Analysts anticipate that reducing royalty rates could provide much-needed relief for lithium producers grappling with plummeting prices. The decline in lithium prices since the beginning of 2023 has been significant, with battery-grade lithium carbonate prices dropping by over 80% by April 2023.
Amid this downturn, lower royalty obligations to local governments could help alleviate financial pressures on mining companies.
Lower royalty payments would directly reduce miners’ cost of sales, particularly as lithium prices decline, thus bolstering profitability amidst challenging market conditions. This adjustment is seen as a short-term measure to support miners until lithium prices stabilize or recover.
Lithium Challenges Amidst Price Decline
The financing landscape for lithium projects in the United States is also encountering hurdles amid sustained low lithium prices. This could impede the current administration’s efforts to strengthen the domestic battery supply chain.
Despite plans for around 100 lithium mine projects across the US, the appeal of these ventures has diminished due to the significant decline in lithium prices.

Data from S&P Global Market Intelligence reveals an 81.7% decrease in lithium prices from their peak in 2022. This prolonged period of low prices has made numerous projects less appealing to investors, affecting the overall viability of the development pipeline. As a result, financing for these projects is facing challenges, while impacting the domestic battery supply chain in the US.
Factors contributing to the current market dynamics include increased production capacity in 2023 alongside slower-than-expected growth in electric vehicle sales. These conditions have led to a scenario where lithium prices are expected to remain subdued until there’s a notable improvement in EV affordability.
Consequently, mining companies adjust their strategies. Some high-cost miners exit the market while others scale back expansion plans and focus on cost-saving initiatives.
The Royalty Realities in a Volatile Market
The fluctuation in lithium prices has a direct impact on royalty payments made by producers.
Royalties are payments made by a third party to the owner of a product or patent for the use of that product or patent. These payments are typically outlined in a licensing agreement, which specifies the terms and conditions under which the third party can use the product/patent.
The royalty rate, which determines the amount of the royalty payment, is calculated as a percentage based on various factors. These include the exclusivity of rights, the value of the technology or intellectual property, and the availability of alternative options.
Royalty structures for lithium extraction vary across major producing countries, with most employing variable systems that adjust with market prices.
In Argentina, royalties fluctuate by province but are capped at 3%. Meanwhile, Western Australia and Zimbabwe set theirs at 5%, with options for partial payment in minerals.
Chile, home to significant lithium reserves, implements a unique royalty system through its production development agency, CORFO. Operators like SQM and Albemarle, major players in the Salar de Atacama, face variable royalty rates ranging from 6.8% to 40%, linked to market prices. This approach aims to support miners during price fluctuations.
Despite Chile’s comparatively high royalty rates, investments in lithium projects there and in Argentina remain attractive. In fact, most projects in these countries maintain profitability even amid current price levels. Chile is the second largest lithium producer while Argentina takes the fourth spot.

As the lithium market evolves, variable royalty systems are gaining popularity for their adaptability to price volatility and support for the mining sector.
The Impact on Lithium Miners’ Bottom Line
In 2022, when lithium prices soared to historic highs, miners saw their royalty payments surge by a staggering 960.1% compared to the previous year. This increase in royalties significantly elevated overall miners’ production costs, with royalties accounting for over 60% of total cash costs.

