Brazil
Highlights This week, Commodity & Energy Strategy is publishing a joint report with our colleagues at BCA's Energy Sector Strategy. Driven by the leadership of the Kingdom of Saudi Arabia (KSA) and Russia, OPEC 2.0 formalized the well-telegraphed decision to extend its production cuts for another nine months, carrying the cuts through the seasonally weak demand period of Q1 2018. The extension is will be successful in bringing OECD inventories down to normalized levels, even assuming some compliance fatigue (cheating) setting in later this year. Energy: Overweight. We are getting long Dec/17 WTI vs. short Dec/18 WTI at tonight's close, given our expectation OPEC 2.0's extension of production cuts, and lower exports by KSA to the U.S., will cause the U.S. crude-oil benchmark to backwardate. Base Metals: Neutral. Despite "catastrophic flooding" in March, 1Q17 copper output in Peru grew almost 10% yoy to close to 564k MT, according to Metal Bulletin. This occurred despite strikes at Freeport-McMoRan's Cerro Verde mine, where production was down 20.5% yoy in March. Precious Metals: Neutral. Our strategic gold portfolio hedge is up 2.61% since it was initiated on May 4, 2017. Ags/Softs: Underweight. The USDA's Crop Progress report indicates plantings are close to five-year averages, despite harsh weather in some regions. We remain bearish. Feature Chart 1Real OPEC Cuts Of ~1.0 MMb/d##BR##For Over 400 Days OPEC 2.0's drive to normalize inventories by early 2018 will be accomplished with last week's agreement to extend current production cuts through March 2018. In total, OPEC has agreed to remove over 1 MMb/d of producible OPEC oil from the market for over 400 days (Chart 1), supplemented by an additional 200,000-300,000 b/d of voluntary restrictions of non-OPEC oil through Q3 2017 at least, perhaps longer if Russia can resist the temptation to cheat after oil prices start to respond. Many of the participants in the cut, from both OPEC and non-OPEC, are not actually reducing output voluntarily, but have had quotas set for them that merely reflect the natural decline of their productive capacity, limitations that will be even more pronounced in H2 2017 than in H1 2017. With production restricted by the OPEC 2.0 cuts, global demand growth will outpace supply expansion by another wide margin in 2017, just as it did last year (Chart 2). As shown in Chart 3, steady demand expansion and the slowdown in supply growth allowed oil markets to move from oversupplied in 2015 to balanced during 2016; demand growth will increasingly outpace production growth in 2017, creating sharp inventory draws (Chart 4) that bring stocks down to normalized levels by the end of 2017 (Chart 5). Chart 3Production Cuts And Demand##BR##Growth Will Draw Inventories Chart 4Higher Global Inventory##BR##Withdrawals Through Rest Of 2017 Chart 5OECD Inventories To Be##BR##Reduced To Normal The extension of the cut through Q1 2018 will help prevent a premature refilling of inventories during the seasonally weak first quarter next year. The return of OPEC 2.0's production to full capacity in Q2 2018 will drive total production growth above total demand growth for 2018, returning oil markets from deliberately undersupplied during 2017 to roughly balanced markets in 2018, with stable inventory levels that are below the rolling five-year average. 2018 inventory levels will still be 5-10% above the average from 2010-2014, in line with the ~7% demand growth between 2014 and 2018. Compliance Assessment: Only A Few Players Matter In OPEC 2.0 OPEC's compliance with the cuts announced in November 2016 has been quite good, with KSA anchoring the cuts by surpassing its 468,000 b/d cut commitment. In addition to KSA, OPEC is getting strong voluntary compliance from the other Middle Eastern producers (except Iraq), while producers outside the Middle East lack the ability to meaningfully exceed their quotas in any case. OPEC's Core Four Remain Solid. The core of the OPEC 2.0 agreement has delivered strong compliance with their announced cuts. Within OPEC, the core Middle East countries Kingdom of Saudi Arabia, Kuwait, Qatar, and UAE have delivered over 100% compliance of their 800,000 b/d agreed-to cuts. We expect these countries to continue to show strong solidarity with the voluntary cuts through March 2018 (Chart 6). Iraq And Iran Make Small/No Sacrifices. Iraq and Iran were not officially excluded from cuts, but they were not asked to make significant sacrifices either. We estimate Iran has little-to-no capability to materially raise production in 2017 anyhow, and KSA is leaning on Iraq to better comply with its small cuts. Chart 7 shows our projections for Iran and Iraq production levels through 2018. Chart 6KSA, Kuwait, Qatar & UAE Carrying##BR##The Load Of OPEC Cuts Chart 7Iran And Iraq Production##BR##Near Full Capacity Iraq surged its production above 4.6 MMb/d for two months between OPEC's September 2016 indication that a cut would be coming and the late-November formalization of the cut. Iraq's quota of 4.35 MMb/d is nominally a 210,000 b/d cut from its surged November reference level, but is essentially equal to the country's production for the first nine months of 2016, implying not much of a real cut. Despite the low level of required sacrifice, Iraq has produced about 100,000 b/d above its quota so far in 2017 at a level we estimate is near/at its capacity anyway. KSA and others in OPEC are not pleased with Iraq's overproduction and have pressured it to comply with the agreement. We forecast Iraq will continue producing at 4.45 MMb/d. Iran's quota represented an allowed increase in production, reflecting the country's continued recovery from years of economic sanctions. We project Iran will continue to slowly expand production, but since the country is almost back up to pre-sanction levels, there is little remaining easily-achievable recovery potential. South American & African OPEC Capacity Eroding On Its Own. Chart 8 clearly shows how production levels in Venezuela, Angola and Algeria started to deteriorate well before OPEC formalized its production cuts, with productive capacity eroded by lack of reinvestment rather than voluntary restrictions. The quotas for these three countries (as well as for small producers Ecuador and Gabon) are counted as ~258,000 b/d of "cuts" in OPEC's agreement, but they merely represent the declines in production that should be expected anyway. With capacity deteriorating and no ability to ramp up anyway, these OPEC nations will deliver improving "compliance" (i.e. under-producing their quotas) in H2 2017, and are happy to have the higher oil prices created by the extension of production cuts by the core producers within OPEC 2.0. Libya and Nigeria Exclusions Unlikely To Result In Big Production Gains. Both Libyan and Nigerian production levels have been constrained by above-ground interference. Libyan production has been held below 1.0 MMb/d since 2013 principally by chronic factional fighting for control of export terminals, while Nigerian production--on a steady natural