April 13, 2024

BHPs economic and commodity outlook


London Metal Exchange (LME) nickel prices ranged from $15,885/t to $22,355/t over the first half of financial year 2024, averaging $18,808/t. The average is –22% versus the prior half, –20% from the corresponding half of FY23, and –46% YoY on an end–of–period basis. 

How did such a large movement in price occur in such a short time period, with so little apparent warning? A survey of twenty private-sector forecasters published in January 202426 was predicting the nickel price would average a little over $19000/t in calendar 2024 with the price path remaining relatively stable above their mean long run real price estimate for the entire period from 2024 to 2027. The Australian Commonwealth Government’s decision to classify nickel as a “critical mineral” on February 16, 202427, something it chose not to do in an updated list published December 16, 202328, speaks to the speed of the deterioration in industry conditions. 

Like most cliff events, while it felt abrupt, the series of developments that led up to it were widely known and commented on, such as excessive Class-II and intermediates supply growth from Indonesia, extreme discounts to LME pricing for non-Class-I nickel products in the physical trade in Asia, and the LME’s impaired price discovery mechanism painting it into a corner on exchange liquidity. What was lacking prior to the last half year was that there was no bridge to bring the mostly distinct Class-I and “other” supply buckets together, thereby triggering the potentially negative price dynamics. 

When a potential bridge appeared via the conversion of a portion of the glut of Indonesian-origin nickel products into nickel cathode, enabled by the LME’s fast-track decision to allow this product to move onto its system, that turned the hypothetical into a reality. That brought the Class-II and intermediates surplus directly into line of sight of the broadly balanced Class-I trade, just as destocking in the battery value chain and weakness in OECD demand for stainless steel made the industry especially vulnerable to such a shift. A very sharp correction in prices ensued. 

While the supply glut was still contained mainly in the Class-II segment of the industry, operating conditions for integrated sulphide businesses, globally, remained solid. However, since the LME began to take delivery of Sino-Indonesian nickel cathode to its warehouses, thus catalysing price convergence between product classes, loss-making has become widespread. 

If the LME nickel price is set to $16000/t, close to the spot price in mid-February, as much as one-half of global production could be loss-making on a cash plus sustaining capex basis.29 Producers adopting more sustainable practices could be disadvantaged in this environment, with their efforts not yet recognised with a commercial premia that could help buffer profitability when the base price declines to cyclical lows. 

At a very high level, that is how we got here. Due to the deterioration in the short-term and medium-term outlook for nickel, we have lowered our nickel price assumptions. In addition, capital costs for Western Australia Nickel have increased due to inflation. BHP has undertaken a carrying value assessment of Western Australia Nickel having regard to these factors and will recognise an impairment as at 31 December 2023 .

The following tells the story of that deterioration in more detail. 

The refined nickel balance flipped from a large deficit in calendar 2021 to an aggregate surplus of material size across calendar 2022, and as highlighted in this article series six months ago, the glut increased in the first half of calendar 2023. Notwithstanding the substantial unwinding of calendar 2022 fly–up pricing levels that had occurred at that point, and the collapse in payables for nickel products in China, the Class–I sub–balance was still on a relatively even keel at this stage, keeping exchange stocks at very low levels (–44% YoY) . However, the directional risk for LME prices was skewing lower at that point, with a multi–year run of aggregate nickel unit surpluses likely and “bridges” between the Class–I, Class–II and higher–nickel intermediate “islands” being actively developed in the Sino–Indonesian industrial complex (50–60kt of Sino–Indonesian cathode was already online at mid–year). With the stainless steel demand backdrop in the developed world weakening as expected, and aggressive destocking in the battery value chain almost neutralising still strong electric vehicle (EV) sales globally (producing a much weaker outcome for nickel in batteries than our expectations), the LME nickel price slumped in the second half of calendar 2023. A series of curtailments were publicly announced, beginning in December 2023. Low inventories were an important element of the industry story prior to the arrival of Sino-Indonesian cathode into LME warehouses, but this narrative quickly evaporated. Visible inventories ended December 2023 up +26% YoY. 

While short-term inventory swings and the negative impact on durable goods demand of anti-inflationary policies in the West have played a part in the recent price movement, the key strategic dynamic here has been on the supply side of the industry. There have been four consecutive years of rampant growth in Class–II production from 2020–2023 (with net growth in Chinese and Indonesian nickel–pig–iron [NPI] up around 1.6 times versus 2019, with the Indonesian standalone component up 3.6 times). This has been accompanied by stunning growth in intermediates from a standing start in Indonesia: NPI–to–matte production (~75% nickel contained) increased from 3 kt in calendar 2021 to an estimated 180 kt in 2023; while mixed–hydroxide precipitate (MHP: 30–45% nickel contained) rose from 16 kt in 2021 to an estimated 154 kt in 2023.30 In calendar 2023, this vertical uplift in supply across the product spectrum intersected with a weak year for stainless steel in the ex–China world (stainless still provides 65% of total first–use), and a global demand speedbump in the battery space (of which more below), leaving a considerable glut of nickel units smeared across all product classes. 

Taking a step back to consider the underlying fundamental drivers of the supply impulse, we note that Wood Mackenzie’s long term Indonesian nickel production forecast has been increased by more than +200% between late–2019 and late–2023. Wood Mackenzie utilises a methodological framework for project assessment based on the kind of hurdle rates of return that a listed Western producer would be familiar with. Consequently, they have been continually surprised when Indonesian projects kept coming forward. These projects were also being delivered at significantly lower costs (and ramping up to nameplate more smoothly) than was thought likely just a few short years ago. Clearly capital has been committed in the Sino–Indonesian nickel complex based on very different return parameters to those that underpin shareholder expectations of capital allocation processes in the West , and/or more optimistic input assumptions are being used in this particular ecosystem, and/or non–commercial imperatives such as security of supply for strategic downstream industries are carrying the day.

Whatever combination of the above you favour, the reality is that this avalanche of operating and committed supply has left the overall industry highly vulnerable to any sort of demand disappointment, such as we saw in calendar 2023. 

From here, we assess that demand needs to track close to the upper end of the plausible range to justify this breakneck expansion and to restore profitability across the supply curve within the decade’s middle third. If demand instead tracks the middle of the plausible range, we estimate that the market may not re-balance before the late-2020s. In this case, prior to that, a multi-year run of surpluses is in prospect. 

These conditions, brought about by excessive investment, have created financial stress across the global industry. As already mentioned, several producers having publicly announced curtailments in response, including multiple operations in Western Australia. These announcements are included in the supply-demand scenarios described in broad brush strokes above. The negative price shock has occurred at a time when Australia’s international competitiveness is at a low ebb in commodity sectors where the geological endowment does not provide an absolute advantage: a group that includes nickel. High general labour costs, ageing mines and processing facilities, a considerable regulatory burden, skill shortages, and economy–wide productivity outcomes that are historically poor, are increasing the distance between the general Australian cost base and business environment and that of some key competitors in the critical minerals sphere. Decisive action is needed to reinstate the durable competitiveness of the industry. Otherwise, Australia and those nations looking to Australia to boost the supply of more sustainably produced future-facing commodities like nickel, may be further disadvantaged. We will return to the theme of sustainability, and ways to remunerate its tangible value, below. 

