Energy

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 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 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 Chart 4BCA'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) 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 Chart 6Capital 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 Chart 8Backwardations Will Steepen, As Inventories Draw Chart 9Volatility 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 Commodity Prices and Plays Reference Table Trades Closed in 2019 Summary of Closed Trades

One way to benefit from the global growth soft-patch is to go long global gold miners/short S&P oil & gas E&P stocks on a tactical three-to-six month basis. Since our Monday inception three days ago, this pair trade is already up 9%. The relative moves in the underlying commodities that serve as pricing power proxies are the key drivers of this share price ratio (top panel). Given the massive currency debasement potential that has gripped Central Banks the world over, such a flush liquidity backdrop will boost the allure of the shiny metal more so than crude oil. Meanwhile, global manufacturing PMIs are foreshadowing recession and our diffusion index has plummeted to the lowest level since 2011 (diffusion shown inverted, middle panel). In the U.S. specifically there is a growth-to-liquidity handoff and the ISM manufacturing survey’s new order versus prices paid subcomponents confirms that global gold miners have the upper hand compared with E&P equities (bottom panel). Bottom Line: We initiated a tactical long global gold miners/short S&P oil & gas E&P pair trade on a three-to-six month time horizon with a stop at the -10% mark. The ticker symbols for the stocks in these indexes are: GDX:US and BLBG – S5OILP – COP, EOG, APC, PXD, CXO, FANG, HES, DVN, MRO, NBL, COG, APA, XEC, respectively. Please refer to this Monday’s Weekly Report for additional details.    

Highlights Portfolio Strategy Recession odds continue to tick higher, according to the NY Fed’s probability of recession model, at a time when global growth is waning, U.S. profit growth is contracting and the non-financial ex-tech corporate balance sheet is degrading rapidly. On a cyclical 3-12 month time horizon we remain cautious on the broad equity market. This is U.S. Equity Strategy’s view, which stands in contrast to the more sanguine equity BCA House View. The souring macro backdrop coupled with a firming industry demand outlook signal that more gains are in store for hypermarket stocks. The global growth slowdown, declining real bond yields, missing inflation, rising policy uncertainty and a favorable relative demand backdrop suggest that there is an exploitable tactical trading opportunity in a long global gold miners/short S&P oil & gas E&P pair trade. Recent Changes Upgrade the S&P hypermarkets index to overweight, today. Initiate a long global gold miners/short S&P oil & gas exploration & production (E&P) pair trade, today Table 1 Feature Obsession with the Fed easing continues to trump all else, with the SPX piercing through the 3,000 mark to fresh all-time highs last week. However, it is unrealistic for the Fed to do all the heavy lifting for the equity market as we have argued recently (see Chart 3 from June 24),1 at a time when profit cracks are spreading rapidly. This should be cause for some trepidation. Since the Christmas Eve lows essentially all of the 26% return in equities is explained by valuation expansion. The forward P/E has recovered from 13.5 to nearly 17.2 (Chart 1). There is limited scope for further expansion as four interest rate cuts in the coming 12 months are already priced in lofty valuations. Now profits will have to do the heavy lifting. But on the eve of earnings season, more than half of the S&P 500 GICS1 sectors are forecast to have contracted profits last quarter, and three sectors could not lift revenue versus year ago comps, according to I/B/E/S data. Looking further out, there is a plethora of indicators that we highlighted last week that suggest that a profit recession is looming.2 Our sense is that once the euphoria around the looming Fed easing cycle settles, there will be a massive clash between perception and reality (Chart 2) that will likely propagate as a surge in volatility. Chart 1Multiple Expansion Explains All Of The SPX’s Return Chart 2Unsustainable Divergence This addiction to low rates has come at a great cost to the non-financial corporate sector. As a reminder, this segment of the economy is where the excesses are in the current cycle as we have been highlighting in recent research.3 Using stock market related data for the non-financial ex-tech universe, net debt has increased by 70% to $4.2tn over the past five years, but cash flow has only grown 18% to $1.7tn. As a result, net debt-to-EBITDA has spiked from 1.7 to 2.5, an all-time high (Chart 3). While stocks are at all-time highs (top panel, Chart 3), the debt-saddled non-financials ex-tech universe will likely exert substantial downward pressure to these equities in the coming months (Chart 4). Chart 3Balance Sheet Degrading Chart 4Something’s Got To Give Moving on to the labor market, we recently noticed an interesting behavior between the unemployment rate and wage inflation since the early-1990s recession: a repulsive magnet-type property exists where like magnetic poles repel each other (middle panel, Chart 5). In other words, every time the falling unemployment rate has kissed off accelerating wage growth, a steep reversal ensued at the onset of recession during the previous three cycles. A repeat may be already taking place, as average hourly earnings (AHE) growth has been stuck in the mud since peaking in December 2018. Importantly, the AHE impulse is quickly losing steam and every time the Fed embarks on an aggressive easing cycle it typically marks the end of wage inflation (bottom panel, Chart 5). Chart 5Beware Of Repulsion Chart 6Waiting For Growth Meanwhile, BCA’s global manufacturing PMI diffusion index has cratered to below 40% (middle panel, Chart 6). Neither the G7 nor the EM aggregate PMIs are above the boom/bust line (top panel, Chart 6). Our breakdown of the Leading Economic Indicators into G7 and EM14 also signals that global growth is hard to come by, albeit EMs are showing some early signs of a trough (bottom panel, Chart 6). As the early-May announced increase in Chinese tariffs begin to take a toll, we doubt global growth can have a sustainable recovery for the rest of 2019, despite Chinese credit growth picking up. Now, even Japan and Korea are fighting it out and are erecting barriers to trade, dealing a further blow to these economically hyper-sensitive export-oriented economies. Netting it all out, the odds of recession by mid-2020 continue to tick higher according to the NY Fed’s model (NY Fed’s probability of recession shown inverted, top panel, Chart 5) at a time when global growth is waning, U.S. profit growth is contracting and the non-financial ex-tech corporate balance sheet is degrading rapidly. On a cyclical 3-12 month time horizon we remain cautious on the broad equity market. This is U.S. Equity Strategy’s view, which stands in contrast to the more sanguine equity BCA House View. This week we are upgrading a consumer staples subgroup to overweight and initiating an intra-commodity market neutral trade. Time To Buy The Hype The tide is shifting and we are upgrading the S&P hypermarkets index to an above benchmark allocation. While valuations are stretched, trading at a 50% premium to the overall market on a 12-month forward P/E basis (not shown), our thesis is that these Big Box retailers will grow into their pricey valuations in the coming months.  The macro landscape is aligned perfectly with these defensive retailers. Consumer confidence has been falling all year long and now cracks are spreading to the labor market (confidence shown inverted, top panel, Chart 7). ADP small business payrolls declined for the second month in a row. Similarly, the NFIB survey shows that small business hiring plans are cooling (hiring plans shown inverted, middle panel, Chart 7). As a reminder, 2/3 of all new hiring typically occurs in the small and medium enterprise space. In the residential real estate market, the drop in interest rates that is now in its eighth month has yet to be felt, and house price inflation has ground to a halt. Historically, Costco membership growth has been inversely correlated with house prices (house price inflation shown inverted, bottom panel, Chart 7). Chart 7Deteriorating Macro Backdrop … Chart 8…Is A Boon To Hypermarkets… Chart 8 shows three additional macro variables that signal brighter times ahead for the relative share price ratio. The drubbing in the 10-year U.S. treasury yield reflects a souring macro backdrop, melting inflation and a steep fall in U.S. economic data surprises. The ISM manufacturing index that continues to decelerate and is now closing in on the boom/bust line corroborates the bond market’s grim message. Tack on the Fed’s expected four cuts in the coming 12 months, and factors are falling into place for a durable rally in relative share prices. This disinflationary backdrop along with the Fed’s looming easing interest rate cycle have put a solid bid under gold prices. Hypermarket equities and bullion traditionally move in lockstep, and the current message is to expect more gains in the former (top panel, Chart 9). On the trade front specifically, these Big Box retailers do source consumer goods from China, but up to now these imports have been nearly immune to the U.S./China trade dispute as prices have been deflating (import prices shown inverted, bottom panel, Chart 9). However, this does pose a risk going forward and we will be closely monitoring it for two reasons: First, because downward pressures may intensify on the greenback and second, President Trump may impose additional tariffs, both of which are negative for industry pricing power. Chart 9Profit Margins… Chart 10…Will Likely Expand Meanwhile, industry demand is on the rise and will likely offset the potential trade and U.S. dollar induced margin pressures. Hypermarket retail sales are climbing at a healthy clip outpacing overall retail sales (bottom panel, Chart 10). Already non-discretionary retail sales are outshining discretionary ones, which is a precursor to recession at a time when overall consumer outlays have sunk below 1% (real PCE growth shown inverted, top panel, Chart 10). The implication is that hypermarkets will continue to garner a larger slice of consumer outlays as the going gets tough. In sum, the souring macro backdrop coupled with a firming industry demand outlook signal that more gains are in store for hypermarket stocks. Bottom Line: Boost the S&P hypermarkets index to overweight. The ticker symbols for the stocks in this index are: BLBG – S5HYPC – WMT, COST. Initiate A Long Global Gold Miners/Short S&P Oil & Gas E&P Pair Trade One way to benefit from the global growth soft-patch and looming global liquidity injection is to go long global gold miners/short S&P oil & gas E&P stocks on a tactical three-to-six month basis. While this market neutral and intra-commodity pair trade has already enjoyed an impressive run, there is more upside owing to a favorable macro backdrop. The key determinant of this share price ratio is the relative move in the underlying commodities that serve as pricing power proxies (top panel, Chart 11). Given the massive currency debasement potential that has gripped Central Banks the world over, such a flush liquidity backdrop will boost the allure of the shiny metal more so than crude oil. Global manufacturing PMIs are foreshadowing recession and our diffusion index has plummeted to the lowest level since 2011 (diffusion shown inverted, middle panel, Chart 11). In the U.S. specifically there is a growth-to-liquidity handoff and the ISM manufacturing survey’s new order versus prices paid subcomponents confirms that global gold miners have the upper hand compared with E&P equities (bottom panel, Chart 11). Chart 11Global Soft-Patch… Chart 12…Disinflation… As a result of this growth scare that can easily morph into recession especially if the U.S./China trade war continues into next year, inflation is nowhere to be found. Unit labor costs are slumping (top panel, Chart 12), the NY Fed’s Underlying Inflation Gauge has rolled over decisively (not shown),4 and the GDP deflator is slipping (middle panel, Chart 12).      