decline since 2010--has been further limited by militants sabotaging pipelines in 2016-2017. While each country has ebbs and flows to the amount of oil they are able to produce, we view both countries' problems as persistent risks that will continue to keep production below full potential (Chart 9). Chart 9Libya And Nigeria Production Could Go Higher##BR##Under Right (But Unlikely) Circumstances For Nigeria, we estimate the country's crude productive capacity has eroded to about 1.8 MMb/d from 2.0 MMb/d five years ago due to aging fields and a substantial reduction in drilling (offshore drilling is down ~70% since 2013). Within another year or two, this capacity will dwindle to 1.7 MMb/d or below. On top of this natural decline, we have projected continued sabotage / militant obstruction will limit actual crude output to an average of 1.55 MMb/d for the foreseeable future. Libyan production averaged just 420,000 b/d for 2014-2016, a far cry from the 1.65 MMb/d produced prior to the 2011 Libyan Revolution that ousted strongman Muammar Gaddafi. Since Gaddafi was deposed and executed, factional strife and conflict has persisted. Each faction wants control over oil export revenues and, just as importantly, wants to deny the opposition those revenues, resulting in a chronic state of conflict that has limited production and exports. If a détente were reached, we expect Libyan oil production could quickly rise to about 1.0 MMb/d of production within six months; however, we put the odds of a sustainable détente at less than 30%. As such, we forecast Libyan crude production will continue to struggle, averaging about 600,000 b/d in 2017-2018. Non-OPEC Cuts Hang On Russia In November, ten non-OPEC countries nominally agreed to restrict production by a total of 558,000 b/d, but Russia--with 300,000 b/d of pledged cuts--is the big fish that KSA and OPEC are relying on. Mexico's (and several others') agreements are window dressing, reframing natural production declines as voluntary action to rebalance markets. Through H1 2017, Russia has delivered on about 60-70% of its cut agreement, with compliance growing in Q2 (near 100%) versus Q1 (under 50%). From the start, Russia indicated it would require some time to work through the physical technicalities of lowering production to its committed levels, implying that now that production has been lowered, Russia could deliver greater compliance over H2 2017 than it delivered in H1 2017. We are a little more skeptical, expecting some weakening in Russia's compliance by Q4, especially if the extended cuts deliver the expected results of bringing down OECD inventories and lifting prices. Russia surprised us with stronger-than-expected production during 2016. Some of the outperformance was clearly due to a lower currency and improved shale-like drilling results in Western Siberia, but it is unclear whether producers also pulled too hard on their fields to compensate for lower prices, and are using the OPEC 2.0 cut as a way to rest their fields a bit. We have estimated Russian production returning to 11.3 MMb/d by Q4 2017 (50,000 b/d higher than 2016 average production) and holding there through 2018 (Chart 10), but actual volumes could deviate from this level by as much as 100,000-200,000 b/d. Mexico, the second largest non-OPEC "cutter," is in a position similar to Angola, Algeria, and Venezuela. Mexican production has been falling for years (Chart 11), and the nation's pledge to produce 100,000 b/d less in H1 2017 than in Q4 2016 is merely a reflection of this involuntary decline. As it has happened, Mexican production has declined by only ~60,000 b/d below its official reference level, but continues to deteriorate, promising higher "compliance" with their production pledge in H2 2017. Chart 10Russia Expected##BR##To Cheat By Q4 Chart 11Mexican Production Deterioration##BR##Unaffected By Cut Pledges Kazakhstan and Azerbaijan are not complying with any cuts, and we don't expect them to. Despite modest pledges of 55,000 b/d cuts combined, the two countries have produced ~80,000 b/d more during H1 2017 than they did in November 2016. We don't expect any voluntary contributions from these nations in the cut extension, but Azerbaijan's production is expected to wane naturally (Chart 12). While contributing only a small cut of 45,000 b/d, Oman has diligently adhered to its promised cuts, supporting its OPEC and Gulf Cooperation Council (GCC) neighbors. We expect Oman's excellent compliance will be faithfully continued through the nine-month extension (Chart 13). Chart 12Kazakhstan And Azerbaijan Not Expected##BR##To Comply With Any Cut Extension Chart 13Oman Has Faithfully Complied##BR##With Cut Promises To Date OPEC Extension Will Continue To Support Increased Shale Drilling Energy Sector Strategy believed OPEC's original cut announced in November 2016 was a strategic mistake for the cartel, as it would accelerate the production recovery from U.S. shales in return for "only" six months of modestly-higher OPEC revenue. As we cautioned at the time, the promise of an OPEC-supported price floor was foolish for them to make; instead, OPEC should have let the risk of low prices continue to restrain shale and non-Persian Gulf investment, allowing oil markets to rebalance more naturally. However, despite our unfavorable opinion of the strategic value of the original cut, since the cut has not delivered the type of OECD inventory reductions expected (seemingly due to a larger-than-expected transfer of non-OECD inventories into OECD storage), we view the extension of the cut as a necessary, and logical, next step. OPEC 2.0's November 2016 cut agreement signaled to the world that OPEC (and Russia) would abandon KSA's professed commitment to a market share war, and would instead work together to support a ~$50/bbl floor under the price of oil. Such a price floor dramatically reduced the investment risk for shale drilling, and emboldened producers (and supporting capital markets) to pour money into vastly increased drilling programs. Now that the shale investment genie has already been let out of the bottle, extending the cuts is unlikely to have nearly the same stimulative impact on shale spending as the original paradigm-changing cut created. The shale drilling and production response has been even greater than we estimated six months ago, and surely greater than OPEC's expectations. The current horizontal (& directional) oil rig count of 657 rigs is nearly twice the 2016 average of 356 rigs, is 60% higher than the level of November 2016 (immediately before the cut announcement), and is still rising at a rate of 25-30 rigs per month (Chart 14). The momentum of these expenditures will carry U.S. production higher through YE 2017 even if oil prices were allowed to crash today. Immediately following OPEC's cut, we estimated 2017 U.S. onshore production could increase by 100,000 - 200,000 b/d over levels estimated prior to the cut, back-end weighted to H2 2017, with a greater 300,000-400,000 b/d uplift to 2018 production levels. Drilling activity has roared back