Switching now to the demand side of the equation, generalist observers have been surprised by the apparent paradox of strong global EV sales (around 40% YoY) in calendar 2023 and the profound slump in the price of key battery metals, such as nickel and lithium. The nickel price declines have been hugely painful, but they pale when compared to the Chinese spot lithium carbonate price slumping –85% from its peak. A vicious bout of mid-and downstream destocking has amplified the weakness in the upstream. 

For nickel specifically, we estimate that destocking – the process whereby demand is met by carry–over stock from prior production periods, contributed to approximately 100 kt of ‘demand loss’ across calendar 2023.

Global nickel battery installation is estimated to have grown by +28% YoY in calendar 2023 (China +14% YoY even with more LFP (lithium–iron–phosphate) batteries and plug–in hybrids gaining ground in colder regions), but global nickel cathode output (in gross tonnage) barely gained ground over the year. We expect end–user (battery cathode–active–materials – CAM) stocks to have declined further in January to February 2024, including some additional ‘passive destocking’ due to the Red Sea logistical disruptions. The good news is that inventory swings are not perpetual, and at some stage in calendar 2024 we are likely to see a flip towards restocking, and the gale force drag of calendar 2023 will turn to a tailwind (of uncertain force). Alongside the supply-side developments discussed above and a modestly firmer industrial economy across the OECD, these factors feed our expectation that the nickel industry’s currently bloated surplus (equivalent to 13% of total demand in calendar 2023) could reduce in size in calendar 2024 and 2025. The bad news is that smaller does not mean small in absolute terms. We estimate that the average surplus across 2022–2025 will easily exceed 200 kt. As a rough guide, 250 kt is equivalent to about 8% of calendar 2023 demand. Difficult operating conditions are expected to endure for years to come. 

As discussed above, the mechanism that transmitted the Class–II and intermediate glut into the Class–I sub–segment was the conversion of over–supplied non–Class–I products into cathode, and the delivery of these cathodes to LME warehouses. This brought previously invisible nickel units into the harsh glare of the investor community. Huayou was the first Sino–Indonesian operator to apply for brand listing under the LME’s new “fast track” approvals process. They have since been followed by GEM and CNGR, with China likely to become a net exporter of nickel cathode in the near future.  

Diversifying sources of deliverable metal to the LME exchange by fast tracking Sino-Indonesian nickel cathode was an attempted solution to the institution’s liquidity problem, arguably without due consideration for unintended consequences.

Not only did these expedited approvals contribute to the rapid drop in the LME price as Class-I pricing converged with the over-supplied Class-II and intermediates spaces, the pain of which is being felt across the established Class-I producer universe, this new Class–I product begs some important questions for the nickel industry. The first are the potential consequences of the fact that the new Class–I supply is going to come in the form of cathodes . Cathodes are traditionally used in stainless steel and are not particularly suited to the rapidly growing lithium–ion battery sector. If Sino-Indonesian cathodes do not prove to be fully fungible with other Class-I products from the perspective of the battery value chain, then there is potential for a material bifurcation within the LME Class–I products space . Bifurcation driven by questionable fungibility in real demand, for which we have a recent analogy with respect to Russian Class-I nickel products, and the hoped-for durable uplift in liquidity, may not go together. 

The second question is that fast track approvals of new products where the majority of feedstock will come from Indonesia, where an increasingly well–known range of ESG and responsible sourcing challenges currently exist31,asks important questions about how fit-for-purpose the policy on Responsible Sourcing of LME-Listed Brands is. The LME’s current policy towards responsible sourcing is narrowly defined, limiting its scope to certain risks both at the point of production which is typically the refinery (health & safety and environmental management system standards focussed) and to due diligence with the upstream metals supply chain (human rights, conflict and financial crimes focussed). Critical ESG risks such as biodiversity, Indigenous rights, tailings, GHG emissions profile and environmental due diligence are not in scope. Standards elsewhere in the ecosystem (for example the relevant OECD Guidelines, Copper Mark, and EU battery regulations) have leapfrogged the LME’s approach, encompassing broader definitions that are more demanding of companies and more reflective of global sustainability best practice. 

To modernise the LME policy and address existing shortcomings we recommend the following: 

  1. Define a single Conflict Affected and High-Risk Area (CAHRA) listing that is made publicly available, kept up-to-date and adopted consistently by all LME Brands.
  2. Expand the scope of upstream due diligence requirements to cover environmental risks in line with the OECD’s Handbook on Environmental Due Diligence in Mineral Supply Chains, and include recycled materials.
  3. Ensure all upstream production, including all mining and processing that act as third-party feed in the production of any LME Brand, are independently assured against a recognised ESG performance standard (e.g. ICMM’s Mining Principles, Towards Sustainable Mining [TSM], Copper Mark) with a clearly defined minimum performance threshold by standard.

Such reforms would likely bring more comfort to downstream metal customers that position themselves as ESG industry leaders to speak to the higher standards of sustainability of their supply chain with more conviction. Presumably they are aware of these fundamental points of difference between traditional sources of LME deliverable Class-I nickel, and cathodes converted from Indonesia origin material. Nickel users in the midstream and downstream are a sophisticated group. Yet they are also pragmatists who want their feedstocks to be as cost effective as possible as they seek to compete in low-margin processing or manufacturing industries. With the influx of Indonesian origin nickel flowing directly and indirectly into western EVs over the last few years, including trade in intermediate products over the last twelve months, it is obvious that pragmatism is winning out. 

We argue that adopting the reforms proposed above would help the LME (and/or other competing organisations) grasp the opportunity created by the actual and potential flurry of new sources of nickel, to increase the transparency for both buyers of metal and ultimate consumers of nickel-containing products as to the heterogeneous GHG emissions intensities and other relevant ESG characteristics that are deemed valuable by discerning purchasers but are currently outside the LME Policy on Responsible Sourcing of LME-listed Brands. Simultaneously, exchanges can explore options to develop nickel market infrastructure that can explicitly incorporate such characteristics as premia and discounts to the base price (i.e. placing tangible value on relative GHG emissions intensity and independent assurance against credible responsible mining and processing standards which incorporate broader ESG risks such as biodiversity, human rights and tailings). We also note in this regard that entrepreneurial interest in alternative nickel pricing solutions has been growing, such as Global Commodities Holdings’ spot trading platform for the physical delivery of Class–I nickel, and Abaxx’s development efforts towards a nickel sulphate price. BHP is monitoring all these developments, and we are engaging constructively with the broader ecosystem to try to help build a more transparent, efficient, and robustly independent pricing mechanism for this critical mineral – in its many traded forms. 

Yet the responsibility for getting this right should not rest solely with private exchanges and leading producers. There are other important players in the ecosystem, not the least of whom are policymakers in the world’s major ex–China manufacturing centres. Arguably the two most influential pieces of legislation in the climate arena are the US’ Inflation Reduction Act (IRA) and Europe’s carbon border adjustment mechanism (CBAM). Neither make it any easier for more sustainable nickel producers to procure a premium for their efforts. The scope of the CBAM is not yet broad enough to encompass trade in nickel products prior to what we call “first–use”, and therefore a nickel–matte product from Indonesia is theoretically treated in the same fashion as a product from Canada or Australia.

The IRA differentiates between where nickel is produced, but not how it is produced. The IRA also treats all battery metals as a basket of value–added, rather than as standalone commodities, which is overly complex for the private sector. It also makes it more difficult to overlay sustainability criteria in addition to point of origin.

