Why Indonesia’s Quota Clock Threatens India’s Coal Import Floor

On 11 September 2026, PT Bayan Resources and three of its subsidiaries told customers they could no longer legally ship coal under existing contracts. There was no mine collapse, no flood, no equipment failure.

The cause was a ceiling on paper. The Indonesian government had not approved revisions to the companies’ annual production quotas, and the mines had simply reached the limit of what they were permitted to dig.

The force majeure landed at an awkward moment. Low-calorific value (low-CV) Indonesian coal prices had climbed to their highest since February 2023, and India’s post-monsoon buying season was just opening.

That places India seaborne coal imports at the intersection of two slow-moving structural forces: Indonesia’s tightening administrative grip on output, and India’s own deliberate push to cut blending imports in favour of domestic coal. How those forces interact over the next quarter will decide whether the current tightness eases or compounds.

Here is what the data tells you about where the stress is concentrated, and where the demand floor holds firm.

What Bayan’s force majeure actually reveals about Indonesia’s export architecture

The disruption did not begin underground. It began in a filing office.

Bayan Resources disclosed its force majeure through a document lodged with Indonesia’s Financial Services Authority (OJK filing No. 461/BR-OJK/IX/2026), citing the non-approval of revisions to its 2026 Work Plan and Budget, known locally as the RKAB. The affected mines had hit their government-sanctioned production ceilings, and without approved revisions, further legal output was impossible.

The force majeure covered four entities and rested on a single regulatory cause:

Indonesia’s RKAB approval procedures, governed by Ministerial Regulation No. 17 of 2025 from the Ministry of Energy and Mineral Resources, establish the formal submission and sign-off process that miners must complete before revising annual production ceilings, making administrative timing a hard constraint on legal output.

• PT Bayan Resources Tbk (parent)
• PT Tiwa Abadi
• PT Tanur Jaya
• PT Fajar Sakti Prima
• Cause: non-approval of RKAB production quota revisions, not any physical mining failure

That distinction is the whole story. Indonesia manages coal output through annual RKAB approvals paired with a Domestic Market Obligation (DMO), a rule requiring miners to reserve roughly 20-25% of approved production for the domestic market. Exports are structurally limited to whatever is left once that domestic slice is carved out, which makes the DMO an indirect export quota in everything but name.

Indonesia’s coal export policy overhaul in 2026 sits at the root of why a bureaucratic delay rather than a physical event can now constitute a material supply shock for importing nations across Asia.

The macro numbers show how political that architecture has become. In early 2026, Jakarta signalled plans to cut national output from 790 MMT in 2025 to around 600 MMT in 2026. Subsequent approvals relaxed that partially, reaching 580 MMT and later just over 600 MMT, but any volume beyond the initial limits still requires a formal RKAB revision, exactly the approval Bayan could not obtain in time.

The credit market read the signal quickly.

Moody’s revises Bayan to negative On 18 September 2026, Moody’s Investors Service revised Bayan Resources’ outlook to negative following the permit blocks and force majeure. As of that date, the force majeure remained in effect with no new quota approval published.

What this tells you is that Indonesian export supply can be constrained by administrative inaction alone. There is no storm to track, no strike to negotiate. Quota revision timelines are now a material risk variable for any buyer leaning on Indonesian spot supply, and because the constraint is bureaucratic rather than physical, it is both harder to anticipate and slower to unwind.

Low-CV Indonesian coal prices at multi-year highs: what the market is pricing in

The price had already told the story before the filing did.

Back in April, low-CV Indonesian coal looked comfortable. On 10 April 2026, Argus assessed GAR 4,200 kcal/kg coal for geared Supramaxes at $59.31/t FOB Kalimantan, a level that gave Indian blenders room to breathe.

By September that comfort had gone. On 11 September 2026, Argus put GAR 4,200 at $76.45/t FOB Kalimantan, the highest reading for the grade since February 2023. The same day, Indonesian broker Coaltradeindo listed GAR 4,200/NAR 3,800 at $72.00/t.

Then came the force majeure, and the price barely flinched. By 17 September 2026, Coaltradeindo’s sheet listed GAR 4,200/NAR 3,800 at $77.00/t FOB South Kalimantan, a week-on-week move of roughly 1% over the $76.45/t Argus mark from six days earlier.

The full arc is easier to read laid out in sequence.

The scale of the run-up From the April Argus baseline of $59.31/t to the mid-September peak near $76.45/t, low-CV Indonesian coal climbed roughly 29% in five months.