so much faster than we had expected, indicative of the flooding of the industry with external capital, that we have raised our 2017 production estimate by 500,000 b/d over our December estimate, and raised our 2018 production growth estimate to 1.0 MMb/d (Chart 15). Chart 14Rig Count Recovery Dominated##BR##By Horizontal Drilling Chart 15Onshore U.S. Production##BR##Estimates Rising Sharply Other Guys' Decline Requires Greater Growth From OPEC, Shales, And Russia We've written before about "the Other Guys' in the oil market, defined as all producers outside of the expanding triumvirate of 1) U.S. shales, 2) Russia, and 3) Middle East OPEC. While the growers receive the vast majority of investors' focus, the Other Guys comprise nearly half of global production and have struggled to keep production flat over the past several years (Chart 16). Chart 17 shows the largest offshore basins in the world, which should suffer accelerated declines in 2019-2020 (and likely beyond) as the cumulative effects of spending constraints during 2015-2018 (and likely beyond) result in an insufficient level of projects coming online. This outlook requires increasing growth from OPEC, Russia and/or the shales to offset the shrinkage of the Other Guys and simultaneously meet continued demand growth. Chart 16The Other Guys' Production##BR##Struggling To Keep Flat Risks To Rebalancing Our expectation global oil inventories will draw, and that prices will, as a result, migrate toward $60/bbl by year-end is premised on the continued observance of production discipline by OPEC 2.0. GCC OPEC - KSA, Kuwait, Qatar, and the UAE - Russia and Oman are expected to observe their pledged output reduction, but we are modeling some compliance "fatigue" all the same. Even so, this will not prevent visible OECD oil inventories from falling to their five-year average levels by year-end or early next year. Obviously, none of this can be taken for granted. We have consistently highlighted the upside and downside risks to our longer term central tendency of $55/bbl for Brent crude, with an expected trading range of $45 to $65/bbl out to 2020. Below, we reprise these concerns and our thoughts concerning OPEC 2.0's future. Major Upside Risks Chief among the upside risks remains a sudden loss of supply from a critical producer and exporter like Venezuela or Nigeria, which, respectively, we expect will account for 1.9 and 1.5 MMb/d of production over the 2017-18 period. Losing either of these exporters would sharply rally prices above $65/bbl as markets adjusted and brought new supply on line. Other states - notably Algeria and Iraq - highlight the risk of sustained production losses due to a combination of internal strife and lack of FDI due to civil unrest. Algeria already appears to have entered into a declining production phase, while Iraq - despite its enormous potential - remains dogged by persistent internal conflict. We are modeling a sustained, slow decline in Algeria's output this year and next, which takes its output from 1.1 MMb/d in 2015 down to slightly more than 1 MMb/d on average this year and next. For Iraq, where we expect a flattening of production at ~ 4.4 MMb/d this year and a slight uptick to ~ 4.45 MMb/d in 2018, continued violence arising from dispersed terrorism in that country in the wake of a defeat of ISIS as an organized force, will remain an ongoing threat to production. Longer term - i.e., beyond 2018 - we remain concerned the massive $1-trillion-plus cutbacks in capex for projects that would have come online between 2015 and 2020 brought on by the oil-price collapse in 2015-16 will force prices higher to encourage the development of new supplies. The practical implication of this is some 7 MMb/d of oil-equivalent production the market will need, as this decade winds down, will have to be supplied by U.S. shales, Gulf OPEC and Russia, as noted above. Big, long-lead-time deep-water projects requiring years to develop cannot be brought on fast enough to make up for supply that, for whatever reason, fails to materialize from these sources. In addition, as shales account for more of global oil supplies and "The Other Guys" continue to lose production to higher depletion rates, more and more shale - in the U.S. and, perhaps, Russia - and conventional Persian Gulf production will have to be brought on line simply to make up for accelerating declines. This evolution of the supply side is significantly different from what oil and capital markets have been accustomed to in previous cycles. Because of this, these markets do not have much historical experience on which to base their expectations vis-à-vis global supply adjustment and the capacity these sources of supply have for meeting increasing demand and depletion rates. Lower-Cost Production, Demand Worries On The Downside Downside risks, in our estimation, are dominated by higher production risks. Here, we believe the U.S. shales and Russia are the principal risk factors, as the oil industry in both states is, to varying degrees, privately held. Because firms in these states answer to shareholders, it must be assumed they will operate for the benefit of these interests. So, if their marginal costs are less than the market-clearing price of oil, we can expect them to increase production up to the point at which marginal cost is equal to marginal revenue. The very real possibility firms in these countries move the market-clearing price to their marginal cost level cannot be overlooked. For the U.S., this level is below $53/bbl or so for shale producers. For Russian producers, this level likely is lower, given their production costs are largely incurred in rubles, and revenues on sales into the global market are realized in USD; however, given the variability of the ruble, this cost likely is a moving target. While a sharp increase in unconventional production presently not foreseen either in the U.S. or Russian shales will remain a downside price risk, an increase in conventional output - chiefly in Libya - remains possible. As discussed above, we believe this is a low risk to prices at present; however, if an accommodation with insurgent forces in the country can be achieved, output in Libya could double from the 600k b/d of production we estimate for this year and next. We reiterate this is a low-risk probability (less than 25%), but, in the event, would prove to be significant additions to global balances over the short term requiring a response from OPEC 2.0 to keep Brent prices above $50/bbl. Also on the downside, an unexpected drop in demand remains at the top of many lists. This is a near-continual worry for markets, which can be occasioned by fears of weakening EM oil-demand growth from, e.g., a hard landing in China, or slower-than-expected growth in India. These are the two most important states in the world in terms of oil-demand growth, accounting for more than one-third of global growth this year and next. We do not expect either to meaningfully slow; however, we continue to monitor growth in both closely.1 In addition, we continue