out price results in a roughly 2,900 SPX fair value estimate (Table 3). Table 3Forward Equity Risk Premium Analysis Gauging Fair Value Gauging Fair Value We remain comfortable with a 3,000 SPX fair value estimate backed up by our DDM, forward ERP and sensitivity analyses. Despite the much needed current consolidation phase, the path of least resistance is higher for the SPX on a 9-12 month cyclical time horizon. This week we are putting a health care subgroup on downgrade alert and initiating a high-octane intra-commodity market-neutral pair trade to benefit from the looming handoff of liquidity to growth. Time To Buy “Black Gold” At The Expense Of Gold Bullion We have been long and wrong on the S&P energy sector and its subcomponents, as neither we nor our Commodity & Energy Strategists anticipated -$40/bbl WTI crude oil futures prices. Nevertheless, as the energy sector is drifting into oblivion within the SPX – it is now the second smallest GICS1 sector with a 2.77% market cap weight slightly higher than materials – we think that WTI May contract reaching -$40/bbl marked the recessionary trough. Similar to the early-2018 “volmageddon” incident when a volatility exchanged trade product blew up and got dismantled and marked that cyclical peak in the VIX, the recent near collapse of USO and shuttering of another oil related levered exchange traded product serve as the anecdotes that likely mark the low in oil prices. True, negative WTI futures prices are no longer taboo and the CME prepared for them by reprograming its systems to handle negative futures prices, thus they can happen again. With regard to the significance of anecdotes in market tops and bottoms, another interesting one that comes to mind is from our early days at BCA in May of 2008 where we worked for the Global Investment Strategy team as a senior analyst. Back then, we vividly remember a Goldman Sachs analyst slapping a $150/bbl target on crude oil,3 and only days later in unprecedented hubris Gazprom’s CEO upped the ante with an apocalyptic $250/bbl prediction.4 This prompted us to create our first mania chart at BCA with crude oil prices on June 20, 2008 (please see chart 16 from that report available here5), which proved timely as oil prices peaked less than a month later at $147/bbl. Today, we are compelled to perform the opposite exercise and run a regression of previous equity sector market crashes on the S&P oil & gas exploration & production index (E&P, that most closely resembles WTI crude oil prices) in order to gauge a recovery profile. Chart 5 suggests that if the anecdotes are accurate in calling the trough in oil prices, then E&P stocks should enjoy a steep price appreciation trajectory in the coming two years. Beyond the overweights we continue to hold in the S&P energy sector and all the subgroups we cover, we believe that there is an exploitable trading opportunity to go long S&P E&P/short global gold miners (Chart 6). Chart 5Heed The US Equity Strategy’s Crash Index Message Heed The US Equity Strategy’s Crash Index Message Heed The US Equity Strategy’s Crash Index Message This high-octane trade is extremely volatile, but the recent carnage in the oil markets offers a great entry point for investors that can stomach heightened volatility, with an enticing risk/reward tradeoff. The gold/oil ratio (GOR) is trading at 112 as we went to press and we think that it will have to settle down. The Fed is doing its utmost to dampen volatility, and historically, suppressed volatility has been synonymous with a falling GOR (Chart 7). As a result, our pair trade will have to at least climb back to its recent breakdown point, representing a near 34% return (top panel, Chart 6). Chart 6Buy E&P Stocks At The Expense Of Gold Miners Buy E&P Stocks At The Expense Of Gold Miners Buy E&P Stocks At The Expense Of Gold Miners From a macro perspective the time to buy oil equities at the expense of gold miners is when there is a handoff from liquidity to growth (bottom panel, Chart 6). While we are still in the liquidity injection phase we deem the Fed and other Central Banks (CB) are committed to do “whatever it takes” to sustain the proper functioning of the markets. Therefore, at some point likely in the back half of the year when the economy slowly reopens, all these CB programs will bear fruit and growth will recover violently (middle panel, Chart 6), especially given our long-held view that the US will avoid a Great Depression. Chart 7VIX Says Sell The GOR VIX Says Sell The GOR VIX Says Sell The GOR With regard to balancing the oil market, nothing like price to change behavior. In more detail, the recent collapse in oil prices will work like magic to bring some semblance of normality back to the crude oil market, as it will naturally cause a shut in of production; there is no doubt about it. Not only has the supply response commenced, but it is also accelerating to the downside as the plunging rig count depicts (Chart 8). This will lead to some longer-term bullish oil price ramifications. As a reminder, while demand drives prices in the short-term, supply dictates the oil price direction in the long-term. Chart 8Oil Price Collapse Induced Supply Response Oil Price Collapse Induced Supply Response Oil Price Collapse Induced Supply Response Turning over to gold and gold miners, all this liquidity is forcing investors to chase bullion and related equities higher. Tack on that every CB the world over is trying to debase their currency, and factors are falling into place for sustainable flows into gold and gold mining equities. However, there are high odds that all this money sloshing around will eventually generate growth especially in the western hemisphere that is slowly contemplating of restarting its economic engines. As a result, real yields will rise which in turn is negative for gold and gold miners (Chart 9). Finally, relative valuations and technicals could not be more depressed, which is contrarily positive (Chart 10). Chart 9Liquidity To Growth Handoff Beneficiary Liquidity To Growth Handoff Beneficiary Liquidity To Growth Handoff Beneficiary Netting it all out, the oil price collapse is eliciting a massive supply response that should help rebalance the oil markets, and coupled with glimmers of hope on reopening the economy, it should put a floor under oil prices. CB are injecting unprecedented amounts of liquidity in the markets and at some point this will lead to a growth revival which is negative for gold prices. Taken together, and given all-time lows in relative valuations and technicals, we are compelled to go long US oil & gas exploration & production equities at the expense of global gold miners. Chart 10As Bad As It Gets As Bad As It Gets As Bad As It Gets Bottom Line: Initiate a long US oil & gas exploration & production/short global gold miners pair trade today. The ticker symbols for the stocks in these indexes are: BLBG: BLBG: S5OILP – COP, EOG, HES, COG, MRO, NBL, CXO, APA, PXD, DVN, FANG, (or XOP:US exchange traded fund) and GDX:US exchange traded fund, respectively. Put HMOs On Downgrade Alert We upgraded the S&P managed health care index last April, the Monday after Bernie Sanders re-introduced his “Medicare For All” bill.6 Our thesis was that the drubbing in this sector was a massive overreaction and we, along with our Geopolitical Strategists, thought that he would have low chances of clinching the Democratic Presidential candidacy and threatening to render HMOs obsolete. A year later, this thesis has panned out and the S&P managed care index is up 30% versus the S&P 500. Nevertheless we do not want to overstay our welcome and are putting it on our downgrade watch list and instituting a 5% rolling stop in order to protect gains in our portfolio (top panel, Chart 11). Relative share prices have broken out to fresh all-time highs, not only courtesy of a more moderate Democratic Presidential candidate, but also because a significant boost to margins and profits is looming. The delayed effect of fewer elective procedures (i.e. hip and knee replacements and even non-life threatening bypass surgeries) owing to the coronavirus pandemic will result in a sizable, yet temporary, margin expansion phase (second panel, Chart 11). Tack on, still roughly 20% health care insurance CPI and the outlook for HMO margins and profits further improves (bottom panel, Chart 11). Nevertheless, there are some negative offsets. Over the past 5 weeks unemployment insurance claims have soared to 26.5mn, erasing all the employment gains of the past decade, thus private insurance enrollment will