Parts of the yield curve first inverted in early-December and the 10-year/fed funds rate slope is still inverted, signaling that gold miners will continue to outperform oil producers (yield curve shown on inverted scale, bottom panel, Chart 13). The near 100bps dive in real interest rates since late-December ties everything together and is a boon to bullion (and gold producers) that yields nothing (TIPS yield shown inverted, top panel, Chart 13). Meanwhile, bond volatility has spiked of late and the bottom panel of Chart 14 shows that historically the MOVE index has been joined at the hip with relative share prices. Chart 13…Melting Real Yields And… Chart 14…The Spike In Bond Vol, All Favor Gold Miners Over Oil Producers On the relative demand front, we peer over to China to take a pulse of the marginal moves in these commodity markets. China (and Russia) has been aggressively shifting their currency reserves into gold, and bullion holdings are rising both in volume terms and as a percentage of total FX reserves. In marked contrast, oil demand is feeble and Chinese apparent diesel consumption that is closely correlated with infrastructure and manufacturing activity has tumbled. Taken together, the message is to expect additional gain in relative share prices (middle & bottom panels, Chart 15). Adding it all up, the global growth slowdown, declining real bond yields, missing inflation, rising policy uncertainty and a favorable relative demand backdrop suggest that there is an exploitable tactical trading opportunity in a long global gold miners/short S&P oil & gas E&P pair trade. Bottom Line: Initiate a tactical long global gold miners/short S&P oil & gas E&P pair trade on a three-to-six month time horizon with a stop at the -10% mark. The ticker symbols for the stocks in these indexes are: GDX:US and BLBG – S5OILP – COP, EOG, APC, PXD, CXO, FANG, HES, DVN, MRO, NBL, COG, APA, XEC, respectively. Chart 15Upbeat Relative Demand Backdrop   Anastasios Avgeriou, U.S. Equity Strategist anastasios@bcaresearch.com   Footnotes 1      Please see BCA U.S. Equity Strategy Weekly Report, “Cracks Forming” dated June 24, 2019, available at uses.bcaresearch.com. 2      Please see BCA U.S. Equity Strategy Weekly Report, “Beware Profit Recession” dated July 8, 2019, available at uses.bcaresearch.com. 3      Please see BCA U.S. Equity Strategy Weekly Report, “A Recession Thought Experiment” dated June 10, 2019, available at uses.bcaresearch.com. 4      https://www.newyorkfed.org/research/policy/underlying-inflation-gauge   Current Recommendations Size And Style Views Favor value over growth Favor large over small caps

Special Report

Highlights So What? Saudi Arabia’s geopolitical risks and still-elevated domestic risks reinforce our cyclically constructive view on oil prices. Why? Saudi Arabia is still in a “danger zone” of internal political risk due to the structural transformation of its economy and society. External risks arising from the Iran showdown threaten to cutoff oil production or transportation, adding to the oil risk premium. We expect oil price volatility to persist, but on a cyclical basis we are constructive on prices. We are maintaining our long EM oil producer equities trade versus the EM equity benchmark excluding China. This basket includes Saudi equities, although in the near term these equities face downside risks. Feature The pace of change in Saudi Arabia has been brisk. Women are driving, the IPO of Aramco is in the works, and the next monarch is likely to be a millennial. Changes to the global energy economy have raised the urgency for an economic transformation that will have political and social consequences, forcing a structural transformation. While the results thus far are attractive, the adjustment phase will be rocky. Saudi Arabia’s successful transition depends on its ability to navigate three main threats: Chart 1The Epic Shale Shake-Up Continues The growth of U.S. shale producers and the dilution of Saudi Arabia’s pricing power: Since the emergence of shale technology, Saudi Arabia faces a new reality in oil markets (Chart 1). Even in the current environment of supply disruptions from major producers such as Iran, Venezuela, and Libya, Brent prices have averaged just $66/bbl so far this year, weighed down by the global slowdown, and the macro context of rising U.S. production. Saudi Arabia has had to enlist the support of Russia in the production management agreement (OPEC 2.0) in effort to support oil prices. But continued oil production cuts come at the expense of the coalition’s market share, and crude exports are no longer a dependable source of revenue for Saudi Arabia. Domestic social and political uncertainties: The successful functioning of the political system has been dependent on the government’s ability to support the lifestyles of its citizens, who have grown accustomed to the generosity of their rulers. But economic challenges bring fiscal challenges. Moreover, shifting powers within the state raise the level of uncertainty and risks during the transition phase. Saber-rattling in the region: Heightened tensions with arch-enemy Iran are posing significant risks of instability and armed conflict that could affect oil production and transportation. And as the war in Yemen enters its fifth year, it poses risks to Saudi finances and oil infrastructure – as highlighted by the multiple drone attacks on Saudi oil facilities in May. These structural risks now dominate Saudi Arabia’s policy-making. OPEC 2.0’s decision at the beginning of this month to extend output cuts into 2020 aims to smooth the economic transition by maintaining a floor under oil prices. Meanwhile Crown Prince Mohammad bin Salman’s Vision 2030 is underway – it is a blueprint for a future Saudi Arabia less dependent on oil (Table 1). Table 1Vision 2030 Highlights Saudi leadership will struggle to minimize near term instability without jeopardizing necessary structural change. In addition to an acute phase of tensions with Iran that could lead to destabilizing surprises this year or next, Saudi Arabia’s economy has just bottomed and is not yet out of the woods. Saudi Arabia’s Economy And Global Oil Markets: Adapting To The New Normal The trajectory of Saudi Arabia’s economic performance has improved since the U-turn in its oil-price management. From 2014-16 Riyadh attempted to drive U.S. shale producers out of business by cranking up production and running prices down. Since then it has supported prices through OPEC 2.0’s production cuts (Chart 2). Export earnings have rebounded over the past two years, reversing the current account deficit (Chart 3). Although net inflows from trade in real terms contribute a much smaller share of overall economic output compared to the mid-2000s, the good news is that the trade balance is back in surplus. Chart 2Return To Cartel Tactics Boosted Economy Nevertheless, the external balance remains hostage to oil prices and may weaken anew over a longer time horizon. Chart 3Current Account Balance Has Improved Chart 4Oil Revenues Easing Budget Strain ... For Now Greater government revenues are helping to improve the budget (Chart 4), but it remains in deficit. Moreover, we do not expect Saudi Arabia to flip the budget to a surplus over the coming two years. Despite our Commodity & Energy Strategy team’s expectation of higher oil prices in 2019 and 2020,1 Saudi Arabia will struggle to balance its budget in the coming 18 months (Chart 5). Their average Brent projection of $73-$75/bbl over the next 18 months still falls short of Saudi’s fiscal breakeven oil price. Most importantly, the kingdom’s black gold is no longer a reliable source of income. Weak oil revenues create a “do-or-die” incentive for Saudi policymakers to diversify the economy. As Chart 1 above illustrates, Saudi Arabia is losing global oil influence to U.S. shale producers. While OPEC 2.0 restrains production, the U.S. will continue dominating production growth, with shale output expected to grow ~1.2mm b/d this year and ~1 mm b/d in 2020.2 Saudi Aramco has been the driving force behind the production cuts (Chart 6), yielding more and more of its market share to American producers. The bad news for Saudi Arabia is that shale producers are here to stay. The kingdom is poorly positioned for this loss of control over oil markets (Chart 7) and is being forced to adapt by diversifying its economy at long last. Chart 7A Long Way To Go In Diversifying Exports Little progress has been made on this front, despite the fanfare surrounding the Vision 2030 plan. 70% of government revenues were derived from the oil sector last year, an increase from the 64% share from two years prior, and Saudi Arabia’s dependence on oil trade has actually increased over the past year (Chart 8).3 This week’s announcement of Aramco’s plans to increase output capacity by 550k b/d does not support the diversification strategy. Nevertheless, the Saudis appear to be redoubling their efforts on Aramco’s delayed initial public offering. The IPO is an important aspect of the diversification process. It is also a driver of Saudi oil price management – other things equal, higher prices support the Saudis’ rosy assessments of the company’s total worth. While an excessively ambitious timeline and indecision over where to list the shares have been setbacks to the plan, last weekend’s meeting between King Salman and British finance minister Philip Hammond follows Crown Prince Mohammad bin Salman’s reassertion last month that the IPO would take place in late 2020 or early 2021.4 On the non-oil front, given that Saudi Arabia’s fiscal policy is procyclical, activity in that sector is dependent on the performance of the oil sector. Strong oil sales not only improve liquidity, but also allow for greater government expenditures – both of which stimulate non-oil activity (Chart 9). This means the improvement in the non-oil sector is more a consequence of the rebound in oil revenues than an indication of successful diversification. Chart 8Saudi Reliance On Oil Not Falling Yet Yet the reform vision is not dead. Weak oil revenues may be a