Why is this too complex? Principally because a change in relative prices can swing a procurement strategy that was eligible for subsidy in the prior year to be ineligible in the coming year. Note the dramatic collapse in lithium prices referenced above. If a downstream firm was relying on the value of lithium from Western Australia remaining broadly steady to achieve the threshold, for example, they would be unlikely to be able to reconstruct their supply chain in time to remain eligible for subsidies. That seems to defeat the intent of the policy, which is to increase the US’ security of supply of critical minerals in this strategic emerging sector and hasten the penetration of “clean” energy technology (as labelled and defined by the US government) downstream. 

If the framework was instead based on individual metals, with volume-based sourcing thresholds calibrated to the realities of the individual industries, it would simplify the policy, remove the price–linkage flaw, and make it more targeted and effective. It would also make it easier to overlay a sustainability incentive into the policy design, in a similar way to how the 45V “clean” hydrogen tax credits work. The 45V credits range from $0.6 per kg to $3 per kg of hydrogen, depending upon the lifecycle GHG emissions associated with each route.32 With the carbon emissions intensity of nickel production from integrated nickel sulphides typically being 4–8 times lower than laterite ore–based processing in Indonesia, the nickel industry is a perfect candidate for a similar policy. The combination of a threshold for eligibility (say 20 tonnes of carbon emissions per tonne of nickel), with an escalating tax credit for nickel produced underneath that threshold, would be an elegant design. A framework along these lines (hopefully cascaded across key manufacturing centres) would serve as a solid foundation for the private sector ecosystem of price reporting and assessment agencies, standards and certification schemes (which could streamline standards to improve transparency and comparability of ESG performance and incorporate GHG emissions intensity), traditional and emerging exchanges, and leading firms at all steps in the value chain to drive the development of an industry based around the reliable supply of more sustainable battery materials. 

More broadly, a set of clear, predictable, and common set of regulations – finalised with a greater sense of urgency – are critical to delivering progress more effectively on ESG performance and transparency across battery supply chains and ensuring a level playing field. Getting this right today will go a long way towards reinstating confidence in the nickel industry’s status as an attractive business in developed jurisdictions.

Turning to the longer–term fundamentals, we believe that nickel will be a substantial beneficiary of the global electrification megatrend and that nickel sulphides will be particularly attractive – while acknowledging the fact that the overall industry is presently enduring a difficult phase that is expected to extend for many years and sulphide operators are obviously not immune to that .

Our longer–term conviction regarding sulphides is based on their relatively lower cost of production of battery–suitable class–1 nickel than for laterites in a balanced market, as well as the favourable position of integrated sulphide operations on the GHG emissions intensity curve. We acknowledge that turning that reality into a durable competitive and commercial advantage under mid-cycle operating conditions will take many years and require a whole of ecosystem effort. No company or nation can do it alone. 

While that effort has already begun, as an upstream producer competing in an increasingly unfavourable situation, it is prudent to carefully consider all our options from an operational and capital perspective. You can read more here.

Looking beyond the 2020s, there are five key questions for the nickel market in the longer run:33 

  • How fast will electric vehicles (EVs) penetrate the auto fleet? 
  • What mix of battery chemistries will power those vehicles? 
  • What will be the “steady state” marginal cost of converting the abundant global endowment of laterite ores to nickel products suitable for use in battery manufacturing once the current frenetic rate of expansion dissipates? 
  • How will the cost curve evolve in the face of ever–increasing consumer and regulatory demands for transparency with respect to the sustainability performance of upstream activity, including a transition to pervasive carbon pricing? 
  • How will the trade flow of nickel units be influenced by policy and geopolitics? 

We have pre–empted the third, fourth and fifth points with the discussions on Indonesian supply and the desirable evolution of policy frameworks above. Our views on the first two questions are both well–known and uncontroversial: EVs are taking off, and ternary nickel–rich chemistries (mostly NCM nickel-cobalt-magnesium but also NCA nickel-cobalt-aluminium) are expected to be the leading technology that powers them. Leading of course does not mean that this technology will monopolise all applications, and we have previously reported that we revised the long–run share of nickel–rich batteries lower in recent analyses. LFP (lithium–iron–phosphate) has made considerable inroads in recent times, particularly in China, where affordability concerns are paramount among EV buyers and range anxiety is somewhat less pronounced than in the West. Equally, when LFP is not being used, the proportion of nickel–rich chemistries have been rising at the expensive of low and mid nickel chemistries (defined as 622 and below), even in China. NCM and NCA combined added 3-4 percentage points of share in China in the December quarter of 2023, with fast charging capability reportedly a driver of that. 

In Europe, nickel–rich chemistries have increased their share from 17% in calendar 2021 to 32% in calendar 2023, while 622 and 532 formulations have lost a combined 11 percentage points of share over the same time period (from 74% to 63 %). Our view is that LFP will continue to play an important role at the low–and–medium end of the cost and performance spectrum, especially in the developing world. Other chemistries (for example those that thrift on cobalt and/or accommodate more manganese) are also likely to find their niche as EV penetration broadens to all vehicle categories. Sodium–ion batteries are expected to play a long–term role in stationary storage, with possible application in some segments of the two–wheeler space, three–wheelers, and no–frills passenger vehicles, where they will compete with LFP. 

Some of the longer–term market share that we had previously allocated to “unspecified future technologies” has now been captured by incumbent chemistry families, partly due to projectable signposts on cathode pairings with solid–state electrolytes. We have also seen an increasing focus on the anode as a battery performance lever. We’ve chosen to bring forward the likely timing of the commercialisation of solid–state batteries, the first generation of which (featuring semi–solid electrolytes, sometimes referred to as “condensed matter”) seem likely to be paired with high nickel cathodes within just a few years. Beyond that, indications are that solid–state batteries, which are expected to represent a leap in safety and performance, can be deployed with a range of anode and cathode technologies and can thus serve as a default electrolyte platform. 


The last twelve months have been characterised by a downtrend in prompt potash prices as the industry continued the process of unwinding the extremely high prices associated with the scarcity regime that emerged in the first half of calendar year 2022. Across the two halves of calendar 2023, price movements were larger in the first half than the second, with some regions range trading over the last six months. 

Looking at price developments by region, according to assessments in CRU’s Fertilizer Week, the price of gMOP34 into Brazil opened the second half of calendar year 2023 at $335/t CFR and closed at $315/t. gMOP into the United States (at NOLA), which initially led the global rally in 2021 before ceding that place to Brazil, opened the second half of calendar year 2023 at $414/t FOB Barge, and closed at $356/t. Spot prices for sMOP in South–East Asia opened the second half of calendar year 2023 at $318/t CFR, and by year end were sitting at $320/t. India re–negotiated its annual contract down to $319/t CFR in August–2023 from $422/t CFR in April–2023, following China’s settlement in June–2023 at $307/t CFR. 

There is a sense that the market is broadly balanced as calendar 2024 opens. The fact that major regional MOP–crop intersections (e.g., Brazilian soybeans, American corn and wheat, Southeast Asian palm oil) were back closer to balance versus the long run affordability trend was a calming factor for the industry in the second half of calendar 2023, after the volatility and strife of the prior year.

Balanced though does not mean that the market is in any sense “at rest.” The industry remains in the midst of a significant disequilibrium phase as it adjusts to the major shocks of recent years. 