take a sizable hit (top panel, Chart 12). Chart 11The Good… The Good… The Good… Chart 12…And The Bad …And The Bad …And The Bad Moreover on the income side, the premia that HMOs take in are typically invested in the risk free asset and given the two month fall from 1.5% to around 0.6% in the 10-year Treasury yield, managed health care earnings will also, at the margin, suffer a setback (bottom panel, Chart 12). True, the HMOs earnings juggernaut has been one of a kind over the past decade underpinning relative share prices (top panel, Chart 13). However, we reckon a lot of the good news and very little if any of the bad news is priced in extremely optimistic relative profit expectation going out five years (middle panel, Chart 13). Keep in mind that the bulk of the M&A activity is behind this industry as the dust has now settled from the previous two year frenzied pace of inter and intra industry combinations (top panel, Chart 14). Chart 13Lots Of Good News Is Already Priced In Lots Of Good News Is Already Priced In Lots Of Good News Is Already Priced In Chart 14Preparing Not To Overstay Our Welcome Preparing Not To Overstay Our Welcome Preparing Not To Overstay Our Welcome Finally, relative technicals are in overbought territory close to one standard deviation above the historical mean and relative valuations are also becoming a tad too lofty for our liking (middle & bottom panel, Chart 14). Adding it all up, we are putting the S&P managed health care index on downgrade alert to reflect the risk that rising unemployment poses to health care enrollment. Falling interest rates also weigh on industry profitability at a time when relative valuations are perky and technicals are overbought. Bottom Line: Stay overweight the S&P managed health care index, but it is now on our downgrade watch list. We are also instituting a rolling 5% stop as a portfolio management tool in order to protect profits. Stay tuned. The ticker symbols for the stocks in this index are: BLBG: S5MANH-UNH, ANTM, HUM, CNC.   Anastasios Avgeriou US Equity Strategist anastasios@bcaresearch.com     Footnotes 1     Please see BCA US Equity Strategy Weekly Report, “What Is Priced In?” dated March 30, 2020, available at uses.bcaresearch.com. 2     https://www.icastpro.ca/events/bca/2020/04/06/us-equity-market-what-the-future-holds/play/16925 3    https://www.nytimes.com/2008/05/21/business/21oil.html 4    https://www.reuters.com/article/gazprom-ceo/russias-gazprom-sees-higher-gas-prices-ceo-idUSL1148506420080611 5    Please see BCA Global Investment Strategy Weekly Report, “Strategy Outlook - PART 1 - Third Quarter 2008” dated June 20, 2008, available at gis.bcaresearch.com. 6    Please see BCA US Equity Strategy Weekly Report, “Show Me The Profits” dated April 15, 2019, available at uses.bcaresearch.com.   Current Recommendations Current Trades Strategic (10-Year) Trade Recommendations Gauging Fair Value Gauging Fair Value Size And Style Views June 3, 2019 Stay neutral cyclicals over defensives (downgrade alert)  January 22, 2018 Favor value over growth May 10, 2018 Favor large over small caps (Stop 10%) June 11, 2018 Long the BCA Millennial basket  The ticker symbols are: (AAPL, AMZN, UBER, HD, LEN, MSFT, NFLX, SPOT, TSLA, V).

The price differential at which Canadian heavy-sour crude trades to the North American benchmark WTI will be pushed to -$20/bbl into 1Q20, as transportation constraints continue to slow the marginal barrel’s egress from Alberta. Increasing demand for low-sulfur distillate fuels as global marine-fuel standards tighten under IMO 2020 regulations next year also will contribute to weaker Canadian crude oil prices. Over the next three to five years, domestic politics will determine whether the Canadian oil industry will be able to attract the investment needed for growth. And that will depend on how uncertainty around pipeline expansion is resolved. Allowing pipeline capacity to expand so that more crude can be shipped south could lead to a significant rebound in Canadian producers’ equity valuations. The industry’s breakeven costs now are on either side of $50/bbl for heavy oil delivered at Cushing, OK. As light-sweet production in the U.S. shales rises, the demand for the relatively scarce, heavier crude likely will pick up, redounding to the benefit of Canadian producers. Highlights Energy: Overweight. Operations at Saudi Aramco’s Abqaiq crude oil processing facility and the Khurais oil field were largely restored by the end of September, in line with management guidance. Capacity in the Kingdom is at 11.3mm b/d, while production is running at 9.9mm b/d. Abqaiq and Khurais were attacked by drone and cruise missiles, an operation the U.S. and Saudi Arabia believe was orchestrated by Iran. On Sunday, Crown Prince Mohammad bin Salman, speaking on CBS News’s 60 Minutes, agreed with U.S. Secretary of State Mike Pompeo’s characterization of the attack as an act of war by Iran, and warned, “If the world does not take a strong and firm action to deter Iran, we will see further escalations that will threaten world interests. Oil supplies will be disrupted and oil prices will jump to unimaginably high numbers that we haven't seen in our lifetimes.” In the interview with Norah O’Donnell, he followed that up with a declaration that the Kingdom prefers “a political and peaceful solution” to resolve its issues with Iran. The crown prince, striking a conciliatory tone, said President Donald Trump and the Kingdom are seeking peace, but that “the Iranians don’t want to sit down at the table.”1 Base Metals: Neutral. China’s steel output rose 9.3% y/y in August to 87.3k MT, according to the World Steel Association (WSA). This was 56% of global output, based on WSA data. Chinese output reached a record 89.1k MT in May. Precious Metals: Neutral. Precious metals' prices collapsed as the broad trade-weighed USD surged earlier this week. Platinum prices were down 5.5% from Friday's close by Tuesday, while gold and silver were down 1.3% and 2%, respectively. Ags/Softs: Underweight. Corn and soybean prices surged earlier in the week in the wake of a bullish USDA stocks report.  December corn was up 5.7%, while beans were up 4.1%.  Feature Canadian heavy oil demand is running strong in Asia, as seen in the surge of exports via the U.S. Gulf over the May-to-mid-September period. By ClipperData’s reckoning, 16mm barrels of Canadian crude were shipped over that period, more than doubling the entire volume shipped to Asia in 2018.2 Canadian demand is being boosted by the collapse of Venezuela’s oil industry, which has removed some 1.5mm b/d of heavy crude from the market since 2016. While Canadian exports into Asia markets are surging, the pick-up in this demand hints at an even greater opportunity if north-to-south pipeline capacity is expanded. Year-to-date exports of Canadian crude to the U.S. are up ~ 2.5% y/y to an average 3.5mm b/d, according to the U.S. EIA. This growth is restrained by slowly expanding export capacity.3 Canadian Oil Takeaway Constraints From 2010 to 2017, Western Canadian oil production grew by an impressive 6.5% p.a., pushing pipeline and storage infrastructure to maximum utilization (Chart of the Week). The development of supporting infrastructure failed to produce the required takeaway capacity, locking bitumen production within the Western Canadian Sedimentary Basin (WCSB). Consequently, Alberta crude oil inventories grew above normal levels and the Western Canadian Select (WCS) discount to Cushing WTI exploded, reaching -$50/bbl in 3Q18. While this incentivized crude-by-rail (CBR) shipments, prices received by Albertan producers fell below $20/bbl, a level significantly below breakeven levels required to sustain investment. Chart of the WeekHeavy Crude Output Surges ... Heavy Crude Output Surges ... Heavy Crude Output Surges ... Facing multiple delays in pipeline developments, then-Premier Rachel Notley announced in December the provincial government would impose mandatory oil production restrictions of ~ 325k b/d starting in January 2019. Moreover, her government secured contracts to lease 4,400 rail cars – ~ 120k b/d by mid-2020 – with Canadian National (CN) and Canadian Pacific (CP) to move crude out of the WCSB. The Alberta government’s intervention rapidly distorted the market’s price mechanism. Initially, the government-mandated production curtailment had the desired impact. The transportation component of the WCS-WTI discount began to narrow, and Alberta’s crude inventory started declining (Chart 2). Chart 2... But Infrastructure Lags ... But Infrastructure Lags ... But Infrastructure Lags However, the Alberta government’s intervention rapidly distorted the market’s price mechanism. To be profitable, moving oil by rail requires a WCS-WTI discount that is somewhere between -$12/bbl to -$22/bbl on top of a quality discount, and possibly higher when additional investments in trains and crews are needed (Chart 3). In January 2019, the transportation discount overshot its equilibrium – narrowing to -$2.90/bbl below the quality component – which weakened crude-by-rail volumes and led to a build in inventories. Chart 3Provincial Government Policy Distorts Market's Heavy-Oil Pricing Dynamics Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen The Great Balancing Act To address these imbalances, the provincial government gradually started easing production curtailments (Chart 4). But this is a work in progress: Ultimately, its goal is to find the right balance between production levels and the WCS-WTI spread – i.e. the necessary price incentive for the market to move further crude by rail (CBR). The following projects still are being advanced by developers. However, no significant additional pipeline takeaway capacity is expected before 2H20 (Chart 5): Chart 4Policy Remains A Work In Progress Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen Chart 5Markets Are Attempting To Redress Takeaway Deficit Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen Enbridge’s Line 3 replacement. This pipeline is part of Enbridge Mainline system. This project will restore the original capacity of the existing Line 3 pipeline to 760k b/d from 390k b/d. The replacement runs from Hardisty, AB, to Superior, WI in the U.S. Since its initial announcement in 2014, the project has faced multiple headwinds, most recently, a delay in permits from the State of Minnesota re the impact of a possible oil spill near Lake Superior. The company continues to expect the project will be completed in 2H20. The Canadian and Wisconsin portions are already completed. TC Energy’s Keystone XL. This is the largest of the proposed projects. It will increase Canadian export capacity to the U.S. by 830k b/d. The project was first proposed in 2008, and will run from Hardisty, AB to Steele City, NE. Recently, Nebraska’s Supreme Court approved the Keystone XL route, lifting one of the last remaining – and probably the most important – legal challenges facing the pipeline construction. This is a positive development for Canadian oil producers. Nonetheless, the project is still facing a federal lawsuit in Montana filed by environmental groups blocking President Trump’s new permit, which gave the project a green light. A hearing is scheduled on October 9, this is a crucial win for TC Energy.4 Reaching a Final Investment Decision (FID) before year-end makes a completion by end-2022 possible. Federally-owned Trans Mountain expansion. The initial application was filed in 2013 and is projected to add 590k b/d of capacity from Edmonton, AB, to Burnaby, B.C. The pipeline was bought for $4.5 billion last year by the Federal government. Earlier this month, a Federal Court of Appeals judge ruled out six of the 12 legal challenges to the expansion, dismissing claims centered on environmental issues. Construction will continue, the government expects the expansion will be operational by mid-2022. Capacity expansion at existing pipelines. We expect some marginal capacity increases at existing pipeline to take place between 3Q19 and 3Q20. Enbridge communicated it could add up to 450k b/d without building new pipelines by 2022. At the moment, we believe ~150k b/d will be gradually added before the end of next year. Additionally, Enbridge mentioned it could boost capacity on its Express line by ~60k b/d before the end of 2020. Lastly, Plains Midstream Canada announced additional capacity on its Rangeland line in both the North and South directions.5 This will assist Canadian producers awaiting for the 2H20 Line 3 replacement. Delays in bringing new takeaway capacity online forced the newly formed Conservative provincial government led by Jason Kenney, which came to power in April 2019, to extend the curtailment program until December 2020. We expect this balancing act to continue over the next 12 months.6 Short- and Medium-term outlook We expect CRB needs to surpass 450k b/d to balance the market In our March 7, 2019 report, we argued the transportation component of the WCS-WTI spread needed to increase by ~ $10/bbl to support incremental crude-by-rail volumes. From March to July, the transportation discount rose by only $4.80/bbl to ~$12/bbl – the floor of our estimated rail price range – and collapsed soon after that. This failed to catalyze sufficient rail volumes to clear the market overhang. Preliminary estimates of CBR volumes based on CN and CP data shows it was largely flat in August and September (Chart 6). Chart 6Crude-By-Rail Shipments Stall Crude-By-Rail Shipments Stall Crude-By-Rail Shipments Stall As the government continues to relax production curtailments – reaching 100k b/d in October – we continue to believe the transportation discount needs to rise from current levels. Recent movements in the discount, averaging $10.3/bbl since the beginning of the month, support our view, and we expect this to continue until it reaches ~$15/bbl. We expect CRB needs to surpass 450k b/d to balance the market until the Line 3 replacement is completed, somewhere in 2H20 (Chart 7). We also expect the quality discount for WCS crude oil to start rising as IMO 2020 approaches. YTD the quality discount has remained relatively narrow, due to the global shortage of heavy-sour crude supply (Chart 8).7 Starting in January 2020, demand for heavy crude will moderate as shippers adapt to the new marine-fuel regulation, offsetting some of the effect of the limited supply. We project this will add $5/bbl to the WCS-WTI spread. Chart 7Additional CBR Capacity Required Additional CBR Capacity Required Additional CBR Capacity Required Chart 8Heavy-Crude Market Remains Tight Heavy-Crude Market Remains Tight Heavy-Crude Market Remains Tight Combined, the quality and transportation discount should push the WCS-WTI spread toward -$20/bbl over the next 6 months, which will, we believe, hurt Canadian producers’ cash flows. We expect WCSB supply will remain flat y/y in 2019. Next year, output is expected to grow 4%, and in 2021 by another 1.2% y/y. Long-term Production Outlook Investment in the Canadian oil sector never truly recovered from the 2014 global oil price collapse, despite the pickup in oil prices (Chart 9). Canada’s total capex ex-oil and -gas has been increasing since 2016, pushing down the share of capex from oil and gas extraction to 14% from 27% in 2014 (Chart 10). This is showing up in our longer-term production forecast: We expect WCSB production will average 5.1mm b/d in 2022 vs. 5.3mm b/d being forecast by the Canadian Association of Petroleum Producers (CAPP). The finite pool of funding available to the Canadian oil and gas sector is competing with U.S. shale development. A favorable regulatory and tax environment, shorter investment cycles and faster initial returns attract most of the funds allocated to oil and gas development to the U.S. at the expense of Canada (Chart 11).8 Most recently, the divergence in investment flows centers on market access Chart 9Canadian Oil Investment Lags Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen Chart 10Canada's Oil & Gas Sector Losing Weight Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen Chart 11U.S. Perceived As Favorable Investment Alternative Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen Foreign companies are exiting the Canadian oil patch, divesting more than $30 billion since 2017.9 The government’s intervention to curtail production led firms to postpone new projects in Alberta. The rig count in Canada remains weak and shows no sign of picking up (Chart 12).10 Nonetheless, the sector should offer an opportunity for investors in the coming years. Once uncertainty around pipeline completion is resolved, we believe there could be a significant rebound in Canadian producers’ equity performance (Chart 13). Technology improvement has reduced oil-sands’ breakeven costs to somewhere between $45/bbl-$55/bbl for oil delivered at Cushing.11 Moreover, the low decline rates of oil-sands supply makes it a more stable and predictable source of supply compared to shale production. Chart 12Capex Reductions Reduce Rig Counts Capex Reductions Reduce Rig Counts Capex Reductions Reduce Rig Counts Chart 13Energy Stock Prices Could