Imagine pulling apart a spent electric-vehicle battery cell the size of a paperback book. Inside the dark, layered material of the positive electrode — the cathode — you would find a powder whose exact recipe determines almost everything: how much energy the cell stores, how long it lasts, how hot it runs under stress, and which mines on which continents had to produce something for it to exist. That recipe is what distinguishes one battery chemistry from another, and it is why a shift in consumer preference or policy can ripple back through supply chains to ore bodies that have been in the ground for millions of years.
NMC: the high-energy standard
Lithium nickel manganese cobalt oxide — NMC — has for years been the dominant cathode chemistry in passenger electric vehicles where range matters most. The formula contains lithium, nickel, manganese and cobalt in proportions that vary by grade: earlier versions used roughly equal parts of the three transition metals, while more recent grades push the nickel content higher to store more energy per unit of weight, simultaneously reducing the cobalt share.
Nickel at high purity is the largest single demand driver here, and not all nickel will do. The refining industry distinguishes between class one nickel — essentially pure metal or high-grade nickel sulfate — and the lower-grade ferronickel or nickel pig iron produced from laterite ores and used predominantly in stainless steel. Battery makers need class one material. This means that even as global nickel production is large, the fraction of it suited to cathode use is considerably smaller, and the two processing routes do not simply substitute for one another.
Cobalt adds further complexity. Most of the world's cobalt is produced as a by-product of copper mining in a single central African region, which means cobalt supply is not governed by cobalt demand alone — it moves with copper decisions made by copper companies. That structural dependency, combined with concerns about artisanal mining conditions in parts of the region, has driven battery manufacturers to reduce cobalt loadings wherever chemistry allows.
Lithium underpins all of these cells. It arrives at the cathode powder as a lithium salt and also forms the anode's travelling ion. The two main sources — hard-rock spodumene, mined primarily in Australia, and lithium-bearing brines beneath salt flats in South America — involve quite different processing routes and different geographies of water use, community impact and carbon intensity.
LFP: fewer metals, different trade-offs
Lithium iron phosphate, universally abbreviated LFP, replaces the nickel, manganese and cobalt with iron and phosphate. Iron is one of the most abundant elements in the Earth's crust, and phosphate rock is mined at large scale for fertiliser, so the supply picture looks considerably simpler at first glance. LFP cells carry less energy per unit of mass than high-nickel NMC, which is why they were long considered unsuitable for vehicles where weight and range compete directly. Advances in cell and pack design have narrowed that gap, and LFP now holds a substantial share of the market, particularly in shorter-range vehicles and in stationary storage where weight is largely irrelevant.
LFP still requires lithium — in similar quantities to NMC on a per-cell basis — so the lithium mining industry is not relieved of pressure by a swing toward LFP. What changes is the demand for nickel and cobalt, which falls to zero for every LFP cell sold. The mining consequence is a rebalancing rather than a reduction in total demand from the ground.
A simple illustrative comparison shows the difference in mineral footprint. Suppose, for illustration only, that a hypothetical NMC cell of a given capacity requires one unit of lithium, three units of nickel, one unit of manganese and a fraction of a unit of cobalt. An LFP cell of the same capacity might require a similar unit of lithium, no nickel, no cobalt, and modest amounts of iron and phosphate. The lithium demand is comparable; the transition-metal demand shifts entirely. At the scale of millions of cells, that arithmetic has real consequences for which mines expand and which do not.
Sodium-ion: stepping away from lithium
Sodium-ion batteries replace lithium with sodium as the working ion. Sodium is chemically similar to lithium — it sits directly below it in the periodic table — but vastly more abundant and more evenly distributed around the world. It can be extracted from common salt or from seawater in principle, though commercial sodium-ion production currently uses refined sodium compounds rather than seawater directly.
The cathode in a sodium-ion cell can use several different material families, some of which contain manganese or iron but none of which require cobalt or high-purity nickel in the way NMC does. The anode, critically, can be made from hard carbon derived from organic precursors rather than the synthetic graphite or natural graphite used in lithium cells. Graphite supply — particularly the natural graphite mined predominantly in China — has been a quiet bottleneck in lithium battery supply chains, and sodium-ion cells that use hard carbon anodes reduce that exposure.
The trade-off is energy density. Sodium-ion cells store less energy per kilogram than either NMC or LFP at present, which makes them most competitive in applications where cost and material availability matter more than weight: grid storage, two-wheelers, and entry-level urban vehicles. Whether they expand significantly into higher-demand applications depends on how much further cell design can improve their energy performance.
What the mining industry faces
Each chemistry effectively creates a different mineral demand profile, and no single mine or material benefits equally from the growth of all three. A lithium producer sees demand from all of them. A cobalt producer is exposed mainly to whatever share of the market NMC retains. A nickel sulfate refiner is in a similar position. The producers of iron, phosphate and sodium compounds face almost no demand from NMC or sodium-ion respectively. Battery chemistry is therefore not an abstract technical matter for the extractive industries — it is the variable that determines which ore bodies become economically relevant and which face reduced demand, sometimes with little warning as technology preferences shift.
For readers who want to go further: the comparison above treats each chemistry as fixed, but cathode formulations continue to change — high-manganese variants, lithium-rich layered oxides and solid-state electrolytes all alter the mineral requirements again. The anode side of the cell, and the role of graphite versus silicon versus hard carbon, is a parallel story worth following, as is the difference between primary supply and what recycling might eventually return to the material stream.