blessing in disguise, presenting Saudi policymakers with a “do-or-die” incentive to intensify diversification efforts. Chart 9Non-Oil Activity Still Depends On Oil Sales Bottom Line: By enlisting the support of Russia, Saudi Arabia has managed to maintain a floor beneath oil prices. However, this comes at the expense of falling market share. This leaves authorities with no choice but to diversify the economy – a feat yet to be performed. Domestic Instability Is A Potential Threat Political and social instability in Saudi Arabia is the second derivative of the new normal in global oil markets. So far instability has been limited, but the transition phase is ongoing and the government may not always manage the rapid pace of structural change as effectively as it has over the past two years. Traditionally, Saudi decision-making has comprised the interests of three main social actors: (1) the ruling al Saud family and Saudi elites (2) religious rulers, and (3) Saudi citizens. In the past, the royal family has been able to mitigate social dissent and maintain stability by ensuring that the financial interests of its citizens are satisfied while granting extensive authority to religious groups. The government has transferred profits amassed from oil to Saudi citizens in the form of subsidies for housing, fuel, water, and electricity; public services; and employment opportunities in bloated and inefficient bureaucracies. Going forward, pressure on Riyadh to reduce expenditures and adapt its budget to the changing oil landscape will persist. The authorities will have to continue to shake down elites for funds, or make cuts to these entitlements, or both. Hence policymakers are attempting to walk a thin line between near-term stability and long-term structural change. Several instances of official backtracking show that authorities fear the potential backlash. Following mass discontent in 2017, the Saudi government rolled back most of a series of cuts to public sector wages and benefits that would have led to massive fiscal savings. Instead, the government raised revenue by increasing prices of subsidized goods and services, including fuel, while doling out support to low-income families. The government also introduced a 5% value-added tax in January 2018. Unemployment – especially youth unemployment – is elevated. This is frightening for the authorities. What about the guarantee of cushy government jobs? 45% of employed Saudis work in the public sector. The consequence is an unproductive labor force lacking the skills necessary to succeed in the private sector. Declining oil revenues remove the luxury of supporting a large, unproductive labor force. Chart 10Youth And Woman Unemployment A Structural Constraint Against this backdrop, unemployment – especially youth unemployment – is elevated (Chart 10). This is frightening for the authorities as over half of Saudi citizens are below 30 years of age and the fertility rate is above replacement level implying continued rapid population growth. It will be a challenge to find employment for the rising number of young people. All the while, jobs in the private sector – which will need to take in the growing labor force – are dominated by expatriate workers. Saudi citizens hold only 20% of jobs in the private sector – but this sector makes up 60% of the country’s employment. Fixing these distortions is challenging. Overall, monthly salaries of nationals are more than double those of expatriates (Chart 11). High wage gaps also exist among comparably skilled workers, reducing the incentive to hire nationals. With non-Saudis holding over 75% of the jobs, the incentive to employ low-wage expatriate workers has also weighed on the current account balance through large remittance outflows (Chart 12). And while the share of jobs held by Saudi citizens increased, this is not on the back of an increase in the number of employed Saudis. Rather, while the number of nationals with jobs contracted by nearly 10% in 2018, jobs held by non-Saudis declined at a faster pace. The absolute number of employed Saudis is down 37% since 2015. “Saudization” efforts are aimed at reducing the wage gap – such as a monthly levy per worker on firms where the majority of workers are non-Saudi; wage subsidies for Saudi nationals working in the private sector; and quotas for hiring nationals. But these have mixed results. While Saudi employment has improved, the associated reduced productivity and higher costs have been damaging. Thus, these labor market challenges pose risks to both domestic stability, and the economy. Moreover, even though improved liquidity conditions have softened interbank rates, loans to government and quasi-government entities still outpace loans to the private sector (Chart 13). This “crowding out” effect is not conducive to a private sector revival. It is conducive to central government control, which the leadership is tightening. Chart 12Jobs For Expatriate Workers Have Declined Chart 13Monetary Conditions Ease But Private Credit Lags Facing these structural factors, authorities are attempting to appease the population through social change. There has been a marked relaxation in the ultra-conservative rules governing Saudi society. Permission for women to drive cars has been granted and the first cinemas and music venues opened their doors last year. Critically, religious rulers are seeing their wide-ranging powers curtailed. The hai’a or religious police are now only permitted to work during office hours. They no longer have the authority to detain or make arrests, and may only submit reports to civil authorities. While these changes appeal to the new generation, they also run the risk of provoking a “Wahhabi backlash.” This risk is still alive despite the past two years of policy change. The recently approved “public decency law” – which requires residents to adhere to dress codes and bans taking photos or using phrases deemed offensive – reveals the authorities’ need to mitigate this risk. Popular social reforms are occurring against a backdrop of an unprecedented centralization of power. Mohammad bin Salman will be the first Saudi ruler of his millennial generation. The evolving balance of power between the 15,000 members of the royal family will hurl the kingdom into the unknown. The concentration of power into the Sudairi faction of the ruling family, through events such as the 2017 Ritz Carlton detentions, is still capable of provoking a destabilizing backlash. Discontent among royal family members and Saudi elites may give rise to a new, fourth faction, resentful of the social and political changes. At the moment, the state’s policies have generated some momentum. A number of major hardline religious scholars and clerics have apologized for past extremism and differences over state policy and have endorsed MBS’s vision of a modern Saudi state and “moderate” Islam – the crackdown on radicalism has moved the dial within the religious establishment.5 But structural change is not quick and the social pressures being unleashed are momentous. Saudi Arabia’s oil production and transportation infrastructure are currently in danger from saber-rattling or conflict in the region. The government is guiding the process, but the consensus is correct that internal political risk remains extremely high. There has been a structural increase in that risk, as outlined in this report – and it is best to remain cautious even regarding the cyclical increase in political risk over the past two years. Bottom Line: Saudi Arabia’s new economic reality is ushering in social and political change at an unprecedented pace. Unless the interests of the three main social actors – the royal family, religious elites, and Saudi citizens – are successfully managed, a new faction comprised of disaffected elites may arise. A Dangerous Neighborhood Putting aside the longer term threat from U.S. energy independence, Saudi Arabia’s oil production and transportation infrastructure are currently in danger from saber-rattling or conflict in the region. Saudi officials originally expected the war in Yemen to last only a few weeks, but the conflict is now in its fifth year and still raging. The claim by the Iran-backed Houthi insurgents that a recent drone attack on Saudi oil installations was assisted by supporters in Saudi Arabia’s Eastern province – home to the majority of the country’s 10%-15% Shia population and oil production – is also troubling as it shows that the above domestic risks can readily combine with external, geopolitical risks. The U.S. is also joining Israel and Saudi Arabia in applying increasing pressure on Iran, which risks sparking a war. Our Iran-U.S. Tensions Decision Tree illustrates that the probability of war between the U.S. and Iran – which would involve the Saudis – is as high as 40% (Diagram 1). Diagram 1Iran-U.S. Tensions Decision Tree We are not downgrading this risk in the wake of President Trump’s decision not to conduct strikes on Iranian radars and missile launchers on June 20. President Trump claims he wants negotiations instead of war, but his administration’s pressure tactics have pushed Iran into a corner. The Iranian regime is capable of pushing the limits further (both in terms of its nuclear program as well as regional oil production and transport), which could easily lead to provocations or miscalculation. The Saudi-Iranian rivalry is structurally unstable as a result of Iran’s capitalization on major strategic movements of the past two decades. The Saudis have lost a Sunni-dominated buffer in Iraq, they have lost influence in Syria and Yemen, and their aggressive military efforts to counter these trends have failed.6 The Israelis are equally alarmed by these developments and trying to persuade the Americans to take a much more aggressive posture to contain Iran. As a result, the Trump administration reneged on the 2015 U.S.-Iran nuclear agreement and broader détente – intensifying a cycle of distrust with Iran that will be difficult to reverse even if the Democratic Party takes the White House in 2020. Hence there is a real possibility of attacks on Saudi oil production facilities, domestic pipelines, and tankers in transit in the near term. Moreover, the majority of Saudi Arabia’s exports transit through two major chokepoints making these barrels vulnerable to sabotage: The Strait of Hormuz, which Iran has resumed threatening to block; The Bab-el-Mandeb Strait, located between Yemen and East Africa, which was the site of an attack on two Saudi Aramco tankers last year, forcing a temporarily halt in shipments. Saudi Arabia is acutely aware of these risks. It is the top buyer of U.S. arms and, as a result of the dramatic strategic shifts since the American invasion of Iraq, it is the world’s leading spender on military equipment as a share of GDP (Chart 14). One of our key “Black Swan” risks of the year is that the Saudis may be emboldened by the Trump administration’s writing them a blank check. Bottom Line: In addition to the structural risks associated with Saudi Arabia’s economic, social and political transition, geopolitical tensions in the region are elevated. Warning shots are still being fired by Iran and their proxies (such as the Houthis), and oil supplies are at the mercy of additional escalation. Investment Implications Saudi Arabia’s equity market is halfway through the process of joining the benchmark MSCI EM index. The process will finish on August 29, 2019 with Saudi taking up a total 2.9% weighting in the index. Research by our colleague Ellen JingYuan He at BCA’s Emerging Markets Strategy shows that in the case of the United Arab Emirates, Qatar, and Pakistan, inclusion into MSCI created a “buy the rumor, sell the news” phenomenon and suggested that a top of the market was at hand.7 Saudi equities have recently peaked in absolute terms and relative to the emerging market benchmark, supporting this thesis. Saudi equity volatility has especially spiked relative to the emerging market average, which is appropriate. We expect ongoing bouts of volatility due to the immediate, market-relevant political risks outlined above. The risk of a disruptive conflict stemming from the Saudi-Iran and U.S.