Rebound Energy Stock Prices Could Rebound Energy Stock Prices Could Rebound The upcoming new pipeline capacity allowing more Canadian heavy crude oil to be delivered to the complex U.S. Gulf Coast refineries will revive sentiment towards Canadian oil sand projects. Canada is judiciously positioned to be the clear winner of the market-share war fought by heavy oil-producing countries to secure capacity at U.S. Gulf refineries. Canadian oil is already dominating PADD 2 imports, and has been increasing its share of PADD 3 imports (Chart 14). The above-mentioned shortage of heavy crude oil presents an excellent opportunity for Canada to capture additional space at PADD 3 refineries. The collapse of Venezuela and the recent attacks on critical oil infrastructure in the Kingdom of Saudi Arabia (KSA) highlight the attractiveness of Canadian heavy crude to U.S. refiners. Chart 14Strong U.S. Demand For Canada's Oil Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen Impact Of The Upcoming Canadian Federal Election Canada is gearing up for a federal election on October 21. The consensus holds that the Liberal Party of Prime Minister Justin Trudeau will remain in power with a minority government, or possibly in a coalition with the left-wing New Democratic Party (NDP) and/or the Green Party. Our Geopolitical Strategists think the chances of Trudeau maintaining a single-party majority are much higher than consensus (which is about 25%), given that he is running on the back of a fairly strong economy, a renegotiated trade deal with the United States, and a stable socio-political environment (Chart 15). Chart 15Canadian Political Risk Is Muted And Should Stay That Way Canadian Political Risk Is Muted And Should Stay That Way Canadian Political Risk Is Muted And Should Stay That Way While Trudeau’s popularity has waned, his approval rating still puts him in the higher range of Canadian prime ministers and he does not face a charismatic challenger. He has a firm base in both of the traditional bastions of political power, Ontario and Quebec, and seat projections show the Liberals leading in both provinces. The small parties are not polling well; the NDP is faring poorly in Quebec and unlikely to steal many Liberal votes. There could still be surprises but it is telling that the Liberals remain in the lead despite the scandals and last minute controversies threatening them. The Canadian election should produce a status quo result that does not change the energy sector outlook. For the energy sector, the most positive outcome is a Conservative majority; otherwise a renewed Liberal majority is the status quo and hence least negative outcome. Trudeau is criticized by the Conservatives and in Alberta for compromising Canada’s energy interests, yet his support of the Trans-Mountain pipeline has him at odds with the left-wing parties. The worst scenario for the energy sector is if Trudeau is forced to rely on these parties in parliament – and this is a real possibility though not our base case. Bottom Line: The Canadian election should produce a status quo result that does not change the energy sector outlook – however, it holds a non-trivial risk of forcing the Liberals into a coalition with left-wing parties whose stances are market-negative for the energy industry. If this outcome is avoided, expect the market to celebrate in the short term, although the long-term effects of a second Trudeau term are not positive on the energy front.   Hugo Bélanger, Senior Analyst Commodity & Energy Strategy HugoB@bcaresearch.com     Footnotes 1      Please see Mohammad bin Salman denies ordering Khashoggi murder, but says he takes responsibility for it, which aired Sunday September 29, 2019, on CBS News. In a related development last week, Saudi Arabia announced a limited ceasefire with the Iranian-backed Houthi Movement in Yemen, with which it has been engaged in a war since 2015; please see Saudi Arabia agrees to limited ceasefire in Yemen, published by Arabian Business September 28, 2019. 2      Please see Canada's heavy oil exports to Asia from U.S. surge: data, traders published September 27, 2019, by reuters.com. 3      Enbridge Inc.’s 100k b/d pipeline expansion scheduled to be operational by December will marginally increase Canadian shipments south Enbridge us the dominant oil pipeline operator in western Canada. It is attempting to get shippers to sign long-term contracts – vs. existing monthly contracts – during its current auction for pipeline space. Its regulator has “has concerns regarding the fairness of Enbridge’s open season process and the perception of abuse of Enbridge’s market power.” Please see Canada regulator orders Enbridge to halt pipeline overhaul plan due to 'perception of abuse' published by reuters.com September 27, 2019. 4      Please see Court affirms alternative Keystone XL oil pipeline route through Nebraska, published August 23, 2019, by reuters.com. 5      Please see “Canadian Oil Sands Supply Costs and Developments Projects (2019-2039),” published by the Canadian Energy Research Institute (CERI), July 2019. 6      The new government made additional small changes to the previous policy. For instance, it will give producers 2 months’ notice of any changes to the limits, increased the base limit to 20k b/d from 10k b/d and allows the energy minister to use discretion to set production limits after M&A. Please see the oil production limit section of the government of Alberta’s website. 7           As discussed in our March 2019 report, our expectation of high compliance to the output cuts agreed by OPEC 2.0 countries, which primarily export heavy-sour crudes; larger-than-expected Venezuelan output declines in heavy-sour output; and sanctions on Iranian oil exports volume limits the supply of heavy crude available to consumers. 8              In June 2019, the Canadian government passed Bill C-69, called “The modernization of the National Energy Board and Canadian Environmental Assessment Agency.” This law changes the federal environmental assessment process. Critics argued this would repel energy investors and limit pipeline projects approval. Additionally, Canada’s Senate passed Bill C-48 – which aims to ban large oil tankers from waters off the north of B.C.’s coast. This law makes it harder for Alberta to ship its oil via northern B.C. export facilities. Companies are now testing shipment of semi-solid bitumen rather than in liquid form to avoid complying with the new legislation. Please see Oilsands crude sails from B.C., sidestepping federal ban, published by the Edmonton Journal on September 26, 2019. 9           Please see The $30-billion exodus: Foreign oil firms keep bailing on Canada's energy sector published by the Financial Post on August 22, 2019. 10             Rig count does not fully capture Canadian oil production. Bitumen production from mining represent ~30% of total production. However, we believe rig count remains a good proxy of capex in the sector. 11             Please see “Canadian Oil Sands Supply Costs and Developments Projects (2019-2039),” published by the Canadian Energy Research Institute (CERI), July 2019. Investment Views and Themes Recommendations Strategic Recommendations Tactical Trades TRADE RECOMMENDATION PERFORMANCE IN 2019 Q3 Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen Commodity Prices and Plays Reference Table Trades Closed in 2019 Summary of Closed Trades Canadian Crude Oil Differentials Likely Widen Canadian Crude Oil Differentials Likely Widen

Overweight Crude Oil And E&P Are Joined At The Hip Crude Oil And E&P Are Joined At The Hip S&P oil & gas exploration & production (E&P) stocks have closely tracked crude oil prices, but recently a wide gap has opened and we reckon that it will likely narrow via a catch up phase in the former (top panel). Even natural gas prices have come out of hibernation and caught a bid of late and similarly suggest that relative share prices are uncharacteristically depressed by steeply deviating from the underlying commodities (second panel). There is so much pessimism ingrained in the E&P space with net EPS revisions sinking to “as bad as it gets” warning that even a modest rise in oil prices can serve as a catalyst to raise the profile of this unloved corner of the deep cyclical universe (bottom panel). Bottom Line: Continue to overweight the S&P oil & gas exploration & production index. Please refer to the following Weekly Report for more details. The ticker symbols for the stocks in this index are: S5OILP – COP, PXD, DVN, HES, APA, MRO, XEC, COG, CXO, EOG, FANG, NBL.