to expect robust global oil-demand growth, averaging 1.56 MMb/d y/y growth in 2017 and 2018. This compares with 1.6 MMb/d growth last year. OPEC 2.0's Next Move Knowing the OPEC 2.0 production cuts will be extended to March 2018 does not give markets any direction for what to expect after this extension expires. Once the deal expires, we expect production to continue to increase from the U.S. shales, and for the key OPEC states to resume pre-cut production levels. Along with continued growth from Russia, this will be necessary to meet growing demand and increasing depletion rates from U.S. shales and "The Other Guys." Yet to be determined is whether OPEC 2.0 needs to remain in place after global inventories return to long-term average levels, or whether its formation and joint efforts were a one-off that markets will not require in the future. Over the short term immediately following the expiration of the production-cutting deal next year, OPEC 2.0 may have to find a way to manage its production to accommodate U.S. shales without imperiling their own revenues. This would require a strategy that keeps the front of the WTI and Brent forward curves at or below $60/bbl - KSA's fiscal breakeven price and $20/bbl above Russia's budget price - and the back of the curve backwardated, in order to exert some control over the rate at which shale rigs return to the field.2 As we've mentioned in the past, we have no doubt the principal negotiators in OPEC 2.0 continue to discuss this. Toward the end of this decade, such concerns might be moot, if growing demand and accelerating decline curves require production from all sources be stepped up. Matt Conlan, Senior Vice President Energy Sector Strategy mattconlan@bcaresearchny.com Robert P. Ryan, Senior Vice President Commodity & Energy Strategy rryan@bcaresearch.com 1 Please see the May 18, 2017, issue of BCA Research's Commodity & Energy Strategy article entitled "Balancing Oil-Shale's Resilience And OPEC 2.0's Production Cuts," in which we discuss the outlook for China's and India's growth. Together, these states account for more than 570k b/d of the 1.56 MMb/d growth we expect this year and next. The article is available at ces.bcaresearch.com. 2 A backwardated forward curve is characterized by prompt prices exceeding deferred prices. Our research indicates a backwardated forward curve results in fewer rigs returning to the field than a flat or positively sloped forward curve. We explored this strategy in depth in the April 6, 2017, issue of BCA Research's Commodity & Energy Strategy, in an article entitled "The Game's Afoot In Oil, But Which One?" It is available at ces.bcaresearch.com. Investment Views and Themes Recommendations Strategic Recommendations Tactical Trades Commodity Prices and Plays Reference Table Trades Closed In 2017 Summary of Trades Closed in 2016
Highlights This week, we are reprising and updating "The Other Guys In The Oil Market" from our sister service Energy Sector Strategy (NRG), because it so well captures the state of oil production outside the U.S. shales, Middle East OPEC and Russia. "The Other Guys" account for ~ half of global supply. Next week, we'll publish a joint report with NRG analyzing today's OPEC meeting. The aptly named "Other Guys" account for ~ 42mm b/d of production, which they are struggling to maintain at current levels, let alone increase. These producers supply nearly half of global production, and have been stuck in a pattern of slow decline for years despite high oil prices. Beginning in 2019, we expect production declines to accelerate. This will put enormous pressure on the three primary growth regions, which markets likely will start pricing in toward the end of next year. Energy: Overweight. OPEC 2.0 is expected to extend its 1.8mm b/d of production cuts to the end of 1Q18 at its meeting in Vienna today. Going into the meeting, markets were being guided to expect even deeper cuts. Our long Dec/17 Brent $65/bbl calls vs. short $45/bbl puts, and our long Dec/17 vs. Dec/18 Brent positions are up 75.0% and 509.5% respectively, following their initiation on May 11, 2017. Base Metals: Neutral. Steel and iron-ore prices are getting a boost from China's anti-pollution campaign, which is expected to run through the end of this month. This was launched ahead of the anti-pollution campaign we expected after the Communist Party Congress in the fall. Iron ore delivered to Qingdao is up 3.1% since May 9, when Reuters reported the campaign began.1 Precious Metals: Neutral. Gold was well bid earlier in the week on the back of a weaker USD. Our long gold position is up 1.9%, while our long volatility trade, which we will unwind at tonight's close, is down 98.5%. Ags/Softs: Underweight. The weaker USD takes some pressure off wheat and beans over the short term, and might prompt a short-covering rally. We remain bearish, however, as the USD likely will bottom in the near future.2 Feature U.S. Onshore, Middle East OPEC (ME OPEC), and Russia combine to produce ~43 MMb/d of oil plus another ~11 MMb/d of other liquids (NGLs, biofuels, refinery gains, etc.). Combined, these producers increased crude production by 5 MMb/d plus another 1 MMb/d of other liquids production over the past three years (2014-2016), creating the oversupply that crashed prices. We expect these producers to add another 1.60 MMb/d of oil plus 1.14 MMb/d of other liquids by 2018 (over 2016 levels), dominated by nearly 2.0 MMb/d of oil and NGLs from the U.S. shales. Oil production from the other 100+ global oil producers also represents about ~42 MMb/d, but on balance has been slowly eroding since 2010, failing to grow even when oil prices were $100+/bbl. Despite some 2017 recovery from Libya, we expect total production to continue to fall in both 2017 and 2018. The few recently expanding producers among the Other Guys are running out of growth. Canada, Brazil, North Sea and GOM account for ~13 MMb/d of oil production in 2016, adding ~1.5 MMb/d over the past three years (2014-2016). North Sea production is projected to resume declines starting in 2017; GOM will reach it peak production sometime in 2017 or 2018, then start to ebb; large new Canadian oil sands projects will add ~310k b/d in 2017-2018, but scarce additions are scheduled beyond that; and Brazil's once-lofty growth plans have slowed to a crawl in 2016-2018. Global deepwater drilling activity and exploration spending have collapsed, lowering the reserve base, and undermining the stability of current production levels. Outside Of Just Three Regions, Oil Supply Picture Looks Worrisome Often overlooked in our discussions about world oil markets are the supply contributions of over 100 geographic regions. This collection of suppliers (which we will call the "Other Guys") is defined as all producing regions in the world other than: 1) U.S. Onshore (shales, specifically), 2) OPEC's six Middle East members, and 3) Russia. The Other Guys deliver nearly half of global production, try to maximize production every day (even OPEC nations among the Other Guys have not had production