The marginal move after the force majeure is the analytical tell. The market had already priced the tightness before Bayan’s declaration hit the wires, which makes the disruption confirmatory rather than catalytic. Further upside from here needs one of two things: a genuine demand acceleration, or a failure to resolve the quota block.

A second demand vector is worth flagging. Cement producers have begun chasing high-CV Indonesian coal as a substitute for US fuel-grade petroleum coke and high-CV NAPP coal, both of which recently hit multi-month highs. That demand is not coming from Indian power buyers, which means the pressure on Indonesian grades is broadening rather than narrowing.

For traders and end-buyers, the distinction between a price that has already moved and one still moving is what shapes forward purchasing. At current levels, the economics of blending imported coal at India’s domestic-coal plants are badly compressed, which feeds directly into the structural substitution story.

India’s import split: why the headline number hides the structural story

Start with the aggregate, and India looks like a market in retreat. During April-July 2026, total utility coal imports came in at 16.83 MMT, down 13% year-on-year from 19.28 MMT.

India’s thermal coal import trajectory across FY26 shows the blending retreat accelerating well before the September supply disruption, which means the aggregate decline already reflected a policy-driven structural shift rather than a demand-side weakness in the dedicated fleet.

Split that number apart, though, and it fractures into two trends moving in opposite directions.

The first is a collapse. Imports at plants that blend imported fuel with domestic coal fell 37% year-on-year over April-July, to just 2.61 MMT from 4.16 MMT a year earlier. In July alone, blending receipts dropped 45% year-on-year to 478,000 tonnes.

This is not a seasonal wobble. It is a policy outcome unfolding over years. Blending imports have fallen from 35.10 MT in 2022-23 to 14.02 MT in 2024-25, then to just 5.5 MT across April-December of 2025-26, a 54% year-on-year cut. Government tracking records a 71.5% reduction over three years, driven by a Coal Ministry strategy paper that prioritises domestic output and targets a 30% cut in power-sector imports during 2026.

The blending decline is elastic demand walking out the door on purpose. What it tells you is that the headline import figure is being pulled down by a segment the Indian government wants to shrink, not by weakening power demand.

The dedicated fleet: a structural floor with a near-term variable

The other trend is a floor, and it is holding.

India’s dedicated imported-coal fleet, a 17.77 GW set of plants representing roughly 8% of the country’s total coal-fired capacity, saw its July 2026 imports rise 30% year-on-year to 4.08 MMT. These plants were built to run on imported coal and cannot simply switch to domestic supply. Their boilers are engineered around specific fuel grades, and long-term contracts lock in the arrangement, which is why substitution here is structurally limited rather than merely inconvenient.

The dependency shows up in the power-sector data. A 17 September 2026 report from local trader iEnergy Natural Resources put India’s power-sector coal imports at 5.52 MMT in August, up 85.6% year-on-year and the highest since May 2025. Around 4.2 MMT, roughly 80%, came from Indonesia.

That leaves one near-term variable sitting on top of the floor. Emergency generation support measures at Tata Power’s 4 GW Mundra imported-coal facility were scheduled to lapse at the end of September unless extended. It is a binary event: an extension keeps the floor intact, a lapse risks output reduction at a plant that has no domestic fallback.

For the full year, the International Energy Agency’s mid-year update projects India’s total seaborne thermal coal imports falling from 167 MT in 2025 to around 160 MT in 2026. Read correctly, that number reflects the blending retreat, not a fleet in decline. If you want to read India’s import data honestly, you have to know which segment is elastic and which is locked in.

Why replacing Indonesian low-CV coal is harder than it looks

The instinctive response to a supply shock is to find another supplier. Following the Bayan disruption, at least one Indian end-user did exactly that, seeking replacement volumes from alternative Indonesian producers and from South Africa.

The problem is that every route out is already partly closed.

Comparable low-CV grades are simply not widely available from other exporters. Indonesia supplied around half of global thermal coal exports in 2025 (a figure worth treating as indicative rather than confirmed), and its coal carries two advantages that are hard to replicate: low sulphur content, and a short-haul freight edge to India’s east coast against Australian cargoes.

The constraints stack up quickly across each alternative:

• Australian and Russian high-CV coal: requires different boiler settings and is poorly suited to blending plants engineered around Indonesian specifications
• South African coal: competing demand from India’s sponge-iron sector, Vietnam and South Korea, alongside sharp volume constraints
• Alternative Indonesian producers: limited spare low-CV availability, especially with the quota system tightening across the board

South Africa deserves particular attention because it is the obvious fallback. Its non-coking coal exports fell 33% month-on-month to a one-year low of about 4.03 MMT in January 2026. The available tonnes are heavily contested. India’s booming sponge-iron sector leans on South African coal because domestic supply is steered toward power plants, and by September 2026 producers and traders reported it in short supply, with Vietnam and South Korea bidding for the same cargoes and pushing prices up.