Highlights   Portfolio Strategy Firming relative profit prospects, rising likelihood of an oil price spike and higher geopolitical risk premia, bombed out valuations and extremely oversold technicals all signal that an overweight stance is warranted in the S&P energy sector. Rising oil price and natural gas price inflation, declining industry high yield spreads, higher capital expenditure discipline and compelling relative value all suggest that it pays to be overweight the S&P E&P index. Recent Changes There are no changes to the portfolio this week. Table 1 The Oil Factor The Oil Factor Feature Equities were range bound last week, digesting the aftermath of the drone attacks on Saudi Arabia’s oil facilities and the kneejerk oil price spike, and the Fed’s at the margin hawkish interest rate cut (Chart 1). While the U.S./China trade war news headlines took the back seat, it is disquieting that the largest oil production disruption in recent memory came to the forefront. Crude oil prices spiked and oil volatility skyrocketed as market participants were not pricing in any geopolitical risk premium on crude prices (Chart 1). This is a wake-up call for market participants and there are longer-term ramifications if the previously dormant geopolitical risk premium returns with a vengeance in the oil markets as we expect. Chart 2 shows that historically, an oil price shock is coincident with a U.S. recession. Given that our Commodity & Energy Strategy (CES) service would not rule out another oil price surge in the coming months, a near doubling in oil inflation would likely be the straw that broke the camel’s back and check the final box for recession. Chart 1Mind The Oil Vol Spike Mind The Oil Vol Spike Mind The Oil Vol Spike Chart 2Doubling In Oil Prices Are A Bad Omen For Stocks Doubling In Oil Prices Are A Bad Omen For Stocks Doubling In Oil Prices Are A Bad Omen For Stocks To be precise, since the mid-1970s a 91% year-over-year oil price increase – using end of period monthly data – is synonymous with recession, with no false positives. In order for that prerequisite to be satisfied, WTI crude oil would have to surge to roughly $86/bbl by December (top panel, Chart 2). While this may seem as a tall order, our CES service has started assigning a rising probability to a sizable oil price jump in the coming months. With regard to equities, in all previous five oil price shocks the S&P 500 suffered significant losses, and if history at least rhymes, then the SPX would steeply contract anew (middle panel, Chart 2). While the U.S. economy is not currently in recession, it is fragile enough that an exogenous oil price shock would tilt it in recession. As a reminder, the U.S. benefits from the “good deflation” i.e. lower oil prices and suffers from oil spikes. Chart 3 depicts this inverse correlation. Importantly, re-reading James D. Hamilton’s “Historical Oil Shocks” NBER paper was insightful.1 In this piece Hamilton documents that “All but one of the 11 postwar recessions were associated with an increase in the price of oil, the single exception being the recession of 1960.” Hamilton then argues that “The correlation between oil shocks and economic recessions appears to be too strong to be just a coincidence…This is not to claim that the oil price increases themselves were the sole cause of most postwar recessions. Instead the indicated conclusion is that oil shocks were a contributing factor in at least some postwar recessions (emphasis ours)”. Chart 3GDP And Oil Are Inversely Correlated GDP And Oil Are Inversely Correlated GDP And Oil Are Inversely Correlated  This week, we update a deep cyclical sector and one of its key subcomponents. Table 2Real GDP Growth (Annual Rate) And Contribution Of Autos To The Overall GDP Growth Rate In Five Historical Episodes The Oil Factor The Oil Factor While only the energy sector benefits from the oil price shock, the consumer, and most other sectors of the economy, have to contend with rising energy input costs. Hamilton finally makes a key point on auto production and a link to output: “one of the key responses seen following an increase in oil prices is a decline in automobile spending, particularly the larger vehicles manufactured in the United States”. He shows this relationship in Table 2 that we have replicated.2 Chart 4 also shows a number of different automobile-related economic series, and the current message is grim. It is clear that, were an oil price shock to hit, the motor vehicle-related production destruction would subtract from overall output and raise the probability of recession. Chart 4What’s Up With Autos? What’s Up With Autos? What’s Up With Autos? In sum, geopolitical risk is getting priced into the crude oil markets and were an oil spike to take place near $86/bbl, then this external shock would most likely tilt the economy in recession as has happened in all previous such oil inflation surges since the 1970s. We would refuse the temptation to listen to pundits that, similar to the initial December 2018 yield curve inversion, would declare that “this time is different”. As a result of all this heightened uncertainty, we remain cautious on the prospects of the overall equity market. This week, we update a deep cyclical sector and one of its key subcomponents. Energy’s Time To Shine? The recent drone attacks in Saudi Arabia’s oil processing and production facilities have re-concentrated investors’ minds on reassessing geopolitical risk premia in the crude oil market (top panel, Chart 5). Given the heightened risk of a future oil price spike that BCA’s CES and Geopolitical Strategy services outlined recently, we remain overweight in the S&P energy sector and re-iterate our high-conviction overweight status.   Rising oil prices will also filter through to rising inflation expectations and further boost the allure of the S&P energy sector (middle & bottom panels, Chart 5). This crude oil supply disruption comes at an inopportune time as U.S. crude oil inventories have been depleting recently; this represents another source of support for the relative share price ratio (crude oil supply shown inverted, second panel, Chart 6). Chart 5Energy Catch Up Phase Looms Energy Catch Up Phase Looms Energy Catch Up Phase Looms Chart 6Energy Can Burst Higher Energy Can Burst Higher Energy Can Burst Higher On the demand front, non-OECD demand remains on an upward trajectory since the start of its recovery path in the aftermath of the 2015/2016 manufacturing recession. Importantly, BCA’s Global Leading Economic Indicator diffusion index is accelerating driven by the emerging markets and signals that recent easing monetary policy measures in EM economies will put a lid under EM oil demand (Chart 6). As a result, still depressed relative S&P energy sales expectations should turnaround (third panel, Chart 6). Turning over to the financial statements of this now niche deep cyclical sector, there are no major red flags waving. Net debt-to-EBITDA is near 2x, on a par with the broad nonfinancial sector, and interest coverage is at a respectable 5x (Chart 7). The sector has been more stringent with shareholder friendly activities and the dividend payout ratio has fallen back to the historical mean (not shown). In more detail, the S&P energy sector sports the highest dividend yield compared with the rest of the GICS1 sectors, a full 185bps above the SPX, offering a relatively safe home for yield hungry