constrained by quotas), and still have endured consistent, albeit modest, production declines over the past six years. Chart 1Outside Of A Very Few Regions,##BR##Oil Production Has Struggled At the end of 1Q17, oilfield-services leader Schlumberger voiced sharp concerns regarding stability of supplies from these ignored producers, warning that aggregate capital expenditures within these regions will sustain an unprecedented third straight year of decline in 2017, with total spending only about half of 2014 levels. Chart 1 shows the divergent production histories of the three growing regions versus the rest of the world. Chart 1 also shows production of the Other Guys excluding the especially dramatic declines/volatility of Libyan production. Even though these producers benefitted from the same incentives and profitability from high oil prices as the three growing regions, as a group, they have been unable to expand production. As oil prices have plunged, drilling activity in these nations has also plummeted, raising concerns that production declines could start accelerating in the near future. Chart 2 shows that oil-directed drilling activity among the international components of the Other Guys (Chart 2 excludes GOM and highly-seasonal Alaska and Canada) has crashed by ~40%, from an average of over 800 rigs during the five-year period of 2010-2014 to under 500 rigs for the past year. Offshore drilling has collapsed even a little more sharply for these producers than overall oil-directed drilling, falling ~43% from an average of over 280 rigs to only 160 today (Chart 3, excludes GOM). Chart 2Other Guys' Drilling##BR##Has Collapsed 40% Chart 3International Offshore Drilling Is Down Over 40%,##BR##Boding Poorly For The Stability Of Future Production Offshore Production Declines To Accelerate Chart 4Other Guys' Offshore Drilling Has Collapsed As a particularly worrisome trend for the Other Guys' production stability, offshore drilling activity has collapsed in some of the most important offshore oil producing regions in the world, including the GOM, North Sea, West Africa, and Brazil (Chart 4). Considering the multi-year lag between drilling activity and the start of oil production, and the large well size and quick declines associated with offshore wells, the oil production impacts of this drilling collapse that started two years ago have not really been felt yet. When these regions get past the wave of new production from 2015-2017 project additions (projects started during 2011-2014), they will face a dearth of new projects maturing in 2018-2022 due to this collapse in drilling, with new production likely to be inadequate to offset the declines of legacy production. Brazil, the North Sea, West Africa, and GOM together account for about 12 MMb/d of oil production (Chart 5). These four offshore regions have benefitted from intense investment from 2010-2015 as shown by the surging rig counts during that period in Chart 4. This investment/drilling drove 1.1 MMb/d of oil production growth in Brazil, the GOM, and the North Sea from 2013 to 2016, without which total production from the Other Guys would have declined by 1.4 MMb/d rather than just 0.3 MMb/d. Despite strong investment, production in West Africa merely held flat outside of Nigeria during 2013-2016 while falling by 0.4 MMb/d within Nigeria (mostly in 2016 due to pipeline disruptions from saboteurs). Chart 5Offshore Production Will Stop Expanding, Then Decline Brazil offshore drilling activity over the past year is less than half of levels during 2010-2013. As a result, production growth will moderate significantly over the next few years, expanding far less (250k b/d in 2018 vs. 2016, based on our balances data) than the rapid 470,000 b/d step-up in production during 2013-2014. While Brazil still has a rich endowment of pre-salt reserves, marshalling capital and the International Oil Companies' (IOCs) focus to resurrect development activity will take years. We expect no growth during 2019-2020. The North Sea has seen production cut in half from the time of peak production in 1999 until 2013. Production declines were briefly halted and re-expanded by ~300,000 b/d during 2014-2016 due to a concerted drilling effort and brownfield maintenance program incentivized and financed by $100/bbl oil prices. Drilling has since declined 35% from average 2010-2014 levels, and production is expected to resume its downward trend in 2017-2018. Overall oil-directed offshore drilling in the GOM has been cut by over 50% from 2013-2014 levels. Based on our field-by-field analysis published in January, we estimate GOM oil production will hit a peak in a year and a half or less and then will succumb to declines due to lack of new drilling. West Africa has suffered production declines for the past several years due to both geologic challenges as well as more recent (2016-2017) political/sabotage related disruptions in Nigeria. With offshore drilling activity plummeting 70%-80%, we expect production declines will accelerate and it will take years of increased drilling to yield new production that can stem the declines. The collapse in Nigerian drilling, from 10 rigs in 2010-2013 to only 2-3 rigs over the past year, likely means that Nigerian production is incapable of returning to 2015 levels even if its recent sabotage issues are resolved. In aggregate, as shown in Chart 5, we expect production from these four offshore regions to stagnate during 2017-2018 (North Sea and West Africa decline while Brazil and GOM expand) before declining by ~0.5 MMb/d in each 2019-2020 due to the dramatic curtailment of investment during 2015-2017. SLB Talks Its Book, But Makes A Strong Point At an industry conference at the end of March, Schlumberger (again) railed against the inadequacy of the cash flow-negative U.S. shale industry to single-handedly supply enough production growth to satisfy continuing global demand growth, especially once the Other Guys start seeing more pronounced negative production effects from the sharply reduced investments over 2015-2017. "The 2017 E&P spend for this part of the global production base...is expected to be down 50% compared to 2014. At no other time in the past 50 years has our industry experienced cuts of this magnitude and this duration." - Paal Kibsgaard, CEO of SLB. SLB highlighted an analysis of depletion rates constructed with data from Energy Aspects. (The March 27 presentation can be found at www.slb.com). Annual depletion rates (annual production/proved developed reserves) in the GOM had spiked to over 20% in 2016 from a long-term level of only ~10% during 2000-2013. Similarly, depletion rates in the U.K. and Norwegian sectors of the North Sea also surged from ~10% to ~15% over the past three years. In both the GOM and the North Sea, oil production had recently been expanded, but proved developed reserves declined. Due to such low drilling investments during 2015-2016, producers have replaced only about half of the oil reserves that they've produced in the GOM and North Sea over the past three years (2014-2016). Eventually, this lack of investment in cultivating tomorrow's resources will catch up to the industry, and production will decline. Investors must take SLB's commentary with a grain of salt, as they could be construed as sour grapes. The immense pull of new capital spending to the U.S. shales has substantially benefitted SLB's primary competitors more than it has benefitted SLB (SLB is much more focused on international and offshore projects). Still, investors are too complacent about the stability of non-U.S. production. SLB's analysis and warnings of accelerating production declines should not be ignored. Bottom Line: Outside of the three regions of sharply growing production (U.S. onshore, ME OPEC and Russia) that investors are focused on, the other half of global production has been stagnant to declining despite high oil prices and high levels of drilling during 2010-2015. Now that drilling and capex in these regions has declined by 40%-50%, production declines should accelerate in coming years. Offshore production, especially, has not seen enough drilling to replace reserves, and is poised to decline within the next 2-3 years. The accelerating declines of the "Other Guys" will allow more room for growth from U.S. shales, ME OPEC and Russia. Matt Conlan, Senior Vice President, Energy Sector Strategy mattconlan@bcaresearchny.com 1 Please see "China steel hits nine-week peak amid crackdown, lifts iron ore," published by reuters.com May 22, 2017. 2 Please see the feature article in last week's edition of BCA Research's Foreign Exchange Strategy entitled "Bloody Potomac," in which our colleague Mathieu Savary lays out the case for an imminent USD rebound. Investment Views and Themes Recommendations Strategic Recommendations Tactical Trades Commodity Prices and Plays Reference Table Trades Closed In 2017 Summary of Trades Closed in 2016
Highlights The U.S. dollar will continue to appreciate while the RMB will depreciate further. This is a bad omen for EM risk assets, commodities, and global late cyclical equity sectors. Gold often leads oil and copper prices. Investors should heed the current downbeat message from gold. EM credit spreads have become detached from fundamentals and are unreasonably tight. Continue overweighting the Indian bourse within an EM equity portfolio. A new equity trade: long Indian software stocks / short the EM overall index. Feature There are several major discrepancies in financial markets that in our view are unsustainable. 1. The gap between EM equity breadth, USD, RMB and EM share prices One way to measure equity market breadth is to compare performance of equal-weighted versus market cap-weighted stock price indexes. Based on this measure, EM stock market breadth has been deteriorating. Poor breadth often heralds a major selloff (Chart I-1). Chart I-1Poor EM Equity Breadth Heralds A Major Selloff Remarkably, the same measure for the U.S. stock market shows improving breadth. The relative performance of equally-weighted EM stocks against U.S. equity indexes - a measure of breadth in relative performance - can also be a reliable marker for the relative performance of market cap-weighted indexes. It has plummeted to a new low pointing to new lows in EM versus U.S. relative share prices. In addition, a surging U.S. dollar has historically meant lower EM share prices (Chart I-2). We doubt this time is different. Finally, EM risk assets have decoupled from the RMB/USD exchange rate as well. The RMB has been depreciating and China's domestic corporate and government bond yields have spiked. As a result, the on-shore bond prices in RMB terms have plummeted (Chart I-3). Chart I-2A Rising U.S. Dollar Is ##br##A Bad Omen For EM Chart I-3China's On-Shore Corporate Bond##br## Prices Have Crashed Experiencing considerable losses on their favorite financial investment of the past year, bonds, Chinese investors, as well as households and companies, could opt to switch into U.S. dollars. The stampede into the U.S. dollar could start as early as January when the annual US$ 50,000 quota per person becomes available. It is hard to see what the government will do to preclude this rush and massive flight towards U.S. dollars. In China, households' and corporates' RMB deposits in the banking system amount to RMB 122 tn or US$17.5 tn. Hence, the PBoC's foreign exchange reserves including gold at US$ 3.2 tn are only equal to 18.5% of these deposits at the current exchange rate. Bottom Line: The U.S. dollar will appreciate and the RMB will depreciate. This is a bad omen for EM share prices and other risk assets. 2. Oil and copper prices deviating from gold prices Historically, when gold and oil prices have diverged, gold in most cases has proven more forward looking, with oil prices ultimately converging toward gold prices. Chart I-4A and Chart I-4B illustrate past episodes of gold and oil decoupling (in the 1980, 1990s and 2008), each of which were resolved via oil prices gravitating toward gold prices. Chart I-4AGold Led Oil Prices Chart I-4BGold Led Oil Prices In short, if history is any guide, the current gap between gold and oil prices will likely close via lower oil prices (Chart I-5, top panel). The same holds true for the recent divergence between gold and copper prices (Chart 5, bottom panel). We identified four historical periods when gold and copper prices diverged. In each case, it was copper prices that amended their trajectory and aligned with the direction of gold prices (Chart I-6A and 6B). Chart I-5Divergence Between Oil, Copper And Gold Chart I-6AGold Led Copper Prices Too Chart I-6BGold Led Copper Prices Too In sum, historically there have been a number of episodes when gold has led both oil and copper prices. Investors should heed the current downbeat message from gold. Chart I-7China: Dichotomies The underlying rationale could be that gold responds to monetary/liquidity conditions (gold is very sensitive to U.S. TIPS (real) yields) while oil and copper are more sensitive to growth conditions. Tightening in monetary/liquidity conditions often precedes a growth relapse. This could be the reason why gold has led oil and copper prices on several occasions in the past. 3. Dichotomies in China's industrial economy There are two types of dichotomies underway within China's industrial economy: The first is between industrial activity and industrial commodities prices. Commodities prices have surged, but the pace of manufacturing production has not improved at all (Chart I-7). There have been major discrepancies among various segments of China's industrial economy, with utilities surging and the technology sector remaining robust, and many others stagnating. The decoupling between industrial activity and industrial commodities prices can be explained by financial speculation and supply cutbacks. The former is unsustainable, while the latter is reversing as the government is gradually lifting restrictions on supply for coal and steel. The second is between the private- and state-owned parts of the industrial sector. The state-owned segment has