-Iran confrontation is significant enough that investors should, at minimum, expect minor conflicts or incidents to disrupt oil markets in the immediate term. We expect oil price volatility to persist. Because Riyadh is maintaining OPEC 2.0 discipline in this environment, oil prices should experience underlying upward pressure. It is not that the Saudis are refusing to support the Trump administration’s maximum pressure against Iran but rather that they are calibrating their support in a way that hedges against the risk that Trump will change his mind, since that risk is quite high. This is the 55% chance of an uneasy status quo in U.S.-Iran relations in Diagram 1, which requires at least secret U.S. relaxation of oil sanction enforcement. Moreover, the Saudis want to reduce the downside risk of weak global growth and support their national interest in pushing Brent prices toward $80/bbl for fiscal and strategic purposes. Our pessimistic assessment of the Osaka G20 tariff truce between the U.S. and China is more than offset by our expectation since February that China’s economic policy has shifted toward stimulus rather than the deleveraging of 2017-18. We assign a 68% probability to additional trade war escalation in Q4 this year or at least before November 2020. But since a dramatic trade war escalation would lead to even greater stimulus, we still share our Commodity & Energy Strategy’s cyclical view that the underlying trend for oil prices is up. We are maintaining our recommendation of being long EM oil producers’ equities relative to EM-ex-China. This trade includes Saudi Arabian equities, but as a whole it has upside in the near-term as Brent prices are below our expected average and Chinese equities are still down 10% from their April highs.   Matt Gertken, Vice President Geopolitical Strategist mattg@bcaresearch.com Footnotes 1 Our Commodity & Energy Strategy team expects Brent prices to average $73/bbl this year and $75/bbl in 2020. For their latest monthly balances assessment, please see “Supply-Demand Balances Consistent With Higher Oil Prices,” dated June 20, 2019, available at ces.bcaresearch.com. 2 Please see BCA Research’s Commodity & Energy Strategy Weekly Report titled “Supply-Demand Balances Consistent With Higher Oil Prices,” dated June 20, 2019, available at ces.bcaresearch.com. 3 The higher export dependence on oil reflects the rebound in oil prices in 2018, rather than a decline in non-oil exports. Given the strong relationship between activity in the oil and non-oil sectors, non-oil exports also increased in 2018. 4 Saudi Aramco’s purchase of a 70 percent stake in SABIC from the Saudi Public Investment Fund (PIF) earlier this year reportedly contributed to the IPO delay. The deal will capitalize the PIF, enabling it to diversify the economy. 5 See, for example, James M. Dorsey, “Clerics and Entertainers Seek to Bolster MBS’s Grip on Power,” BESA Center Perspectives Paper No. 1220, July 7, 2019, available at besacenter.org. 6 The U.S., Saudi Arabia, and their allies are trying to restore Iraq as a geopolitical buffer by cultivating an Iraq that is more independent of Iranian influence – and this is part of rising regional frictions. Iraqi Prime Minister Adel Abdul Mahdi’s recently issued decree to reduce the power of Iraq’s Iran-backed milita, the Popular Mobilization Forces (PMF) and integrate them into Iraq’s armed forces by forcing them to choose between either military or political activity. Just over a year ago, Iraq’s previous Prime Minister Haider al-Abadi issued a decree granting members of the PMF many of the same rights as members of the military. 7 Please see BCA Frontier Markets Strategy, “Pakistani Stocks: A Top Is At Hand,” March 13, 2017, available at fms.bcaresearch.com.

Special Report

Highlights The U.S. oil market has always been dynamic, but, over the past couple of years, profound changes have been occurring at increasingly rapid rates. In Part 1 of this two-part Special Report, we presented our forecasts for U.S. independent E&P companies’ crude oil production.1 We concluded that U.S. producers would increase production by 15% and 10% yoy this year and next, roughly in line with guidance. We argued that this could be done with flat/higher capex this year, and that current guidance for more than a 10% yoy decrease in capex would not allow for the estimated production increase. This week, we publish Part 2 of our Special Report and look at some of the larger changes occurring in the U.S., and assess the big factors we believe could significantly impact the evolution of oil production: The Majors’ increasing presence in the Permian Basin; Rising U.S. Gulf of Mexico (GOM) production; and Bottlenecks at U.S. Gulf Coast export facilities. Feature The world’s largest privately held energy companies – the "Majors" – have committed to the U.S. in a big way – mostly in the Permian Basin in Texas – directing their formidable technology, scale, and, most importantly, strong balance sheets to expanding U.S. production. Guidance from supermajors2 indicates capital expenditures increased by 11.6% in 2018, and will increase by 17.3% in 2019 (Chart of the Week). U.S.-directed capex for the group has been in a steep upward trend since 2016. In 2018, Chevron, Exxon and BP increased their U.S upstream capex by ~ 50% y/y. Additionally, Exxon’s and Chevron’s U.S. upstream capex represented 30% and 36% of each company’s total capex vs. an average 22% and 23%, respectively, over the past 5 years. This is not exclusively related to tight-oil developments in the major shale basins. Nonetheless, it corroborates comments from these companies re the expansion of their activity in the U.S. tight oil market.3 The major oil companies are expected to invest more than $10 billion in the Permian this year, according to IHS Markit.4 The supermajors could add close to 1mm b/d by 2021 and ~ 2mm b/d of production from U.S. shales alone by 2024, most of it in the Permian and at the lower end of the shale production cost curve. Adding this to the guidance from the E&Ps highlighted in Part 1 of our Special Report motivates our positive U.S. crude production outlook. We expect U.S. onshore production will increase by close to 1.3mm b/d in 2019, and ~ 1mm b/d in 2020. Longer term, the presence of these major integrated oil companies in the U.S. shale patch will reduce production’s price-elasticity. This is because, for some of these companies with all-in sustaining costs close to $40/bbl, tight-oil production out of the Permian will become baseload production, which higher-cost producers will be forced to adjust to going forward.5 These major oil producers focus mainly on the medium- to long-term, on sustainable and stable production, and dividend growth versus short-term production in response to higher – and often transient – prices. The latter production strategy – i.e., ramping production as prices rise – can only be sustained by outspending cash flow (Chart 2). Chart 2E&Ps Have Outspent Their Cash flow Since 2011 Moreover, large integrated oil companies can sustain extended periods of low prices from their shale projects, because their focus is on being the lowest-cost producers wherever they operate. This is the strongest risk-management policy an oil producer can pursue, because it minimizes revenue and profit exposure to low and volatile prices. In addition, these firms develop a presence in midstream and downstream operations to diversify revenues, which reduces direct exposure to E&P activity, thus benefiting balance sheets and income statements. Our updated full-cycle breakeven price for our group of independent E&P companies – arguably the marginal light-tight-oil producer – suggests shale production’s average breakeven (excluding land acquisition costs) is around $50.10/bbl.6 Chart 3 illustrates the impact of this new wave of low cost supply – coming from the supermajors’ focus on Permian production – on our estimated full cycle cost breakeven. Assuming a constant breakeven for independent E&P companies, this could significantly lower the average breakeven cost for shale production by 2021. These operating features brought to the shales by the supermajors have important implications for how we model U.S. onshore production. In our current methodology, we estimate the rig count elasticity with respect to variation in oil prices based on the historical relationship between realized prices, the forward curve (its level and slope), and rig counts. Subsequently, we use these rig count estimates – along with our own estimates of production decline rates and productivity per rig by basin – as an input to forecast oil production.7 Rig count is a core input to our U.S. production estimates. It is a straightforward metric entirely driven by the E&Ps’ willingness to increase capex. Thus, the ongoing capital discipline evident in the E&Ps and the Majors, combined with rising production from the supermajors, could affect our estimated rig count elasticity.8 This in turn, would increase the uncertainty of forecasts obtained from models estimated on historical data over the short run, as we – and the market – become accustomed to a less-elastic production profile in the U.S. shales. Over the short term, this will not have a material effect to our 2019 production estimates. As shown in Part 1 of this report, our modeling based on historical rig count price-elasticity is in line with E&P’s production guidance. If we are right that the current capital discipline theme will remain a top priority for independent U.S. E&P companies in the future, this will gradually affect our forecasting methodology starting next year. U.S. Gulf Production Since 3Q18, our modeling of U.S oil production has focused mainly on onshore production ex GOM. We’ve relied largely on the U.S. EIA‘s estimates of GOM production, given that our own assessment did not differ materially from the EIA’s during that period. Going forward, we believe GOM production could surprise to the upside and surpass the EIA’s estimates in the short term. The EIA recently revised down its GOM forecasts for 2020 (Chart 4). Since the 2014 global oil prices collapse, producers in the Gulf have been increasingly leveraging existing infrastructure with short-cycle field developments using subsea tie-backs to boost production at reduced costs. Previously omitted locations – i.e. smaller fields not profitable enough to support