Realised prices for producers tend to reflect developments in prompt pricing assessments with a lag that is partly dependent on the perpetual dance between prompt and fixed price contract markets. Approximate realised prices for Canadian producers (FOB Vancouver equivalent as reported by CRU) as of January 2024, were around $296/t. The peak for the fly–up period was $867/t, achieved in the months immediately following the opening of the Russia–Ukraine conflict.

Overall shipments increased by +7½ Mt to 66½ Mt in calendar 2023 (+12% YoY, our estimate), which was roughly +1 Mt higher than our full year projection at the halfway point. Production rebounded a lesser +7% YoY, from 62½ Mt to 66¾ Mt.35

The demand figures represent a decent recovery from the stunning –12 Mt, –17% YoY collapse of calendar 2022, bringing the market back to 93% of its pre–shock volume. Four of the five major contestable importing regions (China, US, Brazil, India) saw double digit YoY growth in percentage terms in calendar 2023, with Southeast Asia being the lone exception to that trend. That said, on a multi–year basis, India, and not Southeast Asia, has been the laggard. Comparing calendar 2023 imports with the calendar 2020 level, the top–ranked growth markets are Brazil (19% above) and China (11% above). Arithmetically, with those two major consumers pursuing precautionary and/or strategic stocking strategies (albeit the approaches are of a very different nature), and with the producer side of the market still supply–constrained, there was no room for any other major importing region to have grown over the same time period. Accordingly, the US and Southeast Asia have not yet fully recovered to pre–shock levels (90% and 87% respectively), while India and Europe (again, for different reasons) have been mired at 59% and 65% respectively. The rest of the world (collectively, these tonnes are the third biggest bloc worldwide after China and Brazil) is sitting at 82% – flat on a year ago. 

Moving to the exporters now, the major YoY changes came from Belarus and Laos. Having fallen to just 43% of calendar 2020 production levels in calendar 2022, Belarus made considerable progress in circumventing logistics constraints in calendar 2023, shipping an extra +4.2 Mt to reach 9.4 Mt (73% of 2020 levels). That +4.2 Mt was equal to the total lift in global shipments, with a 1 Mt jump in Laotian exports and slightly higher Russian flows fully offset by declines in China, Canada, and the Middle East. Canada’s run–rate in calendar 2023 was down mildly (–1%) after a flat year in calendar 2022. Voluntary mine curtailments in late calendar year 2022 that extended into the following period, and logistics issues due to work stoppages at its western ports, were both headwinds for shipments. 

The approval of stage two of BHP’s Jansen potash project, announced on October 31, 2023, advances our strategy to increase our exposure to future-facing commodities. Longer–term, we feel potash offers very attractive fundamentals. Demand for potash stands to benefit from the intersection of global megatrends: rising population, changing diets and the need for the “sustainable intensification of agriculture”. Developments in the geopolitical landscape since we approved stage one of the project have the potential to bring the balance point of the market forward from prior estimates.

The compelling demand picture, rising geopolitical uncertainty and the maturity of the existing asset base collectively provide an attractive, accelerated entry opportunity in a lower–risk supply jurisdiction such as Saskatchewan, Canada.

The phrase “sustainable intensification of agriculture” includes both the need to improve yields on existing land under cultivation in the face of depleted native soil fertility, but to also begin factoring in the long run land–use implications of large–scale first–generation biofuel production, lower availability of crop residues as an alternate supply of potassium to chemical fertilizer36 under large–scale 2nd generation biofuel production (e.g. “sustainable” aviation fuel), giga–industrial scale renewables and nature–based solutions to climate change. To be clear though, we consider that the impact of deep decarbonisation on potash demand is best characterised as attractive upside on top of an already compelling demand case: not a case in itself.

Something else that attracts us to conventional potash mining and processing is its generally favourable upstream environmental footprint among the major fertiliser nutrients, and beyond the mine gate potash does not generate some of the negative environmental impacts associated with excessive application of nitrogen and, to a lesser extent, phosphorus. The major issues here are leaching into and polluting waterways and the release of GHGs in the application process. Excess nitrogen and phosphorus flows to the biosphere and oceans have been identified as critical “planetary boundary” parameters.37


Inputs and inflation trends

Eighteen months ago, our core message on the inflation front was that we were sensing emerging differentiation between manufacturing and logistics, on the one hand, and labour and energy on the other. The first two categories were moving into the “past the worst” camp. Labour and energy, especially power, remained pressing issues where it was unclear if conditions might yet deteriorate further. Europe’s energy crisis and Australia’s east coast power crisis were cases in point. 

Twelve months ago, it was becoming clear that our instincts on manufacturing and logistics had served us well. If you slow the industrial sector of the developed world down to the point where it is balanced on the precipice of a possible recession, you can take a lot of pressure off physical supply chains and the cost of durable goods and logistics services.

Operational labour markets justified the concerns we expressed, with worker availability tight and wage pressure coming through. But importantly, we gauged that risks with respect to energy costs had become balanced at that stage, rather than skewed to the upside, thus leaving labour markets as the single most pressing forward looking inflationary concern for calendar 2023. 

And we repeated the standard disclaimer on realised costs versus prompt prices: “The lag effect of inflationary pressures is expected to remain a challenge in the 2024 financial year.” 

In the time since, those predictions have begun to manifest in significantly lower rates of general inflation and as well as industry–specific exposures. Even so, the lag effect is very real and will be with us for some time yet.

Turning to the maritime bulk freight market, the key C5 WA–China route averaged $9.5/t in the first half of financial year 2024 up 22% half–on–half and +6% YoY.

In the medium term, we anticipate that rates may rise, with very modest growth in the fleet after a period of weak orders intersecting with an expected lift in bulk volumes. The orderbook for Capesize vessels stands at 5% of the fleet, versus 10-11% for vessels in smaller subclasses. We also note that shipbuilding capacity is stretched across the board due to the surge in container ship orders in response to the pandemic crunch, in addition to a backlog of tankers, LNG/LPG vessels and car carriers.

Regulatory shifts are also likely to influence industry evolution in coming years, with the International Maritime Organization’s newly minted “close to 2050” net zero ambition, and the shorter–term targets that lead up to that milestone, requiring decisive action across the maritime ecosystem if they are to be achieved. 

Last year, BHP participated in two joint industry initiatives to propel the decarbonisation agenda forward: the Australia–East Asia Iron Ore Green Corridor  consortium, led by the Global Maritime Forum; and the ammonia bunkering safety study conducted by DNV under the leadership of one of our strategic partners,

The Global Centre for Maritime Decarbonisation in Singapore38. The first study concluded that ammonia–fuelled vessels could be in operation out of Western Australia from 2028. That finding is subject to technology, safety and regulatory considerations. The second study identified parameters that need to be addressed for safe bunkering of ammonia, which of course have resonance with the outcomes of the first study.  

Wages in Australia and Chile are on different trajectories. Chilean nominal mining wage inflation (as measured in local currency terms by the national statistics agency) has decelerated sharply over the last twelve months, coming down from a peak around 18% YoY to the mid-single digits in the most recent reading, which is close to the longer-term average. The primary force in the deceleration has been the steep decrease in CPI, as hard indexation flows through to wage movements with a predictable lag. Softer labour demand has also contributed, with the Chilean unemployment rate up by around three-quarters of a percentage point over the last twelve months. 