While miners were able to absorb these additional costs during the peak price period, the likelihood of lithium prices returning to such levels in the near future is uncertain. As lithium prices normalize, royalty adjustments are expected to have a lesser impact on miners’ profitability. This is particularly prevalent in a market characterized by lower prices.
Lower royalty rates in a depressed price environment can provide miners with some relief. This will allow them to preserve margins despite challenging market conditions.
Market projections suggest a decrease in average royalty payments and total cash costs, providing a favorable outlook for lithium producers. More remarkably, investors still continue to show strong interest in lithium projects amid short-term price challenges, foreseeing their long-term potential.
As lithium prices continue to plummet, the call for reduced royalty rates emerges as a lifeline for struggling producers. With royalties comprising a significant portion of mining costs, lowering these obligations could inject much-needed stability into the industry.
The post Lower Royalty Rates Give Lithium Producers a Lifeline appeared first on Carbon Credits.
Carbon Footprint
Insetting vs Offsetting: Which Actually Counts Toward Your Scope 3 Targets
The accounting differences that decide whether your nature investment shows up in inventory, in BVCM, or nowhere at all.
The question reaches a procurement team about three weeks before the next sustainability committee meeting. Someone has read about insetting. Someone else has just signed off on an offset purchase. The CSO wants to know if the two are interchangeable. The answer is no, and the GHG Protocol Land Sector and Removals Standard is the reason why.
This article walks through what each term means at audit-grade specificity, what the standards actually say about how each gets counted, and how to decide which tool fits which target. The insetting vs offsetting question is one of the most-searched in corporate climate strategy, and one of the most poorly answered. By the end of this piece, you should be able to brief a committee on the difference without notes.
The two definitions, in plain English
Offsetting means buying carbon credits generated outside your value chain and retiring them against your residual emissions. The reduction happens somewhere else, financed by you, and the credit is the receipt.
Insetting means investing in emission reductions or removals inside your own value chain, typically with suppliers, where the reduction is directly linked to the products and services you buy. The reduction happens inside the boundary of your Scope 3 inventory, and the accounting treatment is fundamentally different.
The shorthand from the University of Oxford’s Nature-based Insetting Initiative is useful: insetting is what you do with the supply chain you have; offsetting is what you do with the supply chain you do not have.
What the GHG Protocol Land Sector Standard actually says
The GHG Protocol Land Sector and Removals Standard, finalised in 2024 after a multi-year pilot, sets the rules for how land-based emission reductions and removals enter corporate inventories. The Standard distinguishes between inventory accounting (Scope 1, 2, and 3) and project or intervention accounting (a separate methodology for crediting).
For insetting, the practical implication is that supplier-level interventions, when properly measured and attributed, can reduce your Scope 3 category 1 (purchased goods and services) emissions in your inventory. The reduction is not a credit retired against the inventory; it is a lower inventory number, period.
For offsetting, the credit is retired separately. It can be reported as a contribution toward a net-zero claim under the SBTi Beyond Value Chain Mitigation framework or as part of a VCMI Carbon Integrity claim, but it does not lower the inventory number.
A practical consequence: if your Science Based Target requires a 50% absolute reduction in Scope 3 emissions by 2030, insetting moves you toward the target. Offsetting does not. This single point of difference reshapes the procurement decision.
When insetting counts toward Scope 3 (and when it does not)
Insetting counts toward Scope 3 only when several conditions are met:
- The intervention must occur with an entity in your value chain.
- The emissions reduction or removal must be measured against a defensible baseline.
- The reduction must be attributed to your share of that supplier’s output, not double-counted with other buyers.
- It must follow the inventory accounting rules in the GHG Protocol Land Sector Standard, not the project accounting rules used to generate credits.
The most common failure mode is double counting. If your supplier sells the same reduction as a credit on the voluntary market and also reports it to you as a Scope 3 reduction, the math breaks. The Standard requires you to address this risk, typically by purchasing and retiring the supplier-issued credit as part of your inventory or by contractual provisions that prevent the supplier from selling the reduction twice.
When insetting does not count toward Scope 3: when the intervention sits with a supplier you do not buy from, when the baseline is not defensible, when the attribution is unclear, or when the documentation does not survive audit. Those cases default to Beyond Value Chain Mitigation, which is still useful but operates on a different ledger.
The procurement and supplier engagement question
Insetting is harder than offsetting. That is the unfashionable truth most buyers eventually confront. Offsetting is a transaction; insetting is a relationship.
To run an insetting program, you need supplier mapping precise enough to know which farms or facilities sit at which Scope 3 boundary. You need an engagement model that gets suppliers to participate, which usually requires multi-year commitments and shared economics. You need an MRV architecture that measures the right things and produces audit-ready documentation. And you need a contractual structure that prevents double counting and protects both sides.
The trade-off you receive in return is significant. Reductions count against your inventory rather than your residual. Supplier relationships deepen, which protects sourcing continuity. Yield and quality improvements often follow regenerative interventions, which reduces your input cost over time. And the regulatory file, under CSRD, CSDDD, EUDR, and the SBTi FLAG Guidance, is materially stronger.
Choosing the right tool for the right target
A practical decision rule. If your target is a science-based Scope 3 reduction and you operate in a FLAG sector or source FLAG commodities, insetting is the structurally correct tool. If your target is a net-zero claim that includes neutralising hard-to-abate residual emissions outside your value chain, BVCM via high-integrity offsets is the structurally correct tool. Most companies with material Scope 3 exposure need both, in different proportions, sequenced over time.
The sequencing matters. Insetting takes longer to stand up but produces a permanent reduction in the inventory. Offsetting can be transacted faster but does not change the inventory and now sits under tighter claim restrictions. Treat them as complementary tools with different jobs, not as substitutes. The Accountability Framework Initiative and the IUCN Global Standard for Nature-based Solutions both provide useful guardrails for the insetting side, with biodiversity, human rights, and benefit-sharing requirements that go beyond carbon math.
If you are mapping a Scope 3 reduction roadmap and need to scope which interventions count toward your inventory versus which sit in Beyond Value Chain Mitigation, the carbon and sustainability experts at Carbon Credit Capital can help you structure a nature-based supply chain investment program that fits your FLAG exposure, your target architecture, and your audit horizon. Schedule a consultation.
Carbon Footprint
Net zero needs nature: a carbon credit guide
Net zero is often described as a balancing act: cut what you can, account for the rest, and reach zero on the ledger. That framing is useful, but it leaves something out. It treats every tonne of carbon as interchangeable and every route to zero as equally sound, while the science tells a more specific story.
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Carbon Footprint
Deforestation in Malawi: causes and solutions
Malawi has lost a striking share of its forests over the past three decades. Woodlands that once covered well over a third of the country now cover less than a quarter, and the pressure on what remains is increasing. Behind those figures sit two practical questions: what is driving the loss, and what reverses it?
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