South African coal export constraints in 2026 extend beyond the Richards Bay volume picture; Hormuz-related trade route disruptions have added freight cost pressure and rerouting complexity that further limits the availability of South African tonnes for Indian buyers seeking a quick substitute.

The historical precedent calibrates the downside.

The 2022 export ban On 1 January 2022, Indonesia imposed a blanket one-month coal export ban to protect domestic power supply. Global coal prices rose steeply, and Indian buyers scrambled to lift Australian volumes and divert vessels bound for other South Asian markets. Earlier in 2026, deep production-cut proposals alone sent benchmark Asian thermal prices up around 9% to a one-year high.

Put the pieces together and the conclusion is earned rather than asserted. Grade specificity, freight economics, and a South African market already stretched by competing sectors mean India has no ready substitute for Indonesian low-CV coal at scale. The substitution constraint is the variable that converts a temporary administrative block into potentially persistent tightness. If the RKAB revision drags, the market has very little room to reroute.

What the quota clock means for Indian buyers before year-end

The next four to six weeks are where administrative delay and seasonal demand converge, and three variables will do most of the work in deciding the outcome.

Ranked by near-term timing, here is what to watch:

1. Tata Power Mundra support expiry (end of September): emergency generation support at the 4 GW imported-coal plant lapses unless extended, putting output at risk
2. RKAB revision outcome (ongoing): Bayan’s force majeure remained unresolved as of 18 September 2026, with no new quota approval published
3. October import season (October onward): post-monsoon demand as utility inventories draw down

The demand baseline for the immediate window looks firm.

Kpler’s September projection Kpler estimated India’s September 2026 seaborne coal imports at 12.54 MMT, slightly above the 12.15 MMT recorded in September 2025.

A June 2026 Kpler signal, which should be treated as indicative, suggested India was likely to lift thermal imports from October as strong power demand pulled down utility stocks. Layer that seasonal uptick over an unresolved quota block, and the arithmetic gets uncomfortable.

Here is the distinction that matters. The IEA’s full-year 160 MT projection assumes normalisation across the year. It does not describe the quarter-by-quarter path, and it will not capture a near-term squeeze if the RKAB delay extends into October.

The structural blending retreat, backed by the Coal Ministry’s 30% import-cut target for 2026, is a genuine long-run dampener on aggregate demand. But it buffers the wrong segment. It does nothing for the dedicated fleet or the spot market, both of which remain exposed to Indonesian administrative timing. Treat the RKAB resolution as the lead indicator, not the import-volume headline.

Coal India’s long-run import reduction strategy frames the Coal Ministry’s 30% power-sector import cut target for 2026 as one milestone in a decade-long programme, which means the blending retreat currently compressing headline import figures is not a cyclical correction but an institutionally designed trajectory.

Three variables that will decide whether the tightness passes or compounds

The central tension is straightforward. Indonesia’s quota architecture creates supply constraints that resolve slowly, while India’s structural move away from blending imports offers a partial demand buffer that is real but imperfect.

The buffer sits in the wrong place. It cushions the segment India is deliberately shrinking, not the dedicated fleet or the spot buyers who still depend on Indonesian tonnes.

Three forward variables will tell you which scenario is actually unfolding:

• RKAB revision resolution: whether Bayan’s quota block clears or persists into October
• Tata Power Mundra support decision: extension or lapse of emergency support at the 4 GW plant
• Post-monsoon demand actualisation: how hard the October inventory-drawdown season pulls on seaborne supply

What the data confirms is clear enough. Prices are elevated, with low-CV coal at $77.00/t as of 17 September 2026. The dedicated fleet demand floor is intact. The substitution constraint is real. The one thing the data cannot yet tell you is duration, and duration is what separates a pricing event from a structural one.

So the question to hold is not whether India imports less coal in 2026. It probably will, per the IEA’s 160 MT projection. The sharper question is whether the dedicated fleet faces a supply-price squeeze in the October-December window that the annual aggregate will quietly conceal.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions. Past performance does not guarantee future results. Financial projections are subject to market conditions and various risk factors, and forward-looking statements are speculative and subject to change based on market developments.