Australian nominal wage inflation is still rising , as the large, administered wage increases covering the financial year 2024 and the rolling renegotiation of expiring enterprise agreements (EAs) flow through the system. Public sector catch-up is an important element in the latest wave of EA inflation. While the Australian labour market remains reasonably tight in absolute terms, it is not as tight as it was earlier in the cycle, with the lead indicators of SEEK and ANZ job ads down by –17% and –15% YoY respectively in December 2023, the coincident indicator of hours-worked declining YoY and the lagging indicator of the unemployment rate now edging up. While a range of skills relevant to mining remain in critically short supply, the relative availability of general workers has improved a little in recent times, partly due to the rapid migration influx. The ABS’ national wage price index (and its mining component) continues to underestimate the growth in labour costs, although at a fourteen year high around 4% YoY in the latest quarter, some of the gap has closed. The true cost of labour though for Australian business, measured on a unit cost rather than a rate basis, is increasingly onerous, with economy-wide productivity performance having been alarmingly weak. Australia’s international competitiveness is suffering from this trend, and arresting this decline is arguably the most urgent task facing all levels of government across Australia. The commonsense response to a productivity problem is to double-down on productivity enhancing policies. Re-regulating aspects of the labour market without reference to the potentially deleterious effects on already weak productivity is the opposite of the commonsense prescription. 

Benchmark indices for ammonium nitrate (AN) – a proxy for explosives costs we estimate as a weighted average of inputs (which varies by region), was quite stable across our key operational regions in the first half of the financial year 2023. Our index increased +1% in Western Australia, fell –1% in Chile, and was flat in eastern Australia. Volatility in feedstock costs (ammonia and its feedstock, natural gas) in the prior half lowered the calendar 2023 outcome for Western Australia –23%, with Chile –30%. Eastern Australia was down just –4%.

Earth–moving tyre raw material costs (weighted) declined by –0.4% in the second half of financial 2023 versus the prior half. Natural rubber has the highest weight in our index, and it has stabilised over the last six months. There were modest increases in petroleum derived inputs, and modest falls half–on–half in steel.

Sulphuric acid prices for Chilean end–users, sourced from Argus, have been volatile within a downtrend trend overall. After falling in both halves of financial 2023, hitting pre–pandemic norms late in the period, they rose again, modestly, in the first half of financial 2024. North Asian FOB prices have been volatile, with negative prices in July 2023 before jumping up to around $40/t just a few months later. They have since receded to around $10/t. CFR Chile pricing ranged from $90/t to $151/t over the first half of financial year 2024, averaging $127/t, a +12% move half–on–half. The end–of–period price is close to the top of the range.The acid market is changing as the massive build out of Indonesia HPAL nickel projects has created a major new demand node in the trade structure, while China’s large build-out of copper smelting capacity promises to uplift Asian by-product supply a material way.

Power prices were crisis–prone across multiple regions for much of calendar 2022, but a sense of (relative) calm descended in the second half of calendar 2023. With prices having receded to more normal levels, we see the forward–looking risks for power prices in our main operational jurisdictions as balanced, with the volatility skew to the downside in Chile if hydro generation continues to improve, and to the upside in Australia – which is our default position given the obvious fragilities in the system.

Chilean spot power prices in the Northern grid (SING) fell –52% in the second half of calendar 2023 to an average of US$51/MWh , versus $104/MWh in the prior half. In Chile, the principal regulatory response to the breakdown of the energy trilemma in calendar 2022 was to mobilise and extend coal power utilisation. Stronger hydro generation has made it feasible to go back to Plan A, with all coal plants that were extended at the time of crisis now being decommissioned .

Australian NEM spot power prices were in a welcome low volatility period in the second half of calendar 2023, with prices down to $56/MWh on average, close to the pre–shock average in calendar 2021. That was –41% from the first half and –64% YoY. For the full calendar year, prices averaged $75/MWh, down from $165/MWh in calendar 2022. Power prices have also been assisted by improved renewable generation, lower fossil feedstock prices and mild weather (in the main). This combination managed to keep the price range in the second half of calendar 2023 much narrower than seen in recent times, despite disappointing coal availability. That said, we see periodic bouts of high volatility as an inherent characteristic of the NEM – with a major spike in evening power prices in Queensland in late January being another reminder of the tenuous nature of calm periods like Spring 2023. We consider the difficulties of calibrating the exit of coal capacity with increasing penetration of intermittent renewables, and managing the complexity for incumbent generators that rising output of rooftop solar brings, all of which is backed by an (as yet) immature storage infrastructure and an under–invested transmission network (noting the NSW–SA interconnector project has been delayed by several years), points towards the amplification of the in–built volatility feature for the remainder of this decade.  For more on the Australian power landscape in the context of the energy transition, see the dedicated chapter here.

Diesel prices have unwound a reasonable portion of the extraordinary gains registered in the wake of the start of the Ukraine conflict, but they remain high after modest gains half–on–half. Average Singapore diesel (into Minerals Australia) increased +11% half–on–half from $101/bb l to $112/bbl, while average US Gulf Coast seaborne (into Minerals Americas) increased +10% half–on–half from $103/bbl to $113/bbl. Refinery spreads have receded from their record highs, but they still remain elevated relative to history. USGC peaked at $80/bbl in the first half of financial 2023 and averaged $33/bbl in the first half of financial 2024. Singapore’s peak was $57/bbl, with an average of $37/bbl). As for crude markets , we see balanced risks in calendar 2024, with escalation in the Middle East a wild card.

The rate of increase in the US producer price index (PPI) for mining machinery and equipment manufacturing moderated further in the second half of calendar year 2023. The index is now running at +10.9% on a 12–month smoothed basis, and +9.5% YoY for the month of December 2023, with the former down around –2.2 percentage points over the last six months. While these figures remain high, and we are somewhat skeptical about the index’ relative stickiness given the time series dynamics of adjacent sectors and comparable indicators, at least they are an improvement from the rate of increase we were facing at times in financial year 2023, with outcomes that were the highest since 1976. The construction machinery PPI was at +9.4% YoY on a 12mma basis and was running at +7.7% YoY in Dec–2023. The YoY rate peaked in August 2022 at +13.8%.


Energy transition trends (the author of this section is Lee Levkowitz, Head of Energy, Carbon and Technology).  

We have touched on elements of the energy transition in the commodity chapters, but it is worth also reflecting on how the low GHG emissions technology transition is progressing in aggregate. Bloomberg NEF (BNEF), an energy think tank, reports that global energy transition investment reached $1.77 trillion in calendar 2023, a +17% increase over calendar 2022 in nominal terms. That compares to an average +24% CAGR from 2020–23.39 While China dominated last year’s figures, growth in calendar 2023 was broader–based. The EU–27 and the UK collectively contributed to one–third of the annual increase, the US to over one–fifth, with China around two-fifths, down from 90% in calendar 2022.