the massive investment required for their own infrastructure – can now be tied in to existing infrastructure using subsea flowlines connected to existing platforms that have surplus production-carrying capacity. GOM producers’ business model is evolving to prosper in volatile oil price environments and sustained lower oil prices. The shorter cycle time and lower capex requirements for subsea tie-backs allow for more flexible production at costs that come close to Permian shale plays. Flowlines can reach wells more than 25 miles away from the main platform; this could be extended to reach 30 miles by 2020, allowing for more field to be profitably developed.9 Chart 4EIA GOM Production Forecasts Are Too Low The theme of subsea tie-backs and low-risk development will remain in place going forward, according to IHS Markit.10 Producers are favoring these projects to limit their exposure to oil price fluctuations. BP and Shell signaled they are expanding development at existing GOM fields.11 However, production at most sites will most probably start towards the end of next year, or slightly after our end-2020 forecast horizon. Chart 5Medium Term, Large Scale Investments Are Needed In the medium term, the risk of stagnating GOM production remains elevated due to a lack of large investments and decline rates at newer fields (2014-2017) (Chart 5). Furthermore, as the majors and large E&Ps continue to focus on increasing their free cash flow, the aggressive shift toward onshore-shale projects risks starving the development of large fields in the GOM of much-needed capex. Future expansions in the Permian and GOM could increasingly be competing for funding by major oil companies. In fact, recent cost-reduction measures could allow for the development of greenfield projects at competitive costs. The recent completion of Shell’s giant Appomattox field – one quarter earlier at a cost 40% lower than initially expected – came in with a breakeven cost between $40-50/bbl, something that could signal a bright future for this type of development.12 U.S. Gulf Export Capacity Buildout Combining our production forecasts for independent E&Ps, majors and GOM projections, we expect total U.S. crude oil production to increase by 1.43mm b/d to 12.38mm b/d in 2019 and 1.16mm b/d to 13.55mm b/d in 2020. However, much of the new shale production, which will represent the bulk of the output growth in the U.S., will have to be sold in export markets, given U.S. refiners still run mostly medium and heavy crude oil slates. This is a problem, taking into account the speed at which Gulf Coast export facilities can be expanded. We believe current export facilities will reach full capacity sometime next year (Chart 6). We will be exploring this topic in greater depth next month. Over the short-term, this implies production bottlenecks likely will move from the Permian Basin to the Gulf Coast. U.S. refineries cannot absorb these large volumes of new light sweet oil in such a short period. Hence, the bulk of additional production will have to be exported to foreign buyers. Additionally, Permian production is becoming lighter as the supply of West Texas Light (WTL) increases – recently reaching more than 10% of the basin’s total production.13 Gulf Coast refiners’ crude slate has become lighter and sweeter as shale-oil production has expanded in the U.S (Chart 7). However, this trend cannot continue without large investments in new capacity, especially with the rising domestic supply of ultra-light WTL-type crude. Chart 6U.S. Crude Exports Are Trending Higher Chart 7Gulf Coast Refiners Crude Slate Has Become Lighter In fact, since 2007, the abundant domestic light-sweet supply has mainly been absorbed through (1) the blending of lighter crude with heavier imported crude, (2) the rising utilization rate of atmospheric distillation units, and (3) declining light oil imports, which have fallen from more than 1.6mm b/d in 2009 to 0.36mm b/d – and close to zero at PADD 3 (Gulf Coast) – as of April 2019. These strategies are at or close to their limits (Chart 8). On the other hand, imports of the heavy crude U.S. refiners continue to need remained constant, reflecting refiners’ stable demand for these grades. Chart 8Domestic Absorption Of Light Crude Is Close To Maximum Chart 9Crude Price Spreads Starting To Signal Export Constraints Historically, logistical imbalances have been resolved quickly in the U.S. shale sector. The price mechanism incentivizes investment where it’s needed the most, and we believe this is already happening in the U.S. Gulf with planned deep-water harbor expansions (Chart 9). In the medium-term – i.e., over the next 2 – 5 years – these export-capacity issues will be fixed. In fact, there already are plenty of projects proposed to alleviate the bottlenecks. We estimate up to 12mm b/d of export capacity increase have been proposed so far. This would be a massive overbuild of Gulf export facilities. We estimate ~ 500k b/d of additional export capacity will be needed by end-2020, which implies only one offshore or a few onshore projects would have to be built. By 2023, the U.S. would need new capacity to reach around 5mm b/d (Chart 10).14 Nonetheless, the buildout of U.S. Gulf coast hydrocarbon-export infrastructure could be a bumpy ride. Risks remain, as these large projects require complicated permitting and massive funding which can drastically increase construction time. The LLS-Brent spread will probably be volatile in 2020 until the first project receives its Final Investment Decision, and markets are able to assess the timeline these new investments are on. Given the number of projects in the pipeline, however, export capacity could significantly expand by end-2020 or 2021. This evolution will be most visible in the different price spreads we follow, which offer a market-based assessment of these developments. First, we track the WTI- and Midland- LLS prices to grasp the evolution of Cushing and Permian pipeline debottlenecks toward the Gulf Coast – i.e. the domestic constraints. Second, we use the LLS-Brent spread as a gauge for the Gulf Coast export buildout – i.e. the external constraints (Chart 11). Bottom Line: Independent U.S. E&Ps will manage to increase production in line with current guidance while remaining profitable. This will be supported by completion of excess DUCs and rising WTI prices. Moreover, the emergence of the supermajors in the Permian and other prolific shale regions will contribute to increasing total U.S. onshore production in line with our current forecasts. Our base case suggests the U.S. Gulf Coast export capacity buildout will allow the excess production to reach foreign buyers. Nonetheless, risks remain re potential delays in these massive projects. The LLS-Brent spread could be volatile this year and next   Chart 11Tracking Domestic And External Constraints With Crude Price Spreads Hugo Bélanger, Senior Analyst Commodity & Energy Strategy HugoB@bcaresearch.com Robert P. Ryan, Chief Commodity & Energy Strategist rryan@bcaresearch.com   Footnotes 1      Please see BCA Research’s Commodity And Energy Strategy Special Report titled “Shale-Oil E&Ps Turning A Corner?” published June 13, 2019. It is available at ces.bcaresearch.com. 2      Supermajors include XOM, CVX, RDS/Shell, BP AND TOTAL. 3      Please See ExxonMobil to increase, accelerate Permian output to 1 million barrels per day by 2024 published March 5, 2019 by exxonmobil.com. Please see Chevron eyes 900,000 b/d from Permian by yearend 2023 published March 6, 2019 by ogj.com. 4      Please see The ‘Monster’ Texas Oil Field That Made the U.S. a Star in the World Market published February 3, 2019 by nytimes.com. 5      For instance, Exxon communicated it could sustain double-digit returns in the Permian with prices falling to $35/bbl. Please see ExxonMobil to increase, accelerate Permian output to 1 million barrels per day by 2024 published March 5, 2019 by exxonmobil.com. 6              Our analysis is based on a sample of selected public independent U.S. E&P companies. As a group, these companies represent ~3.0mm b/d of production (or close to 35% of U.S. onshore production). Our full cycle cost breakeven represents oil price that provides a ~10%+ return on the incremental capital plus the cost of overhead and the capital cost of the drilling right acquisition. 7              Our production estimate is equal to [rig count X estimate of new production per rigs] – [estimate of decline rates X legacy production]. 8              In Part 1, we discussed the likelihood independent E&P companies will deliver on investors’ demand for fiscal discipline. In our view, this will contribute, at the margin, to lowering the supply price-elasticity of U.S. shale development. In periods of high oil prices, these companies will increase production within the limit of their growing cash flow (i.e. without raising external financing via debt or equity). This implies production will have less upside as prices increase or remain elevated. On the other hand, in periods of declining or low prices, the healthy balance sheets of fiscally disciplined companies keeps the external financing window open in case of reduced cash flow. Moreover, the larger the share of companies that manage to improve their balance sheets, the lower the number of bankruptcies when prices decline. This limits the production decline. Hence, on average, production will grow at more steady pace than in the past, decreasing its price-elasticity. 9              Please see “Take a Look at Me Now – Gulf of Mexico Crude Output Is Approaching 2 MMb/d,” published May 7, 2019 by RBN Energy. 10     Please see Subsea tie-backs de-risk Deepwater Gulf of Mexico published June 4, 2019 by ihsmarkit.com. 11     BP plans to increase its production in the GoM by ~400k boe/d through expansion using existing facilities at its Atlantis, Thunder Horse and Na Kika fields. Please see BP plans for significant growth in deepwater Gulf of Mexico published January 8, 2019 by bp.com. Shell signaled it would leverage its new Appomattox infrastructure to tie-back adjacent fields -- e.g. production from Vicksburg and Fort Sumter. Shell's upstream director mentioned “Appomattox creates a core long-term hub for Shell in the Norphlet through which we can tie back several already discovered fields as well as future discoveries.” Please see Appomattox field comes on stream in GOM published May 23, 2019 by ogj.com. 12     Please see Shell starts production at giant Appomattox field in Gulf of Mexico published May 23, 2019 by reuters.com. 13     Please see As Permian oil production turns lighter, price outlook darkens published June 6, 2019 by reuters.com. West Texas Light (WTL) is a newly available crude grade from the Permian basin with an API of 44.1 to 49.9 and maximum sulfur of 0.4% vs. an API of ~ 40 for WTI. Most of the growth in WTL production comes for the Delaware basin within the Permian. The API is a measure of the density of a petroleum liquid. The higher the API, the lighter the crude is. This will determine the complexity of refining a certain crude input into finished products. 14     Please see BCA Research’s Commodity and Energy Strategy Weekly Report titled “Oil Price Diffs: Global Convergence,” published March 7, 2019. It is available at ces.bcaresearch.com.