investors in the era of depressed global interest rates (bottom panel, Chart 7). In fact, the S&P energy sector is so extremely undervalued that all of its 28 constituents combined are now worth as much as one stock, Microsoft. Indeed, our relative Valuation Indicator has plunged and is now roughly two standard deviations below the historical mean, a three decade low (second panel, Chart 8). Chart 7Repaired B/S With The Highest GICS1 Sector Dividend Yield Repaired B/S With The Highest GICS1 Sector Dividend Yield Repaired B/S With The Highest GICS1 Sector Dividend Yield Chart 8Oversold And… Oversold And… Oversold And…   Energy sector technicals are also bombed out, with our relative Technical Indicator in deeply oversold territory. Such depressed levels have marked prior reversals and a violent snap back would not surprise us. Internal energy sector dynamics reveal a similarly extreme picture, with both the percentage of subgroups trading above the 40-week moving average and with a positive 52-week rate of change perched at the zero lower bound (fourth & fifth panels, Chart 8). Sell-side analysts are equally pessimistic, assigning a low probability in energy sector revenues and profits besting the overall market. This is not only a near-term phenomenon, but the sell side has also thrown in the towel on a 5-year time horizon (Chart 9). All of this extreme bearishness overshadowing the S&P energy sector is contrarily positive. One key risk to our overweight stance in the S&P energy sector is the U.S. dollar. Historically, the higher the greenback goes the lower oil prices and energy shares fall. This multi-decade inverse correlation remains intact and were the U.S. dollar to materially increase from current levels, it would heavily weigh on relative share prices (top panel, Chart 8). BCA’s U.S. Equity Strategy’s relative profit growth macro-models have an excellent track record in forecasting relative profit trends as they accurately capture most of the key profit drivers. Currently, the relative EPS models are in a slingshot recovery, which stands in marked contrast to the overly pessimistic sell side analyst community (second panel, Chart 9). Chart 9…Undervalued …Undervalued …Undervalued Netting it all out, firming relative profit prospects, rising likelihood of an oil price spike and higher geopolitical risk premia, bombed out valuations and extremely oversold technicals all signal that an overweight stance is warranted in the S&P energy sector. Bottom Line: Stay overweight the S&P energy sector. This deep cyclical sector also remains on our high-conviction overweight list. Double Down On Exploration & Production Stocks S&P oil & gas exploration & production (E&P) stocks have closely tracked crude oil prices, but recently a wide gap has opened and we reckon that it will likely narrow via a catch up phase in the former (top panel, Chart 10). Even natural gas prices have come out of hibernation and caught a bid of late and similarly suggest that relative share prices are uncharacteristically depressed by steeply deviating from the underlying commodities (second panel, Chart 10). There is so much pessimism ingrained in the E&P space with net EPS revisions sinking to “as bad as it gets” warning that even a modest rise in oil prices can serve as a catalyst to raise the profile of this unloved corner of the deep cyclical universe (bottom panel, Chart 10). While the energy default rate has risen lately, the high yield E&P option adjusted spread is neither surging a la 2015/2016 nor sending a distress signal. If anything, given the recent jump in oil prices and prospects of an oil price surge, independent oil producers’ bond holders should further breathe a sigh of relief (junk spread shown inverted, middle & bottom panels, Chart 11). Chart 10Primed To Follow Oil Prices Higher Primed To Follow Oil Prices Higher Primed To Follow Oil Prices Higher Adding it all up, rising oil price and natural gas price inflation, declining industry high yield spreads, higher capital expenditure discipline and compelling relative value all suggest that it pays to be overweight the S&P E&P index. With regard to operating metrics, free cash flow has more than doubled since the 2016 trough and has now stabilized (second panel, Chart 12). This highly capital intensive industry has gotten forced to live within its means and be more careful with expansion plans financed by rising indebtedness. Use of cash has also come under scrutiny. Capex as a percentage of overall cash flow rose from 35% to over 60% at the recent cyclical peak and has now corrected to 47%, just above the two decade average (Chart 12). Chart 11No Yellow Flags No Yellow Flags No Yellow Flags Chart 12Cash Discipline Should Start To Pay Off Cash Discipline Should Start To Pay Off Cash Discipline Should Start To Pay Off Similar to the broad energy space, E&P stocks are compellingly valued irrespective of the valuation metric chosen. To name a few, the dividend yield differential is at 150bps versus the broad market, relative price-to-sales has corrected from 3x to par, and on an EV/EBITDA basis E&P stocks trade at a 35% discount to the broad market (Chart 13). Nevertheless, there is a risk to our still constructive view of the E&P index. Oil prices have to stay above the $50-$55/bbl range in order for the shale oil space to breakeven and sustain crude oil production at recent all-time high levels. As a reminder, an industry capex collapse is synonymous with oil price plunges and major relative share price drawdowns (Chart 14). Chart 13Bombed Out Valuations Bombed Out Valuations Bombed Out Valuations Chart 14Capex Collapse Is A Big Risk Capex Collapse Is A Big Risk Capex Collapse Is A Big Risk Adding it all up, rising oil price and natural gas price inflation, declining industry high yield spreads, higher capital expenditure discipline and compelling relative value all suggest that it pays to be overweight the S&P E&P index. Bottom Line: Continue to overweight the S&P oil & gas exploration & production index. The ticker symbols for the stocks in this index are: S5OILP – COP, PXD, DVN, HES, APA, MRO, XEC, COG, CXO, EOG, FANG, NBL.   Anastasios Avgeriou, U.S. Equity Strategist anastasios@bcaresearch.com   footnotes 1      https://www.nber.org/papers/w16790 2      Ibid. Current Recommendations Current Trades Size And Style Views Stay neutral cyclicals over defensives   (downgrade alert) Favor value over growth Favor large over small caps (Stop 10%)

Housekeeping Housekeeping Last Thursday we were stopped out from our tactical S&P semi equipment underweight position as it hit our -7% stop loss (bottom panel). We are obeying the stop loss and are returning this index to a neutral weighting as better than expected profits from both ASML and TSMC lifted all chip-related equities. In marked contrast, our long global gold miners/short S&P oil & gas exploration & production trade initiated just last week has gone parabolic, spiking to 17% (top panel). While our thesis has not changed in this high beta tactical pair trade, from a risk management perspective, we are moving our stop loss from -10% to +12% in order to protect profits. Bottom Line: Stick with the counter-cyclical long global gold miners/short S&P oil & gas exploration & production trade via the long GDX:US/short XOP:US exchange traded funds. For additional details on the rationale behind this trade, please refer to last Monday’s Weekly Report.  