Solar continues to lead energy transition spending in the power sector globally, at $393 billion, with China accounting for roughly half of that. See the China chapter – the rate of installations for calendar 2023 are truly remarkable. However, the total renewables segment was weighed down by wind, particularly wind investment in China, which declined –35% year–on–year. Capacity additions typically lag investment, so while China’s National Energy Administration and the International Energy Agency both reported a large uptick in new wind projects installed in calendar 2023, we could potentially see a slowdown in wind turbines coming online at a global level this year. Ex-China, the wind value-chain has been struggling for a little while now, with weak offshore auctions results, sharply rising manufacturing costs, project over-runs, asset write-downs and job losses at bellwether companies.40

A notable exception to the OECD growth story was Australia, which saw tepid growth of +2%, versus the OECD average of +28%. Despite having a target of 82% renewables by 2030, only six utility–scale wind and solar projects reached FID in the first three quarters of calendar 2023—the lowest since 2015. “Clean” power investments (according to the BNEF definition) for the full year were down –35%. In speaking with our renewables suppliers (BHP sources renewable power for a proportion of our power needs at almost all of our operated assets globally), they cite numerous reasons for the slowdown, including higher financing and supply chain costs, as well as grid constraints–not dissimilar to the headwinds that would be facing the rest of the OECD. Policy uncertainty and approval delays add to the list. Another major challenge has been integration of the growing number of households with rooftop solar. Distributed solar in the National Electricity Market (or NEM, which serves the states of Queensland, New South Wales, Victoria, South Australia and Tasmania) accounted for 11% of power generation in calendar 2023 (+2 percentage points from calendar 2022); in South Australia, it reached as high as 22%.41 Meanwhile, investment in energy storage and grid interconnections in Australia, while growing, has been inadequate to temper the wide swings in day and night-time grid demand and supply caused by rooftop solar.42 These dynamics have contributed to extreme volatility in wholesale power prices over 24-hour periods, with daytime prices often negative, but shooting into the triple digits per megawatt-hour in the evening hours. Enhancing energy storage and grid interconnectors could help smooth the peaks and troughs, but progress has been patchy to date (see: the multiple year delay to the South Australia-New South Wales interconnector since the project was announced).

We are hopeful that the expansion of the Government’s Capacity Investment Scheme, which aims to bring an additional 23 GW of renewables and 9 GW of low GHG emissions dispatchable capacity in Australia, will bolster investor confidence in this space. Access to low GHG emissions firm power supply and grid infrastructure are an essential enabler for the mining sector to meet its decarbonisation targets in Australia, as well as to ensure the competitiveness of Australia’s mining sector writ large. Further policy support to ensure zero emission power supply is ready to replace retiring thermal capacity, such as providing clarity around the Renewable Guarantee of Origin scheme, reforming permitting (with the goal of reducing approval timelines without lowering standards) and enhancing coordination and consistency between federal and state governments, will be essential.

Moving back to the global story, electric vehicle penetration continued to climb, reaching 16% of worldwide auto sales and growing around 40% year–on–year in calendar 2023. For the first time, electrified transport also grew to be the largest segment of “clean” energy investment in BNEF’s methodology, overtaking all forms of renewable energy. China was the overwhelming stand–out in terms of vehicle output: nearly 1 in 3 light duty vehicles sold in China in calendar 2023 were non-internal combustion engine (ICE) vehicles—more than double the amount of EVs sold in all of Europe, and more than all the vehicles (ICE and non–ICE) sold in developed Asia. Increasingly affordable Chinese EVs, and a proliferation of new models and features to lure consumers, not only underpinned a rise in domestic demand but have also enabled a surge in exports. This has accelerated growth in markets that allow unfettered access to Chinese EVs. For instance, Israel and Thailand both recently passed the 10% penetration mark, a critical first infection point for S–curve take–off.

In the US and Europe, EV sales penetration continued to rise, but at a slower rate. Both saw penetration lift around 3 percentage points in calendar 2023, to around 9% and 23% respectively. A number of factors are turning retail buyers more cautious, from higher interest rates (coupled with higher EV financing rates) to OEMs announcing a roll–back in some model releases—particularly in the affordable segments. In the US, hybrids have gained market share after some battery electric models lost access to tax credits amid stricter eligibility criteria. This trend could deepen in the coming months following stricter ‘foreign entity of concern’ guidelines, which may render some more EV models ineligible for federal credits. Fleet operators such as hire car companies have also become somewhat wary of EVs due to less-than-expected residual values on the second-hand market. 

We view the recent EV slowdown in the US and EU as a “bump in the road.” In time, improved cost economics coming out of China should translate to learning and improvements in all markets—as has been the case in a variety of energy transition technologies over the last decade. We still expect a sticker price cross–over point in most major markets between ICE and EVs in the second half of the 2020s, particularly as manufacturing scales and new technologies, such as solid–state batteries, permeate the mass market. Nevertheless, protectionist policies in the politically sensitive auto sector remain a key risk to the outlook in the near term. 

Investment in harder–to–abate decarbonisation technologies is accelerating but is still only ~4% of the investment flowing into the power and transport sectors. According to BNEF, hydrogen and CCUS investments have each grown to above $10 billion for the first time, while investments in the “clean industry” category, which includes low–GHG emissions steelmaking and ammonia, as well as recycling facilities and bioplastics, grew to $49 billion. We have yet to see the true impact of the US IRA come through in the data for the hard-to-abate sectors, but an increase can be expected in the coming years as businesses wrap their heads around the complex legislation—noting of course the clear policy risk at play as we head into a US Presidential election year.

On the international policy front, two major pledges were signed at COP28 in Dubai: one to triple global renewables capacity by 2030 (signed by 129 countries, representing roughly half of global power demand) and one to triple global nuclear capacity by 2050 (22 signatories, ~30% of global power demand, but 70% of nuclear capacity). For the first time ever in a COP agreement, nuclear was also called out as a solution to combat climate change. If achieved, the pledges would drive renewables capacity to 11 terawatts by 2030 and nuclear to 1100 gigawatts by 2050—both above the plausible upside case in our planning range. An important nuance to the pledges is that they do not require each individual signatory to triple capacity domestically, but rather to support a global goal. Notably absent from the list of signatories were China and India, which we expect will be responsible for 40–60% of capacity growth in renewables and nuclear over the coming decades. Without their contribution, the ‘global’ targets may be difficult to meet. 

Meeting the two targets or even getting close to them (noting that on average, the external 1.5-degree scenarios we have studied only get to 6.2 terawatts of wind and solar by 2030, and 939 gigawatts of nuclear by 2050) will require an even steeper uplift in primary mineral and metal supply than currently expected. A typical onshore wind turbine is 3 ½ times more steel–intensive and 1½ to 2 times more copper–intensive than a gas–fired power plant; moving that turbine offshore requires 5.3 times more steel than the gas plant, and over 5 times as much copper. 

These multiples quickly add up, and demand from “energy transition” sectors (i.e. renewables, EVs) represent a growing share of metals and minerals demand over time. BHP’s 1.5-degree scenario43 envisages cumulative primary copper demand over the next 30 years to be around double the amount consumed in the previous 30. Whereas today, the ratio of traditional sources of copper demand (construction, consumer durables, capital goods, etc) to energy transition end-use demand is roughly 93:7, by 2035, that ratio shifts to 80:20. Steel demand, too, sees upside growth from the power sector that more than offsets declines driven by the phase down in fossil fuels.

On the nuclear pledge, the uranium spot market certainly took notice. Nuclear’s standing in the COP process, coupled with a series of supply announcements—with the latest being Kazatomprom’s downgrade of its calendar 2024 production outlook—sent the uranium price above $100/lb for the first time since 2007. These latest developments have augmented the upside coming from the geostrategic risks that have engulfed nuclear fuel supply chain since Russia’s invasion of Ukraine: Russia accounts for half of global enrichment capacity, and one-quarter of Kazakh mined supply is Russian–owned (Kazakh supply represents around 40% of the global total). If the US Senate joins the House in banning the imports of enriched Russian uranium later this year, it could send the spot price even higher. 