Highlights The breakout in financial asset prices stands at odds with a deteriorating profit outlook. This suggests a high probability of a coiled-spring reversal in one of the two variables as we enter the thin summer trading months. We are maintaining a pro-cyclical currency stance, but are making a few portfolio tweaks in case we are caught offside during what could be a volatile summer. Maintain very tight stops on cable at 1.25, but look to sell EUR/GBP between 0.92 and 0.94. Our top pick for long positions are petrocurrencies, as geopolitical support is unlikely to ebb anytime soon. Buy a speculative basket of the Norwegian krone, Russian ruble, Mexican peso, and Colombian peso versus the euro. The latest RBA interest rate cut might be the ultimate insurance backstop needed to jumpstart the Australian economy. Remain long the Aussie dollar versus both the greenback and the kiwi, but with tight stops on the former. Any “flash crashes” are likely to favor the currencies of countries where tradeable bonds are in short supply. Remain short USD/JPY. Also, tactically sell gold bullion versus the yen. Feature Chart I-1The Markets And Data Diverge Financial markets are at an important crossroads as we head into the thin summer trading months. Asset prices have been reflated by plunging bond yields, with the S&P 500 hitting fresh highs this week. On the other hand, incoming manufacturing data across the major economies continue to deteriorate, suggesting the profit cycle remains in a downtrend. Either markets get better visibility into an improving profit outlook, or stock prices will succumb to the pressure of incoming data weakness (Chart I-1).    For currency strategy, this means fundamentals could be temporarily put to the wayside, as markets flip the switch towards risk aversion. Our recommendations this week are threefold. First, maintain tight stops on tactical positions, especially those susceptible to summer volatility. Topping this list is our long position in the British pound. Second, our top pick for long positions are petrocurrencies, as geopolitical support is unlikely to ebb anytime soon. Finally, maintain portfolio insurance by being short the USD/JPY. Also, sell gold against the yen, given that relative sentiment has shifted in extreme favor of the former. A Summer Attack On The Pound? The episodes leading to the collapse of the pound in 1992 have important lessons for today.1 Britain entered the Exchange Rate Mechanism (ERM) in October of 1990 in an attempt to find a stable nominal anchor. In the years preceding entry into the ERM, inflation in the U.K. had been high and rising, leading to an appreciation in the real exchange rate. The rationale was that by adopting German interest rates, inflation would finally be tempered, and the real exchange rate would eventually be realigned. Most of the adjustment in the pound happened quickly, but a key difference from today is that exit from the ERM was unanticipated, unlike Brexit.  During the ensuing years, pressure on the pound was relatively short-lived and could be quickly reversed by foreign exchange interventions or modest increases in interest rates. Meanwhile, the prospect of a European Monetary Union (EMU) also provided an anchor for expectations, since it would allow for more sound domestic policies. Problems began to surface in June 1992, when the Danes voted no in a referendum on the Maastricht Treaty that included a chapter on the EMU. This led to severe doubts about the progress made towards a union, especially as the outcome of the French referendum in September was expected to be close. Investors began to question where the shadow exchange rate for ERM currencies lay, especially where the Italian lira or the Spanish peseta were concerned. In August of that year, Britain began to massively step up interventions in the foreign exchange market, having to borrow excessively through the Very Short Term Financing facility (VSTF) to increase reserves. It also promised to raise interest rates from 10% to 12%, and later to 15%. But as an overvalued exchange rate had generated extremely sluggish GDP growth going into the 1990s, markets were not convinced the U.K. would tap into its unlimited borrowing facility or raise interest rates sufficiently to defend the pound. On black Wednesday in September 1992, Britain suspended membership to the ERM. There are a few important lessons that stand in stark contrast to a hard Brexit: Most of the adjustment in the pound happened quickly, but a key difference from today is that exit from the ERM was unanticipated, unlike Brexit. Foreign exchange markets are extremely fluid and adjust to expectations quite quickly, usually with overshoots or undershoots. From its peak, GBP/USD depreciated by 24% by the end of October 1992. It subsequently fell to a low of 1.418 in February 1993 (Chart I-2). Peak to trough, cable has already fallen by 28%. Judging from the real effective exchange rate adjusted for consumer prices, the pound was overvalued as the U.K. entered the ERM. A persistent inflation differential between the U.K. and Germany had led to significant appreciation in the real rate. That gap is much narrower today (Chart I-3). Chart I-2The Pound Drop During ERM Was Quick And Violent Chart I-3Not Much Misalignment In##br## U.K. Prices Today The overvaluation of the pound meant that domestic growth was under tremendous pressure. Growth was already at recessionary levels entering into the ERM. Meanwhile, a bursting real estate bubble necessitated lower, not higher interest rates. This put to test the credibility of the peg. Today, U.K. growth is outpacing that of Germany, and will only improve if the pound drops further (Chart I-4). Productivity in the U.K. has kept pace with that of Germany over the last several years, suggesting the fall in the pound has been unwarranted. The Tory government runs a balanced budget and the Bank of England has much foreign exchange reserves to intervene in the market should confidence in the pound collapse. More importantly, the British currency is freely floating meaning there are less “hidden sins” compared to the fixed exchange rate period when it had to use the VSTF facility to boost reserves (Chart I-5). Chart I-4The U.K. Is Growing Faster Than The Eurozone's Engine Chart I-5Britain Has Lots Of ##br##FX Reserves A new conservative leadership is, at the margin, more negative for the pound (the assessment of our geopolitical strategists is that the odds of a hard Brexit have risen to 21% from 14%). However, our simple observation is that the pound is below where it was after the 2016 referendum results, yet more people are now in favor of staying in the union (Chart I-6). The pound is below where it was after the 2016 referendum results, yet more people are now in favor of staying in the union. This dichotomy might be the reason why in a speech this week, BoE Governor Mark Carney continued to highlight the growing divergence between market interest rate expectations (almost a 50% probability of a cut this year) and the central bank’s more hawkish bias. The experience of the ERM suggests it will be extremely destabilizing for the pound if the BoE is unable to anchor market interest rate expectations. This is especially true since the second quarter is likely to be a very weak one, leaving little time for data improvement until the October 31st Brexit deadline. Chart I-6More People In Favour Of The Union Chart I-7Cable Valuation Reflects Brexit Risk   Putting it all together, our bias is that if there is a hard Brexit, the pound could easily drop to the 1.10-1.15 zone. Part of this move will be an undershoot. The real effective exchange rate of the pound is now lower than where it was after the U.K. exited the ERM in 1992, with a drawdown that has been of similar magnitude (24% in both episodes) (Chart I-7). In the case of a soft Brexit (or no Brexit), the pound should converge toward the mid-point of its (or above) historical real effective exchange rate range, which will pin it 15-20% higher, or at around 1.50. As for EUR/GBP, U.K. gilt yields stand at 108-basis-point over German bunds, an attractive spread should carry trades return in favor. Historically, such a spread has usually pinned the EUR/GBP much lower (Chart I-8). Yes, incoming data in the U.K. has softened, but employment growth has been holding up, wages are inflecting higher and the average U.K. consumer appears in decent shape. Investment and construction have been the weak spot in the U.K. economy, but may marginally improve on lower rates. Meanwhile, from a technical perspective, the pound is also oversold versus the euro (Chart I-9). Chart I-8EUR/GBP Is A Sell Long-Term Chart I-9EUR/GBP Is Overbought Bottom Line: Stay long the pound as we enter volatile summer trading, but maintain tight stops at 1.25. Sell EUR/GBP if 0.94 is touched. Buy A Speculative Basket Of Petrocurrencies Rising geopolitical tensions between the U.S. and Iran continue to support oil prices. Meanwhile, at its latest meeting, OPEC agreed to extend its production cuts to the first half of 2020. This will put upward pressure on forward curves, nudging oil near our Commodity & Energy Strategy service’s target of $75 per barrel.2 Should demand pick up later this year, it will supercharge the uptrend. More importantly, the risk of escalation between Iran and the U.S. is high, given that the former has been backed up into a corner on falling oil exports. Together with a weakening U.S. dollar, this will be categorically bullish for petrocurrencies. In our currency portfolio, we are long the NOK versus both the SEK and CAD as exposure to both crude oil prices and the Brent premium. This week, we are adding a speculative basket of the Colombian peso, Mexican peso and Russian ruble to benefit from any surge in the oil geopolitical risk premium. This basket is attractive for two reasons. First, the currencies are trading at a discount to what is implied by the oil price (Chart I-10). This discount could rapidly close if it becomes evident that oil supplies are at major risk. It is also beneficial that the shipping routes these supplies take categorically avoids the Straits of Hormuz, or the epicenter of the conflict. Second, the carry from the trade is attractive at 5%, which provides some cushion against downside risks. The risk of escalation between Iran and the U.S. is high. Together with a weakening U.S. dollar, this will be categorically bullish for petrocurrencies. The positive correlation between petrocurrencies and oil has been gradually eroded as the U.S. economy has become less and less of an oil importer. Meanwhile, Norwegian production has been falling for a few years. This is why it may be increasingly more profitable to be long a basket of petrocurrencies versus oil-consuming nations rather than the U.S. Going long versus the euro is also a cushion against a knee-jerk rally in the dollar. Also going long a basket of higher-yielding EM petrocurrencies versus DM ones is a good bet (Chart I-11). Chart I-10Petrocurrencies Are Attractive Chart I-11EM Versus DM Oil Basket Bottom Line: Buy a speculative basket of the Norwegian krone, Russian ruble, Mexican peso and Colombian peso versus the euro. Investors should also consider a basket of EM petrocurrencies versus DM ones. A Final Note On Gold The short-term technical picture for gold has become unfavorable. This suggests that investors could be caught offside in the interim holding gold as a hedge. We recommend swapping some gold bullion for yen to insure against this risk for three reasons: As both are safe-haven proxies, yen in gold terms has tended to mean revert since 2012, so as to maintain a stable ratio of 138,000 JPY per ounce of gold. Today, the yen is sitting at two standard deviations below this range (Chart I-12). Open interest for gold is surging towards new highs, while that of the yen is making fresh lows. In the case of a rush towards safe havens, the liquidity squeeze is likely to favor appreciation in the yen (Chart I-13). Chart I-12Sell Some Bullion For Yen Paper Chart I-13A Liquidity Squeeze Could Favor The Yen   Speculators are long gold but short the yen, which is attractive from a contrarian standpoint (Chart I-14). Chart I-14Speculators Are Long Gold And Short Yen Bottom Line: Remain short USD/JPY and sell a basket of gold versus some yen.    