Oil price volatility will remain elevated, as markets transition from a pronounced demand slowdown in 1H19, which is apparent in actual consumption data, to stronger growth. We expect global fiscal and monetary accommodation will arrest and reverse this slowdown in 2H19, and spur oil demand growth in 2020. Consistent with BCA’s Geopolitical Strategy, we are not expecting a resolution to the Sino – U.S. trade war that boosts demand; however, we could see a limited deal by 2H20 that partially addresses tariff barriers and boosts trade in the short run.1 In line with the EIA’s and IEA’s weaker 1H19 oil-consumption assessments, we now expect global demand to grow 1.25mm b/d this year, and 1.50mm b/d next year. These expectations are down 100k b/d and 50k b/d, respectively, from our June estimates. Chart of the WeekOPEC 2.0’s Storage Strategy Continues To Drive Production OPEC 2.0's Storage Strategy Continues to Drive Production OPEC 2.0's Storage Strategy Continues to Drive Production Supply – demand factors combine to push our 2019 Brent forecast to $70/bbl from $73/bbl last month. We are holding our 2020 Brent forecast at $75/bbl. On the supply side, we continue to expect OPEC 2.0’s production strategy to be driven by its primary goal – reducing global oil inventories – which means it will maintain production discipline this year and possibly into 1Q20 (Chart of the Week). We also expect capital discipline in the U.S. to restrain shale-oil production. Lastly, news flows around U.S. – Iran tensions continue to oscillate between hopeful resolution and a hardening of positions, which fuels price volatility. At the end of the day, we expect any increase in Iranian exports resulting from an easing of U.S.-GCC-Iran tensions to be accommodated by OPEC 2.0, as it was prior to the re-imposition of U.S. export sanctions.2 These supply – demand factors combine to push our 2019 Brent forecast to $70/bbl from $73/bbl last month. We are holding our 2020 Brent forecast at $75/bbl. We continue to expect WTI to trade $7/bbl below Brent this year, and $5/bbl lower next year (Chart 2). Chart 2Demand Slowdown In 1H19 Pushes Brent Forecast Lower Demand Slowdown In 1H19 Pushes Brent Forecast Lower Demand Slowdown In 1H19 Pushes Brent Forecast Lower Highlights Energy: Overweight. Given our expectation for tighter markets, we are getting long 1Q20 Brent vs. short 1Q21 Brent at tonight’s close, expecting steeper backwardation in the benchmark forward curve as global inventories draw in 2H19. Base Metals: Neutral. At $52.50/MT, Fastmarkets MB’s spot copper TC/RC Asia – Pacific index remains depressed, suggesting smelters will have to continue to discount their services due to tight physical supplies. Expecting tighter markets, we are getting long Dec19 $3.00/lb COMEX call spreads, vs. short Dec19 $3.30/lb COMEX calls at tonight’s close. Precious Metals: Neutral. Gold prices are largely being driven by U.S. real interest rates and the broad trade weighted USD, which we will explore in detail next week in a Special Report written with our colleagues in BCA’s Foreign Exchange Strategy. Given our expectation for Fed accommodation this year, we remain long gold. Ags/Softs: Underweight. The USDA lifted expected ending stocks for corn in its latest WASDE released last week. The department expects supply growth to outstrip use, which will raise stocks 335mm bushels to 2.0 billion. Feature Last week, we had the good fortune to visit U.S. clients in “The Great State,” otherwise known as Texas. It was a fortuitous swing through the Promised Land, because we had the opportunity to gain insight on a wide range of topics impacting commodity markets, particularly oil and gold, which are responding to many of the same factors driving markets for risky assets generally. Demand for industrial commodities in particular should pick up this year and next. More than a few of our discussions centered on global aggregate demand for real and financial assets. Prior to the Osaka G20 meeting last month, it looked like the odds of a global recession were increasing. Markets were contending with tightening financial conditions in the wake of the Fed’s December 2018 rate hike, the fourth such hike last year; escalating Sino - U.S. trade tensions, which were depressing capex and demand for industrial commodities; and slowing growth generally ex U.S. (Chart 3). Positioning as if the Fed was too late in reversing the policies that led to tighter financial conditions in 2H18 and earlier this year, and in a manner consistent with a deepening of the Sino - U.S. trade war was not unreasonable. That said, a client at one of the Lone Star state's larger investment managers observed that the powerful rallies in markets for risky assets following Fed accommodative signaling beginning earlier this year strongly suggest the markets’ verdict — at least for the moment — is the Fed acted in time to arrest the risk of a global recession this year. Chart 3Global Growth Slowdown Likely Drove Policy Responses Global Growth Slowdown Likely Drove Policy Responses Global Growth Slowdown Likely Drove Policy Responses Chart 4BCA's GIA Index Signaling Industrial Commodity Rebound BCA's GIA Index Signaling Industrial Commodity Rebound BCA's GIA Index Signaling Industrial Commodity Rebound Added to this is the fact that the U.S. central bank is being supported by other systematically important central banks (specifically the PBOC, BOJ, and ECB), and that fiscal stimulus is being deployed globally. Against this backdrop, it is difficult to remain bearish re global aggregate demand going forward, which is to say demand for industrial commodities in particular should pick up this year and next. Indeed, this is starting to show up in our Global Industrial Activity (GIA) Index, which is heavily weighted toward EM industrial commodity demand (Chart 4).3 Oil Demand Will Roar Back In 2H19 Our updated 2019 demand estimates align with the EIA’s and IEA’s depressed 1H19 oil-consumption assessments: We now expect global consumption to grow 1.25mm b/d this year, down 100k b/d vs. our previous estimate. Next year, however, we expect demand to be up 1.50mm b/d in the wake of global stimulus, which is only 50k b/d below our June estimate.4 The IEA’s assessment of 1H19 demand weakness is particularly striking. In its latest forecast, the agency noted that in 2Q19, they show a global surplus of 500k b/d (i.e., supply exceeded demand), where previously they expected a 500k b/d deficit. This million-barrel swing – if it is confirmed when data are later revised with more accurate reporting – suggests the global economy did come close to entering recession earlier this year. We are not as bearish as the IEA, but we do incorporate the severity of the trend they highlight in our forecast. We expect 1H19 global demand grew 520k b/d y/y. In 2H19, like the IEA, we expect demand to come roaring back. We expect consumption to grow at a rate of slightly over 2mm b/d, whereas the IEA’s expecting a 1.8mm b/d rate (Table 1). We believe this momentum will be maintained into 1H20, with growth expected to come in at just over 1.8mm b/d, followed by a more subdued 1.35mm b/d growth rate in 2H20.5 Table 1BCA Global Oil Supply - Demand Balances (MMb/d, Base Case Balances) Weak 1H19 Oil Demand Data Fuels Market Uncertainty Weak 1H19 Oil Demand Data Fuels Market Uncertainty It is important to note here that monetary stimulus hits the economy after “long and variable lags,” in the phrasing of Nobel laureate Milton Freidman. Therefore, we will be closely monitoring our demand estimates for signs the coordinated stimulus being deployed by central banks globally actually is translating into higher industrial commodity demand.6 It also is worthwhile pointing out there is a non-trivial risk – i.e., greater than Russian-roulette odds of 1:6 – the Sino – U.S. trade war metastasizes into a global trade war as positions on both sides harden. This could usher in a new Cold War, and see global supply chains broken and reconstituted within trading blocks. The transition to such a realignment of global trade no doubt would be volatile, but, at the end of the day likely would support commodity demand as supply chains are re-built. OPEC 2.0 Remains Sensitive To EM Demand On the supply side, we continue