Back in 2021, we celebrated the crossing of the $500 billion mark for annual investment focused on the energy transition, but we noted that there was still much more to do. We’re now well past $1 trillion, and yet the message remains the same. Progress across all aspects of the energy transition is accumulating, but the world is still not on track to keep global average temperatures from increasing by more than 1.5-degrees above pre–industrial levels at the end of the century. Current pledges, in our view, fall short of this objective whilst the populous emerging markets target carbon neutrality at a point beyond 2050. Both Bloomberg and the International Energy Agency (IEA) agree that current investment in the energy transition is only slightly above one-third of where it needs to be this decade in their respective Paris-aligned scenarios. The story is nuanced, of course, with some categories roughly tracking to where they’d need to be in a 1.5-degree scenario—this is particularly true for technologies that have reached the point of being commercially competitive (e.g. new solar, Chinese EVs). However, major changes in behaviour and policy are clearly still required for the rest of the energy system. For our part, BHP will continue to focus on the more sustainable production of resources that are essential to meet the world’s climate ambitions.

Important notice:

This article contains forward–looking statements, which involve risks and uncertainties. Forward-looking statements include all statements other than statements of historical or present facts, including: statements regarding: trends in commodity prices and currency exchange rates; demand for commodities; global market conditions; guidance; reserves and resources and production forecasts; expectations, plans, strategies and objectives of management; our expectations, commitments, targets, goals and objectives with respect to social value or sustainability; climate scenarios; approval of certain projects and consummation of certain transactions; closure, divestment, acquisition or integration of certain assets, operations or facilities (including associated costs or benefits); anticipated production or construction commencement dates; capital expenditure or costs and scheduling; operating costs, and supply of materials and skilled employees; anticipated productive lives of projects, mines and facilities; the availability, implementation and adoption of new technologies; provisions and contingent liabilities; and tax, legal and other regulatory developments. 

Forward–looking statements may be identified by the use of terminology, including, but not limited to , “intend”, “aim”, “ambition”, “aspiration”, “goal”, “target”, “prospect”, “project”, “see”, “anticipate”, “estimate”, “plan”, “objective”, “believe”, “expect”, “commit”, “may”, “should”, “need”, “must”, “will’, “would”, “continue”, “forecast”, “guidance”, “outlook”, “trend” or similar words. 

These statements discuss future expectations or performance, or provide other forward-looking information and are based on the information available as at the date of this article and/or the date of BHP’s scenario analysis processes. BHP cautions against reliance on any forward–looking statements or guidance. 
Additionally, forward–looking statements in this article do not represent guarantees or predictions of future financial or operational performance, and involve known and unknown risks, uncertainties, and other factors, many of which are beyond our control, and which may cause actual results to differ materially from those expressed in the statements contained in this article. 

There are inherent limitations with scenario analysis, and it is difficult to predict which, if any, of the scenarios might eventuate. Scenarios do not constitute definitive outcomes for us. Scenario analysis relies on assumptions that may or may not be, or prove to be, correct and may or may not eventuate, and scenarios may be impacted by additional factors to the assumptions disclosed. 

Except as required by applicable regulations or by law, BHP does not undertake to publicly update or review any forward–looking statements, whether as a result of new information or future events. Past performance cannot be relied on as a guide to future performance.

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BHP and its subsidiaries

In this article, the terms ‘BHP’, the ‘Company’, the ‘Group’, ‘BHP Group’, ‘our business’, ‘organisation’, ‘we’, ‘us’ and ‘our’ refer to BHP Group Limited and, except where the context otherwise requires, our subsidiaries. Refer to the ‘Subsidiaries’ note to the Financial Statements in the BHP Annual Report for a list of our significant subsidiaries. Those terms do not include non–operated assets. 



Data and events referenced in this article are current as of February 16, 2024. All references to financial years are June–end, as per BHP reporting standards. For example, “financial year 2024” is the period ending 30 June 2024. All references to dollars or “$” are US dollars unless otherwise stated. Unless otherwise stated, the data is compiled by BHP from a wide range of publicly available and subscription sources, including national statistical agencies, Bloomberg, Wood Mackenzie, CRU, IEA, ILO, IMF, Argus, CREIS, Fertecon, FastMarkets, SMM, Parker Bay, MySteel, Platts, LME, COMEX, SHFE, ICE, DCE, SGX, and S&P Global, among others.

Data comparisons are between 2019 and 2030 and reflect our central case forecasts, which incorporate aspects of the potential physical impacts of climate change for regions around the world and responses to them for these global indicators, the projected climate-related “green” investment boom, estimates of global inflation and the likely impact of expected climate policies. GDP is in nominal US dollars, on a base of $87 trillion in 2019, with changes being the absolute difference between the 2019 actual and the 2030 projection. Capital spending is estimated based on the expected share of gross capital formation (GCF) applied to this measure of GDP. In PPP terms, the 2019 GDP base is around $135 trillion.

Paris–aligned” means a societal pathway aligned to the aims of the Paris Agreement. The central objective of the Paris Agreement is its long–term temperature goal to hold global average temperature increase to well below 2°C above pre–industrial levels and pursue efforts to limit the temperature increase to 1.5°C above pre–industrial levels. 

Available from https://www.iea.org/topics/net––zero––emissions

The relative size of the two segments moves considerably over the course of cycles. The non–commodity segment was 72% of starts and 79% of completions in calendar 2022. However, such was the scale of the starts ramp–up in the multi–year upswing that led up to the pandemic, that developers still account for 58% of the stock of floor space underway.

We have discussed the 3 Red Lines macroprudential criteria for property developers many times on this platform. Those interested in a refresher and a historical comparison to the previous housing downturn can revisit the August 2022 vintage of this Prospects series, available from https://www.bhp.com/news/prospects/2022/08/bhps–economic–and–commodity–outlook#chineseeconomicgrowth 

It is not an all–time low, partly because the commodity housing market did not exist until the late 1990s, and therefore the inventory figures were exceedingly small in absolute terms in the 2000s. 

Household size is from the decadal Census. Sample surveys are conducted more frequently but the data is of substantially lower quality than the Census.

Estimates from the China Household Wealth Survey Report: The proportion of real estate remains high_China Economic Network National Economic Portal (ce.cn) 

10 China has a target to increase the share of rural sewage that is treated from 28% in 2020 to 40% in 2025. That is also an interesting datapoint for those wondering if China is saturated with infrastructure. Developed countries treat about three–quarters of their sewage, on average.

11 As the line goes, the supply chain issue constraining autos in China is no longer chips, but ships, with a shortage of car transport vessels limiting China’s ability to increase its auto exports even more. 

12 An unsustainable spike in exports to Russia was a contributor to this stunning outcome for ICE vehicles.

13 These figures are exports produced in the country. Japanese auto sales produced by affiliates abroad dwarfs their direct export numbers. Of the approximate 24 million sales of Japanese auto makers in 2022, 70% were foreign affiliates, 17% were domestic and 13% were traditional exports. So, while China may be the largest exporter now, but it is still far from being the larger seller of cars in foreign markets. 

14 The Observatory of Economic Complexity (with MIT roots) and Harvard’s Atlas of Economic Complexity are the two competing sources.

15 This range should be treated with modest caution, given different weighting systems, different years of publication and the fact that a bullish or bearish disposition towards US growth may bias the relative level assessed for China. We feel though that the information is broadly indicative of the best thinking on this incredibly important topic.