Chester Ntonifor, Foreign Exchange Strategist chestern@bcaresearch.com Footnotes 1 Mathias Zurlinden, “The Vulnerability of Pegged Exchange Rates: The British Pound in the ERM,” Economic Research, Vol. 75, No. 5 (September/October 1993). 2 Please see Commodity & Energy Strategy Weekly Report, titled “Oil Volatility Will Abate As Financial Conditions Ease,” dated July 4, 2019, available at ces.bcaresearch.com Currencies U.S. Dollar Chart II-1USD Technicals 1 Chart II-2USD Technicals 2 Recent data in the U.S. have been soft: Headline PCE fell to 1.5% year-on-year in May. Core PCE was unchanged at 1.6% year-on-year. Personal income growth was unchanged at 0.5% month-on-month in May, while personal spending fell to 0.4% month-on-month. Markit composite and manufacturing PMI both increased to 51.5 and 50.6 in June. However, ISM manufacturing and non-manufacturing PMI both decreased to 51.7 and 55.1 in June. Chicago purchasing managers’ index fell to 49.7 in June. Trade deficit widened to $55.5 billion in May. Factory orders contracted by 0.7% month-on-month in May. Also, durable goods orders fell by 1.3% month-on-month in May. DXY index increased by 0.4% this week. Our bond-to-gold indicator continues to point towards a weaker dollar. We believe that the combination of Chinese stimulus and the lagged effects from easing financial conditions should lift the global growth later this year, which would be a headwind for the dollar. Report Links: On Gold, Oil And Cryptocurrencies - June 28, 2019 Battle Of The Central Banks - June 21, 2019 EUR/USD And The Neutral Rate Of Interest - June 14, 2019 The Euro Chart II-3EUR Technicals 1 Chart II-4EUR Technicals 2 Recent data in the euro area have been mixed: Headline inflation was unchanged at 1.2% year-on-year in June, while core inflation increased to 1.1% year-on-year in June. Money supply (M3) grew by 4.8% year-on-year in May. Markit composite PMI increased to 52.2 in June. Manufacturing PMI fell to 47.6, while services PMI increased to 53.6. Unemployment rate fell to 7.5% in May. Producer price inflation fell to 1.6% year-on-year in May. Retail sales growth fell to 1.3% year-on-year in May. EUR/USD fell by 0.8% this week. IMF managing director Christine Lagarde was nominated to replace Mario Draghi as European Central Bank president this week. Analysts believe that she will likely maintain the ECB’s accommodative stance. This was confirmed by the plunge in 10-year bund yields to -40bps. Report Links: Battle Of The Central Banks - June 21, 2019 EUR/USD And The Neutral Rate Of Interest - June 14, 2019 Take Out Some Insurance - May 3, 2019 Japanese Yen Chart II-5JPY Technicals 1 Chart II-6JPY Technicals 2 Recent data in Japan have been mixed: The Tankan survey for Q2 was a mixed bag. The index for large manufacturers fell from 12 to 7. That for non-manufacturers increased from 21 to 23. Importantly, capex intentions rose from 1.2% to 7.4%. Housing starts contracted by 8.7% year-on-year in May. Construction orders continue to fall by 16.9% year-on-year in May. Nikkei composite PMI increased to 50.8 in June. Manufacturing PMI fell to 49.3, while services PMI increased to 51.9. Consumer confidence fell to 38.7 in June. USD/JPY has been flat this week. While Trump and Xi agreed to delay the trade talks during the G20 summit last weekend, there is no real progress toward a final trade agreement that could alleviate the tariffs. We continue to recommend the yen as a safe-haven hedge. Report Links: Battle Of The Central Banks - June 21, 2019 Short USD/JPY: Heads I Win, Tails I Don’t Lose Too Much - May 31, 2019 Beware Of Diminishing Marginal Returns - April 19, 2019 British Pound Chart II-7GBP Technicals 1 Chart II-8GBP Technicals 2 Recent data in the U.K. have been negative: GDP growth was unchanged at 1.8% year-on-year in Q1. Current account deficit widened to £30 billion in Q1. Markit composite PMI fell to 49.7 in June. Manufacturing PMI decreased to 48; Construction PMI fell to 43.1; Services PMI fell to 50.2. Mortgage approvals fell to 65.4 thousand in May, while the Nationwide house price index was up 0.5% year-on-year. GBP/USD fell by 1% this week. BoE governor Carney warned in a speech this week that “a global trade war and a no deal Brexit remain growing possibilities not certainties.” Moreover, he stated that monetary policy must address the consequences of such uncertainty for the behavior of business, household, and financial markets. The probability of a BoE rate cut by the end of this year has thus increased from 21% to 46% following his speech. Report Links: Battle Of The Central Banks - June 21, 2019 A Contrarian View On The Australian Dollar - May 24, 2019 Take Out Some Insurance - May 3, 2019 Australian Dollar Chart II-9AUD Technicals 1 Chart II-10AUD Technicals 2 Recent data in Australia have been mostly positive: The Markit manufacturing PMI increased from 51.7 to 52.0 Terms of trade remain in a powerful uptrend. HIA new home sales increased by 28.8% month-on-month in May. This is beginning to put a floor under building approvals. Trade surplus increased to A$5.8 billion in May, the highest on record. Retail sales increased by 0.1% month-on-month in May. AUD/USD increased by 0.3% this week. Following the rate cut last month, the RBA again cut interest rates by another 25 basis points to a historical low of 1% this week. During the policy statement, Governor Philip Lowe stated that this should support employment growth and provide greater confidence to achieve the inflation target. We continue to favor the Australian dollar from a contrarian perspective. Report Links: A Contrarian View On The Australian Dollar - May 24, 2019 Beware Of Diminishing Marginal Returns- April 19, 2019 Not Out Of The Woods Yet - April 5, 2019 New Zealand Dollar Chart II-11NZD Technicals 1 Chart II-12NZD Technicals 2 Recent data in New Zealand have been positive: Consumer confidence increased by 2.8% month-on-month in June. Building permits increased by 13.2% month-on-month in May. NZD/USD fell by 0.3% this week. With its policy rate 50 basis points higher than its antipodean counterpart, the RBNZ is now under pressure to cut rates in the coming weeks. The market is currently pricing an 84% probability of a rate cut for the next policy meeting in August, and 94% chance rates will be cut before year-end. Should data disappoint in the interim, additional cuts could be priced in. Hold on to our long AUD/NZD and SEK/NZD positions. Report Links: Where To Next For The U.S. Dollar? - June 7, 2019 Not Out Of The Woods Yet - April 5, 2019 Balance Of Payments Across The G10 - February 15, 2019 Canadian Dollar Chart II-13CAD Technicals 1 Chart II-14CAD Technicals 2 Recent data in Canada have been positive: GDP growth increased to 1.5% year-on-year in Q1. Bloomberg Nanos confidence continues to rise to 58.3 last week. This tends to lead GDP growth by a quarter or two. Markit manufacturing PMI increased to 49.2 in June. Exports and imports both increased to C$53.1 billion and C$52.3 billion in May. The trade balance turned positive to C$0.8 billion on surging exports to the U.S. USD/CAD fell by 0.5% this week. The BoC Business Outlook Survey published last Friday highlighted that business sentiment has slightly improved, and that hiring intentions continue to be healthy. This should underpin the loonie in the near-term. ­­­Report Links: On Gold, Oil And Cryptocurrencies - June 28, 2019 Currency Complacency Amid A Global Dovish Shift - April 26, 2019 A Shifting Landscape For Petrocurrencies - March 22, 2019 Swiss Franc Chart II-15CHF Technicals 1 Chart II-16CHF Technicals 2 Recent data in Switzerland have been negative: KOF leading indicator fell to 93.6 in June. Real retail sales contracted by 1.7% year-on-year in May. Manufacturing PMI fell to 47.7 in June. Headline inflation was unchanged at 0.6% year-on-year in June, while core inflation increased to 0.7% year-on-year in June. USD/CHF increased by 0.4% this week. The CHF/NZD cross has been correcting in recent weeks, and could eventually trigger our limit buy order at 1.45. Stay tuned. Report Links: What To Do About The Swiss Franc? - May 17, 2019 Beware Of Diminishing Marginal Returns - April 19, 2019 Balance Of Payments Across The G10 - February 15, 2019 Norwegian Krone Chart II-17NOK Technicals 1 Chart II-18NOK Technicals 2 Recent data in Norway have been mixed: Manufacturing PMI fell from 54.1 to 51.9 in June. Registered unemployment was unchanged at 2.1% in June. House prices are inflecting higher, to the tune of 2.6% year-on-year in June. USD/NOK fell by 0.5% this week. This week’s OPEC meeting extended the production cuts into 1Q20. Easing global financial conditions and Chinese stimulus should help revive oil demand. Our Commodity & Energy Strategy team continues to expect Brent to average $75/bbl by the end of this year. Stay long NOK/SEK and short CAD/NOK. Report Links: On Gold, Oil And Cryptocurrencies - June 28, 2019 Currency Complacency Amid A Global Dovish Shift - April 26, 2019 A Shifting Landscape For Petrocurrencies - March 22, 2019 Swedish Krona Chart II-19SEK Technicals 1 Chart II-20SEK Technicals 2 Recent data in Sweden have been negative: Retail sales fell by 0.5% year-on-year in May. Composite PMI fell to 50.5 in June. Manufacturing and services PMI both fell to 52 and 49.9. USD/SEK increased by 0.4% this week. The Riksbank held its interest rate unchanged at -0.25% this week as widely expected. However, the tone in the communique was hawkish. That said, the trade disputes between U.S. and China, and the Brexit chaos remain downside risks to the European economy, and the Riksbank might push the planned rate hike further down the road. Report Links: Where To Next For The U.S. Dollar? - June 7, 2019 Balance Of Payments Across The G10 - February 15, 2019 A Simple Attractiveness Ranking For Currencies - February 8, 2019 Trades & Forecasts Forecast Summary Core Portfolio Tactical Trades Limit Orders   Closed Trades