experienced a meaningful improvement in output, while private companies in the industrial sector have seen their output growth weaken, albeit the growth rate is higher than in the SOE sector. (Chart I-7, bottom panel). As China's fiscal and credit impulses wane,1 activity in the state-owned industrial segment will relapse anew. 4. EM credit spreads diverging from EM currencies and credit fundamentals EM sovereign and corporate credit spreads (credit markets) are once again proving very resilient, despite the renewed selloff in EM currencies (Chart I-8). EM credit markets have defied deteriorating EM credit fundamentals in the past several years. Below we identify several divergences and anomalies within the EM credit space that give us confidence that EM credit markets have become detached from fundamentals, and that their risk-reward profile is poor. Chart I-8EM Credit Markets And EM Currencies:##br## A Widening Dichotomy Chart I-9EM Corporate Financial Health:##br## Not Much Improvement The EM Corporate Financial Health (CFH) Indicator has stabilized, but remains at a very depressed level (Chart I-9, top panel). This amelioration is largely due to the profit margin component. The other three components have not improved (Chart I-9, second panel). The valuation model based on the EM CFH indicator shows that EM corporate spreads are far too tight (Chart I-10). Chart I-10EM Corporate Bonds Are Expensive The strong performance of EM credit markets in recent years has been justified by the persistence of low bond yields in developed markets (DM). Yet the latest spike in DM bond yields has so far not caused EM credit spreads to widen. We expect U.S./DM government bond yields to rise further, and the U.S. dollar to continue to strengthen. This, along with potential broad-based declines in commodities prices, should lead to material widening in EM sovereign and corporate credit spreads in early 2017. With respect to unsustainable discrepancies, the case in point is Brazil. The country's sovereign and corporate spreads have tightened a lot this year, even though economic activity continues to shrink. The country has had numerous boom-bust cycles in the past 100 years, yet this depression is the worst on record. In fact, the nation's economic growth and public debt dynamics are worse than at any time during the past 20 years. Yet, at 300 basis points, sovereign spreads are well below the 1000-2500 basis point trading range that prevailed in the second half of 1990s and early 2000s (Chart I-11). Remarkably, the economy's pace of contraction has lately intensified (Chart I-12). This will likely worsen government revenues and lead to further widening in the fiscal deficit - making debt dynamics unsustainable. Another absurd credit market divergence is between China's sovereign CDS and Chinese offshore corporate spreads. Sovereign CDS spreads have been widening, but corporate credit spreads remain very tight (Chart I-13). Chart I-11Brazil: Dichotomy Between Sovereign ##br##Spreads And Fundamentals Chart I-12Brazil's Economy: ##br##No Improvement At All Chart I-13Chinese Sovereign CDS And ##br##Off-Shore Corporate Spreads Yet there is much more risk in Chinese corporates than in government debt. The corporate sector commands record leverage of 165% of national GDP, while public debt stands at 46% of GDP. Besides, the central government in China will always have immediate access to domestic or foreign debt markets, while some corporations could lose access to financing if creditors question their creditworthiness and decide to tighten credit. There is no rational case to support the rise in sovereign CDS when corporate spreads are tame. The only feasible explanation is that investors - who are invested in Chinese corporate bonds, and are not interested in selling them - are buying sovereign CDS to tactically hedge their credit exposure. If and when market sentiment sours sufficiently, and credit spread widening is perceived durable and lasting, real money will sell corporate bonds, resulting in a major spike in corporate spreads. 5. Divergence between global late cyclicals and the U.S. dollar Another area where we detect that financial markets have lately become overly optimistic is in global late cyclicals - materials, machinery and energy stocks. Typically, the absolute share prices in these sectors correlate with the U.S. dollar exchange rate but they have lately diverged (Chart I-14). Furthermore, global machinery stocks in general, and Caterpillar's share price in particular, have lately staged significant gains, while their EPS and sales continue to plunge (Chart I-15). Notably, Caterpillar's sales have not improved, even on a rate-of-change basis. Chart I-14Global Late Cyclicals And The U.S. Dollar: ##br##Unsustainable Decoupling Chart I-15Global Machinery Sales And##br## Profits Continue Plunging EM including China capital spending in real terms is as large as the U.S. and EU capital spending combined (Chart I-16). If the EM and China capex cycle does not post a recovery, which is our baseline view, it will be hard for global late cyclical stocks to continue rallying based solely on the positive outlook for U.S. infrastructure spending and potential U.S. tax reforms. In short, global late cyclicals such as machinery, materials and energy stocks that performed quite well in 2016 are vulnerable to a major pullback as EM/Chinese capital spending disappoints on the back of credit growth deceleration. Notably, these global equity sectors have reached a major technical resistance that will likely become a ceiling for their share prices (Chart I-17). Chart I-16EM/China's Capex Is As Large As ##br##U.S. And Euro Area Combined Chart I-17Global Late Cyclicals Are ##br##Facing Technical Resistance 6. Decoupling between the South African rand and precious metals prices The South African rand's recent resilience - despite the considerable drop in precious metal prices - is unprecedented (Chart I-18, top panel). Similarly, the rand has also decoupled from the exchange rate of another major metals producer: Australia (Chart I-18, bottom panel). We cannot think of any reason why these discrepancies can or should persist. Rising global bond yields and a broadening selloff in commodities prices should hurt the rand. In fact, the trade-weighted rand is facing a major technical resistance (Chart I-19) and will likely relapse sooner than later. Chart I-18Rand, AUD And ##br##Precious Metals Chart I-19Trade-Weighted Rand Is ##br##Facing Technical Resistance We reiterate our structural short position in the rand versus the U.S. dollar, and on October 12, 2016 initiated a short ZAR / long MXN trade. Traders should consider putting on these trades. Investment Strategy Chart I-20EM Relative Equity Performance ##br##Is Heading To New Lows Emerging markets share prices and currencies have been doing poorly since October, despite U.S. equity shares breaking out to new highs. In fact, almost all relative outperformance has been wiped out (Chart I-20). BCA's Emerging Markets Strategy team expects further