16 Data on steel and pig iron in this chapter are from WorldSteel and official agencies, unless specified otherwise. Some growth rates have been rounded and historical figures have been revised since our previous version of this report.

17 Note that the net exports increased to around 12% of production in 2015 and 2016, circa 100 Mtpa, on a much smaller production base than today. That spike in exports was a sign of stress, not strength.

18 The tragic Brumadinho tailings dam collapse occurred in the south–eastern Brazilian state of Minas Gerais in January 2019. With hindsight, it has been revealed as a key inflection point for the iron ore market.

19 The comparisons are made with the 2018 Q3 forecast. We first presented analysis along these lines in late calendar 2022, with the end point being 2021 actuals. This analysis is updated for two extra years of activity, but the story remains strikingly similar. The 2023 levels from which the changes in the text are derived are as follows: contestable demand 1860 Mt (actual) versus 1696 Mt (forecast). Low–cost major supply was 1315 Mt (actual) versus 1349 Mt (forecast) and the rest (including Chinese domestic, junior producers and swing exporters) was 559 Mt (actual) versus 392 Mt (forecast). The forecast change in industry–wide stocks was +45 Mt. The actual change in stocks (inferred) has been –14 Mt. 

20 The abbreviations used in the metallurgical coal section are as follows – PLV: Premium Low–Volatile, MV64: Mid–Volatile 64, PCI: Pulverised Coal Injection, SSCC: Semi–soft Coking Coal, as published by Platts. Unless specified otherwise, figures are rounded to the nearest dollar and are quoted in free–on–board (FOB) terms. The terms “coking” and “metallurgical” coal are used interchangeably throughout the text. Note that the PLV index is used as a benchmark for “premium hard coking coals” (PHCCs), which also comprise PMVs (premium mid vol, generally traded at a discount to the PLV index), as well as PLVs. 

21 See footnote 30 for terminology. Note that around two-thirds of our product was in the PHCC technical quality bracket pre-divestment, but three-quarters referenced the PLV index in our contracts. The slide in the results presentation is presented on the former basis, where 86% of production will meet the specifications of PHCC post-divestment.

22 These approximations are based on a sample of mills, not a census. Note a BF is typically relined every 20 years or so. 

23 LME Cash Settlement basis. Daily closes and intra–day lows and highs may differ slightly. 

24 A decade ago, stocks in Chinese bonded warehouses reached 1 Mt. At the end of January-2024, there was less than 10 kt. 

25 Note that scrap is also used directly by copper semi producers, and these copper units are outside the refined balance. The total scrap share of copper semis in calendar 2023 is estimated to be just short of 31% (~19 percentage point from direct use in semis production, ~12 percentage points from use in refined production).

26 Consensus survey distributed to UBS clients monthly. The January 2024 edition cited in the text captured forecasts current as of end November 2023. 

27 https://www.minister.industry.gov.au/ministers/king/media-releases/nickel-placed-critical-minerals-list

28 https://www.industry.gov.au/publications/australias-critical-minerals-list-and-strategic-materials-list

29 Based on the 2024 Wood Mackenzie cash plus sustaining nickel cost curve as of January 2024. Note that under considerable financial pressure operators can take urgent actions on their cost base that make it very difficult to estimate true cost in real-time. It also assumes that all producers face spot prices, whereas some producers may have taken hedge positions. Therefore, the analysis presented here should be taken as a rough approximation of industry conditions at a specific point in time, not as a precise estimate with an extended period of validity. The loss-making share could go higher with even small downward movements in price, or lower if, for example, sustaining capex was temporarily suspended at a number of operations. Management actions such as the latter would not be visible to the rest of the industry for some time. The cash plus sustaining cost curve is quite flat either side of the current intersection with spot prices. 

30 Historical data is compiled from a composite of sources (Wood Mackenzie, SMM and CRU), with some BHP estimates.

31 Beyond the mining ecosystem, these concerns have been noted in the NGO community, for example https://cri.org/indonesia-huge-nickel-project-driving-climate-rights-environmental-harms/ 

32 See this link for the official policy on “clean” hydrogen. https://home.treasury.gov/news/press–releases/jy2010#:~:text=The%20IRA%20Clean%20Hydrogen%20Production%20Credit&text=For%20hydrogen%20production%20facilities%20meeting,emissions%20of%20the%20hydrogen%20production.

33 We focus on key uncertainties in the main text, but the future path of conventional non–battery demand is also worthy of note. Nickel first–use is dominated by the stainless steel sector. It comprised more than two–thirds of primary demand in the 2010s but has been losing ground to batteries at the rate of a few percentage points each year in the 2020s. Non–stainless, non–battery demand has been more stable in its share of around one–fifth. Nickel end–use is diverse, with broad sectoral exposure to construction, consumer durables and electronics, engineering, metal goods and transport, in addition to finished batteries. 

34 Fertiliser–grade MOP is commonly sold in powder (“standard”) or compacted “granular” forms, abbreviated as sMOP and gMOP respectively. gMOP typically sells at a premium. Major demand centres for sMOP include China and India, while gMOP is prevalent in the Americas. Pricing data sourced from Fertilizer Week and public filings. The FOB prices in Fertilizer Week are freight netbacks only. Realised prices will differ from these estimates to the extent that other contract terms, such as negotiated discounts, deviate from zero. 

35 All trade data in this section are from S&P Global.

36 The potassium uptake of crops comes from (a) native K in the soil, (b) crop residues, (c) manures, and (d) chemical fertiliser. These shares vary widely by region, but the global averages are 30% from the soil, 20% from manures, 20% from crop residues and 30% from fertiliser. We anticipate that the fertiliser share will rise over time as soil fertility depletes. 

37 For more on the Global Boundaries framework, see W. Steffen et al., Science 347, 1259855 (2015).

38 https://www.gcformd.org/ammoniabunkeringreportdownload

39 Bloomberg NEF changed its methodology in this year’s update to include a wider range of technologies (grids, “clean” shipping, “clean” industry), but using last year’s methodology, growth was even higher at +20% YoY. The expanded coverage to grids now brings the Bloomberg numbers closer to the IEA’s methodology, which estimated “clean” energy investment would reach US$1.74 trillion in CY23.

40 Siemens (the leading offshore turbine manufacturer), Vestas (the leading turbine maker on a combined basis) and Orsted (global project developer and generator), three European giants operating in various segments of the wind industry, all reported financial results in February 2024. The general theme was that the sector’s profitability is being challenged on many fronts. 

41 In contrast, distributed solar generation accounts for around 3% of the EU-27’s power generation mix.

42 For example, in Queensland the phenomenon known as the “Russ Christ Effect” is often at play in the summer months. During daylight hours strong rooftop solar offsets higher demand during hot and humid days, but by late afternoon, storm clouds from the rising humidity can dim solar penetration, while household air conditioning demand remains at relatively high levels. This leads to a sharp increase in operational grid demand, requiring expensive gas generators (or even diesel) to rapidly be brought into the system. 

43 This scenario requires steep global annual GHG emission reduction, sustained for decades, to stay within a 1.5°C carbon budget. 1.5°C is above pre-industrial levels. For more information about the assumptions, outputs, and limitations of our 1.5°C scenario refer to the BHP Climate Change Report 2020, available at bhp.com/climate.

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