to expect OPEC 2.0’s production strategy to be driven by its primary goal – i.e., reducing global oil inventories. This means the coalition will continue to exercise production restraint: We expect OPEC 2.0 to reduce output by 540k b/d this year per this strategy. In addition to its inventory goals, we believe OPEC 2.0 also does not want to see Brent price go through $85/bbl. This is because many EM states removed fuel subsidies following the oil-price collapse of 2014 – 2016, and the demand-destruction effects of higher prices would be realized in fairly short order above $85/bbl.7 We view this as a binding constraint – prices above the $80 - $85/bbl range will destroy EM demand, which makes them counterproductive for OPEC 2.0. As a result, next year, we expect the producer coalition to gradually raise output by 800k b/d over the January – August 2020 period, to restrain prices below $80/bbl (Chart 5). It is worthwhile mentioning, since it came up repeatedly in conversations during our Texas swing, we do not share the view OPEC 2.0’s production restraint allows U.S. shale producers to increase production and steal market share from OPEC 2.0. This restraint does play a pivotal role in our balances estimates, and is part of the equation propelling prices higher in our modeling. It is a necessary condition for U.S. shale output to grow, but it is not sufficient. U.S. shale oil is filling a market need for light-sweet crude and condensate, and is attracting investment to meet this need. It does compete with light-sweet OPEC production ex Persian Gulf, but investment in these provinces has proven to be difficult to sustain and commit to over the long haul for a variety of reasons, many of which spring from the lack of rule of law, corruption, and hostile operating environments. Shale oil production, in addition to presenting an opportunity to tap into an abundant resource, allows E&Ps to operate in a low-risk political and geological environment, where contracts are enforced by a disinterested judiciary. In terms of its importance, these factors cannot be overestimated. More importantly, the medium and heavier crudes produced and marketed by KSA and Russia are not in direct competition with U.S. shale oil, which means OPEC 2.0’s leadership is not directly fighting for market share with this output. However, there are constraints to shale-oil production, coming mostly from capital markets. We are modeling slower U.S. onshore production growth this year and next, arising from capital constraints on shale-oil producers. Our recent Special Report on the financial performance of E&P companies and the Majors highlighted the importance they attach to prioritizing investors’ interests, which is clearly visible in the financial metrics of these companies.8 Chart 5OPEC 2.0 Will Raise Supply In 2020 To Keep Brent Prices Below /bbl OPEC 2.0 Will Raise Supply In 2020 To Keep Brent Prices Below $85/bbl OPEC 2.0 Will Raise Supply In 2020 To Keep Brent Prices Below $85/bbl Chart 6Capital Discipline Will Reduce U.S. Onshore Output In 2020 Capital Discipline Will Reduce U.S. Onshore Output In 2020 Capital Discipline Will Reduce U.S. Onshore Output In 2020 Consistent with our investor-driven framework for modeling U.S. output, we reduced our expectation for U.S. onshore supply growth by 160k b/d for next year (Chart 6). As a result, we now expect U.S. onshore production to grow by 1.2mm b/d to ~ 10.0mm b/d this year and by 900k b/d to ~ 10.8mm b/d next year – mostly from shales. We expect U.S. offshore production to increase 170k b/d this year and 130k b/d next year, to 1.9mm b/d in 2019 and 2.0mm b/d in 2020. Expect Tighter Balances, Steeper Backwardation The fundamental supply – demand expectations above combine to push our 2019 Brent forecast to $70/bbl from $73/bbl last month. We are holding our 2020 Brent forecast at $75/bbl. We continue to expect WTI to trade $7/bbl below Brent this year, and $5/bbl lower next year (Chart 7). As can be seen in the Chart of the Week, our balances estimates indicate inventory draws will resume this year, which will lead to a steeper backwardation in benchmark crude streams (Chart 8). Given this expectation, we are getting long 1Q20 Brent vs. short 1Q21 Brent at tonight’s close, expecting steeper backwardation in the benchmark forward curve as global inventories draw in 2H19. Bottom Line: Oil price volatility will remain elevated, as markets transition from the profound demand slowdown reported for 1H19 to a higher-growth footing (Chart 9). We expect Brent crude to average $70 and $75/bbl this year and next, with WTI trading $7 and $5/bbl lower, respectively. On the back of our expectation balances will tighten, we are getting long 1Q20 Brent vs. short 1Q21 Brent at tonight’s close. Chart 7Balances Will Tighten In 2H19, Following 1H19 Weakness Balances Will Tighten In 2H19, Following 1H19 Weakness Balances Will Tighten In 2H19, Following 1H19 Weakness Chart 8Backwardations Will Steepen, As Inventories Draw Backwardations Will Steepen, As Inventories Draw Backwardations Will Steepen, As Inventories Draw Chart 9Volatility Will Remain Elevated Volatility Will Remain Elevated Volatility Will Remain Elevated We are not sounding an all-clear on aggregate demand in the wake of the fiscal and monetary stimulus being deployed globally. The odds the Sino – U.S. trade war expands to encompass global markets are not trivial (we make them greater than 1:6 in our estimation), and this could keep demand and demand expectations uncertain for an indefinite period. Evidence of this will be visible in the options markets, which will price to higher implied volatilities for a longer period of time.   Robert P. Ryan, Chief Commodity & Energy Strategist rryan@bcaresearch.com Hugo Bélanger, Senior Analyst Commodity & Energy Strategy HugoB@bcaresearch.com   Footnotes 1      Please see The Polybius Solution published by BCA Research’s Geopolitical Strategy July 5, 2019. It is available at gps.bcaresearch.com. 2      OPEC 2.0 is the producer coalition led by the Kingdom of Saudi Arabia (KSA) and Russia. It was founded in 2016 to manage oil production, so as to reduce global inventory levels, which were bloated by a market-share war launched by the original OPEC cartel in 2014. In the political-economy framework driving our analysis, OPEC 2.0 treats U.S. and Chinese policy as exogenous factors, and maintains sufficient flexibility to respond to whatever these states do. We develop our paradigm for this in The New Political Economy Of Oil, published by BCA Research’s Commodity & Energy Strategy February 21, 2019. It is available at ces.bcaresearch.com. 3      Please see “Oil, Copper Demand Worries Are Overdone,” where we introduce and discuss the GIA index, published February 14, 2019, in BCA Research’s Commodity & Energy Strategy. It is available at ces.bcaresearch.com. 4      The EIA has lowered its growth estimates for oil consumption six consecutive times this year, with the publication of this month’s forecast. This is the third time we’ve lowered our forecast. 5      Global oil demand is extremely difficult to estimate. It is an estimate subject to large revisions, as we discussed last year: From 2010 to 2016, “On average, the EIA has increased net demand (increases in estimated demand in excess of the increase in estimated supply) by about 470,000 b/d, with the lowest retroactive increase of net demand being 260,000 b/d (2012).” Copies of this research are available upon request. 6      Please see The Lag in Effect of Monetary Policy, by Milton Friedman (1961). Journal of Political Economy, University of Chicago Press, vol. 69, pages 447-466. 7      Please see With the Benefit of Hindsight: The Impact of the 2014-16 Oil Price Collapse, published January 13, 2018, by the World Bank for a discussion of subsidy removal by EM states. 8      Please see Shale-Oil E&Ps Turning A Corner?, published June 13, and U.S. Shales, GOM Production Reinforce Our Robust Production Forecasts, published July 11, 2019. These are available at ces.bcaresearch.com. Investment Views and Themes Recommendations Strategic Recommendations Tactical Trades TRADE RECOMMENDATION PERFORMANCE IN 2019 Q2 Image Commodity Prices and Plays Reference Table Trades Closed in 2019 Summary of Closed Trades Image