declines in EM share prices and currencies, as well as a selloff in domestic bonds and a widening of sovereign and corporate spreads. Absolute return investors should stay put, while asset allocators should maintain underweight positions in EM risk assets within respective global portfolios. Arthur Budaghyan, Senior Vice President Emerging Markets Strategy arthurb@bcaresearch.com India: Demonetization And Opportunities In Equities On November 8, India launched a demonetization program with the goal of removing the two most used banknotes - the 500 INR and 1000 INR banknotes - from circulation. Both banknotes accounted for roughly 85% of currency in circulation, which itself accounts for 13% of India's broad money supply. Moreover, almost 90%2 of retail transactions in India are cash-reliant. While around INR 13 trillion of notes (US$ 190 billion) have been deposited in the banking system as of December 10, only INR 5 trillion of new notes have been issued by the Reserve Bank of India (RBI). India is unlikely to turn cashless overnight. According to a Harvard Business Review article,3 less than 10% of Indians have ever used non-cash payment instruments. Likewise, less than 2% of Indians have used a cellular phone to receive a payment. This implies cash shortages could persist for a while and will have a significant impact on short-term economic activity. There are numerous reports that layoffs and business shutdowns have ensued in several industries, particularly in the informal economy (Chart II-1). The service sector PMI already dipped below 50 in November and the manufacturing PMI fell as well (Chart II-2). Chart II-1Very Weak Employment Outlook Chart II-2Indian PMIs Are Sinking Having boomed over the past year, motorcycle sales growth is now waning. Similarly, passenger and commercial vehicle sales - that have been anemic - will now dip. However, the consumption slowdown should not continue beyond the next couple of months. As more currency is supplied by the RBI, economic activity will rebound - particularly household spending. Pent-up demand will be unleashed as money circulation is restored. Nevertheless, investment expenditures are the key factors for improving productivity and, hence, as non-inflationary growth potential. Capital spending had been anemic in India well before the demonetization program was announced (Chart II-3). The reason for such lackluster investment expenditure lies in the fact that past investment projects taken on by highly leveraged Indian conglomerates have delivered poor performance. This translated into ever rising non-performing loans (NPLs) at state banks. Without debt restructuring and public bank recapitalization, a new capex cycle is unlikely in India. Consistently, credit to large industries is now contracting (Chart II-4) and foreign lending to Indian companies is declining. Chart II-3Indian Capex Is Anemic Chart II-4Banks Prefer Consumers We expect the demonetization program to hurt capital spending only mildly in the coming months, but do not expect a material bounce in investment afterward, unlike the one slated for household consumption. Indian share prices have more downside in absolute terms, as the market is still expensive and growth is slumping. Nevertheless, India will likely outperform the EM equity benchmark going forward (Chart II-5). Chart II-5Indian Share Prices: A Tapering Wedge The rationale for our overweight on Indian equities within the EM stock universe is due to the nation's much better macro fundamentals relative to those in many other EM. In particular, deleveraging and NPL write-offs are more advanced, the current account deficit is small, and India will benefit from potentially lower commodities prices. Within the Indian bourse, we recommend overweighting software stocks that will benefit from a revival in advanced economies' growth and a weaker currency. Besides, Indian software stocks are not exposed to the currently weak domestic consumption cycle and in fact might benefit from the push toward digitalization in banking. Bottom Line: Indian consumption will weaken in the coming three months or so, but will rebound thereafter. The capex cycle is weak and will remain subdued. Continue overweighting the Indian bourse within an EM equity portfolio. A new equity recommendation: long Indian software stocks / short the EM overall index. Ayman Kawtharani, Research Analyst aymank@bcaresearch.com Arthur Budaghyan, Senior Vice President Emerging Markets Strategy arthurb@bcaresearch.com 1 Please refer to the Emerging Markets Strategy Weekly Report, titled "Key EM Issues Going Into 2017," dated December 14, 2016, available at ems.bcaresearch.com 2 Chakravorti, B., Mazzotta, B., Bijapurkar, R., Shukla, R., Ramesha, K., Bapat, D., &Roy, D. (2013). The cost of cash in India. Institute of Business in the Global Context, Fletcher School, Tufts University. 3 Chakravorti, B. (2016, December 14). India's Botched War on Cash. Retrieved from https://hbr.org Equity Recommendations Fixed-Income, Credit And Currency Recommendations
Hillary Clinton has a 65% chance of winning the election; she receives 334 electoral college votes according to our model. Trump still requires an exogenous shock to win. Meanwhile, the USD is poised to rally - and leftward-moving policymakers will applaud its redistributive effects while MNCs suffer the consequences.
The U.S. dollar's corrective/consolidation phase is over, and it is about to rally. The risk-reward for EM stocks and currencies is extremely unattractive. We are reiterating our recommendation to short a basket of ZAR, BRL, TRY, MYR, IDR and CLP versus the U.S. dollar. There is a value opportunity in the Mexican peso. Go long MXN versus ZAR. Also, double down on the long MXN / short BRL trade.
India's agricultural output per capita has not increased at all. Thus, food and headline inflation will remain structurally high, which will negatively impact savings and investment dynamics in the years ahead. With respect to cyclical growth, household spending is very strong, but investment expenditures are stagnant. Fixed-income traders should bet on yield curve steepening in India. A section <i>Brazil's Business Cycle Illustrated</i> highlights the cyclical profile of this economy.
In a February <i>Special Report</i> titled "Assessing Fair Value In FX Markets" we introduced a set of long-term valuation models based on various fundamentals. We have updated the results and added KRW, INR, PHP, HKD, CLP and COP to our analysis. The dollar still remains expensive, albeit with no signs of a dangerous overvaluation. The yuan is now at its cheapest level since 2009.
The median voter moving to the left has spurred paradigm shifts. These new regimes are giving way to transformational leaders who seek change by breaking convention. As they test their constraints and pursue their preferences, a cautious stance towards risk assets is warranted. In this Monthly Report, BCA's Geopolitical Strategy discusses Trump's recent comeback, rising EM political risk, and Italy's upcoming constitutional referendum.