Oil prices will remain volatile as markets work through the lingering effects of tighter financial conditions prevailing last year, which, along with extended angst over Sino-U.S. trade tensions, slowed commodity demand growth (Chart of the Week). In 2H19, globally accommodative monetary policy and fiscal stimulus will revive demand for industrial commodities, particularly in EM economies. This will be most apparent in oil markets, where we continue to expect demand growth to strengthen going into 2020, aided in part by a weaker USD. On the supply side, this week’s extension of OPEC 2.0’s production cuts into 1Q20 means growth will remain constrained. Prices will rise, and forward curves, particularly for Brent, will steepen as refiners are forced to draw inventories to meet product demand.1 We continue to expect Brent to average $73/bbl this year and $75/bbl next, respectively. We expect WTI to trade $7/bbl and $5/bbl below that this year and next. Chart of the WeekEasing Financial Conditions Will Spur Oil Demand Highlights Energy: Overweight.  Venezuela’s oil production reportedly recovered to 1.1mm b/d in June.  Most of the increased production found its way to China, which accounted for just under 60% of crude and product exports.2  Given its modus operandi, we believe OPEC 2.0 likely will accommodate higher production in Venezuela by reducing production in other member states, keeping overall output relatively constant. Base Metals: Neutral.  Copper treatment and refining charges fell to new lows at the end of last week, with Fastmarkets MB’s Asia – Pacific TC/RC index recording its lowest level on record at $52.40/MT ($0.0524/lb).3  TC/RC levels fall when supplies are low, as refiners have to discount their services to attract concentrate supplies.  Elsewhere, workers at Codelco’s Chuquicamata copper mine agreed to a new contract last week, ending a brief strike.  Precious Metals: Neutral.  Gold’s rally resumed this week, reflecting investors’ expectations for expanded central-bank accommodation globally, which, all else equal, will keep interest rates lower for longer. The Fed's dovish turn, in particular, will weaken the USD later this year, which will be positive for EM commodity demand, the engine for commodity demand growth globally. Ags/Softs: Underweight.  The USDA reported 56% of corn in the ground was in good to excellent condition last week, vs. 76% of the crop last year.  For soybeans, 54% of the U.S. crop was in good or excellent condition, vs. 71% last year.  The USDA’s Crop Progress reports cover 92% and 95% of total acreage planted in the U.S., respectively. Feature Oil prices will remain volatile over the short term, as markets transition from tighter monetary conditions to a more accommodative global backdrop (Chart 2). Based on our research into the drivers of oil-price volatility, this should translate into a less stressful pricing environment for industrial commodities generally, base metals and oil in particular (Chart 3).4 Chart 2Volatility Indicators Are Moderating Chart 3Signaling Oil Price Volatility Will Fall Much of the current oil-price volatility is being driven by worries over damage to aggregate global demand and growth expectations in the wake of the Sino-U.S. trade war, and by what now appears to be a too-aggressive posture by central banks implementing rates-normalization policies last year. Both of these can affect consumption and investment locally and globally.5 Fear That Real Demand Will Weaken At present, any indication real demand is faltering – e.g., weaker manufacturing PMIs – gives industrial commodities an excuse to sell off (Chart 4). In the case of the Sino-U.S. trade war, presidents Xi and Trump appear to have agreed to re-start trade negotiations. Markets are not going to be terribly concerned with the specifics of a trade deal between the U.S. and China, but it does appear some rollback in U.S. tariffs will be necessary for a trade deal – perhaps in exchange for greater access to Chinese markets. However, our geopolitical strategists make the odds of a trade deal by the time U.S. elections roll around 1:3. Our colleagues in BCA Research’s Global Investment Strategy note, “The specifics of the deal are less important than there being a deal – any deal – that avoids a major escalation. Ultimately, the distinction between a ‘small’ trade war and a ‘moderate’ trade war is a function of how high tariffs end up being. Tariffs are taxes, and while no one likes to pay taxes, they are a familiar part of the global capitalist system.”6 As for monetary policy, major central banks are embarked on a coordinated effort to reverse falling inflation expectations, and will be vigorously stimulating their money supply and credit growth over the balance of the year. In addition, fiscal stimulus globally – in the U.S. and China most prominently – will boost real demand for industrial commodities, particularly oil and base metals.7 Monetary and fiscal stimulus operates with a lag, which is why we continue to expect its more visible for commodity demand to become apparent in commodity prices later in 2H19 and next year. This lagged effect can be seen in our expectation for the evolution of EM import volumes to year end, which we estimate using data compiled the CPB World Trade Monitor (Chart 5). EM import volumes are closely tied to the evolution of EM income, which drives global commodity demand.8 Chart 4Globally, The Real Economy Has Slowed Chart 5EM Imports and Income Will Rebound In our modeling of supply-demand balances and prices, we accounted for the reduced EM GDP growth brought about by more restrictive monetary policy last year and the slowdown in global trade in our most recent forecast. In our base case, we took our expected global oil-demand growth this year down to 1.35mm b/d from 1.5mm b/d earlier, and to 1.55mm b/d next year from 1.6mm b/d previously. These adjustments reduced our price expectation for Brent crude oil slightly to $73/bbl this year and $75/bbl next year, with WTI trading $7/bbl and $5/bbl below those respective levels (Chart 6). Chart 6Our Forecasts Reflect Lower Demand, Tighter Supply Oil Markets Will Get Tighter   For all of the concern over real demand, prompt demand remains stout relative to available supply, as can be seen in the backwardations for global benchmark crude oil prices (Chart 7). This week’s extension of OPEC 2.0’s production cuts into 1Q20 means supply growth will remain constrained, which, given our demand expectation, will tighten balances globally (Chart 8).9 Chart 7Global Oil Benchmarks Remain Backwardated Chart 8Oil Supply Demand Balances Will TightenChart 9Oil Inventories Will Fall, As Supply Is Constrained As balances tighten in the wake of global fiscal and monetary stimulus, oil prices will rise, and forward curves, particularly for Brent, will steepen as refiners are forced to draw inventories to meet product demand (Chart 9). For this reason we remain long September – December 2019 Brent vs. short September – December 2020 Brent, expecting backwardation to increase.10 Bottom Line: We remain constructive toward oil markets, as they transition to a more accommodative monetary backdrop globally. Combined with fiscal stimulus in the U.S. and China in particular, demand will remain supported in 2H19 and 2020. The extension of OPEC 2.0’s production-cutting deal will tighten markets, forcing refiners to draw down inventories.   Robert P. Ryan, Chief Commodity & Energy Strategist rryan@bcaresearch.com     Footnotes 1      OPEC 2.0 is a name we coined for the OPEC/non-OPEC oil-producing coalition led by the Kingdom of Saudi Arabia (KSA) and Russia. Their agreement to extend production cuts of 1.2mm b/d into 1Q19 was announced this week in Vienna. Please see OPEC/non-OPEC rolls over oil output cuts for 9 months published by S&P Global Platts on July 2, 2019. Compliance with these cuts has been higher by ~ 400k b/d in 1H19 by our reckoning. 2      Please see Venezuela's June oil exports recover to over 1 million bpd: data published July 2, 2019, by reuters.com. 3      Please see Copper concs TCs drop marginally on traders purchase; Cobre Panama’s fresh supply hits market published by Fastmarkets MB June 28, 2019. 4      We are using “volatility” in the technical sense here – i.e., the standard deviation of per-annum returns. We have shown this can be explained by different variables, including EM volatility; U.S. financial conditions – as seen in the St. Louis Fed’s financial-stress index; and by speculative positioning, which tends to follow the evolution of prices as news flows change. For discussions of our volatility modeling, including the construction of Working’s T index, please see Specs Back Up The Truck For Oil, published April 26, 2018, and Feedback Loop: Spec Positioning & Oil Price Volatility, published May 10, 2018, by BCA Research’s Commodity & Energy Strategy. Both are available at ces.bcaresearch.com. 5      Please see The economic implications of rising protectionism: a euro area and global perspective published by European Central Bank April 24, 2019. 6      Please see Third Quarter 2019 Strategy Outlook: The Long Hurrah, BCA Research’s global macro outlook for 3Q19, published June 28, 2019, by our Global Investment Strategy. It is available at gis.bcaresearch.com.  The larger issues that will have to be addressed at some point in the future are non-tariff barriers to trade, exemplified by Huawei’s exclusion from access to U.S. technology on national security grounds.  An expansion of such non-tariff barriers would strand huge amounts of capital globally, which likely would lead to a global recession. 7      Our chief global strategist, Peter Berezin, notes in the above-cited BCA Research third-quarter outlook that Fed policy is expected to remain ultra-accommodative into late 2021, which will push the USD lower later this year, and will support commodity demand generally. 8      We use an FX-based model to estimate EM import volumes to year end off the CPB data. 9      We will be updating our Venezuela and OPEC 2.0 production estimates to reflect this development in our July global oil market balance publication later this month. 10     We have been long 2H19 Brent vs. short 2H20 Brent since February 28, 2019.  The July and August pieces of this position returned 222.7% and 273% since inception. We remain long the September – December exposure. Investment Views and Themes Recommendations Strategic Recommendations TRADE RECOMMENDATION PERFORMANCE IN 2019 Q2 Commodity Prices and Plays Reference Table Trades Closed in 2019 Summary of Closed Trades