Australia's LNG operators have accumulated PRRT deduction credits in excess of $238 billion. The PRRT cannot bite.

The Petroleum Resource Rent Tax was introduced in 1987 and extended to onshore projects in 2012. It was sold to the public as a 40% rent tax on the super-profits of the petroleum sector. In 39 years, no LNG project has ever paid it04. VERIFIED

The mechanism is uplift. Project costs that cannot be deducted in the year they are incurred are carried forward and uplifted, originally at the long-term bond rate plus 15 percentage points, more recently at lower but still generous rates after the 2019 amendments09. By the time a project begins to generate the gross profits PRRT was designed to tax, its accumulated and uplifted deductions exceed any plausible profit stream for the life of the asset. The headline rate of 40% applies to a number that, in practice, is never positive.

Zero PRRT, by design

The Australian National Audit Office reviewed PRRT administration in its 2008-09 performance audit. It found the Tax Office's administration of the regime to be sound. It made no finding that the regime was malfunctioning. The regime was operating exactly as the statute required05. VERIFIED

The ATO Corporate Tax Transparency Report for 2022-23 puts numbers on the per-company position06:

• Santos has reported approximately $47 billion of income across its decade of LNG operations and paid roughly $3.1 million in income tax over the same period.
• Shell's QCLNG entity has reported approximately $31 billion of revenue and paid $0 in income tax across the period covered by the Transparency Report.
• INPEX (Ichthys) has reported approximately $43 billion of cumulative sales and paid approximately $6.7 million in income tax across the same period.
• Woodside is the genuine outlier: $2.87 billion in corporate income tax across the group, and approximately $936 million in PRRT across three Woodside entities in FY2022-2306. The PRRT is principally on Bass Strait oil operations (the Woodside-Esso joint venture) and on the North West Shelf (NWS). The NWS was brought into the PRRT regime on 1 July 201212, but operates under a hybrid arrangement: royalties and excise paid before 2012 are credited against PRRT liability under a gross-up mechanism, materially reducing its net PRRT relative to a clean-PRRT project. The Bass Strait share of Woodside's PRRT was approximately $695 million; the NWS share approximately $175 million; the parent entity contributed the remaining $66 million06.

Almost none of Australia's PRRT collections come from new LNG operations. The full FY2022-23 distribution across the 11 reporting entities, sourced directly from the ATO Corporate Tax Transparency PRRT details sheet06:

The figures above are read directly from the PRRT details sheet of the ATO Corporate Tax Transparency XLSX, accessed via data.gov.au06. Press reporting on these per-entity numbers has at times been inconsistent - published figures for Woodside's group total, for Shell's PRRT contribution, and for which projects entered the PRRT-paying population in FY2023-24 do not all reconcile against the primary file. Where this article's numbers and earlier press citations differ, the primary file is the controlling source. Readers can audit the table cell-by-cell against the XLSX.

VERIFIED The PRRT receipts come overwhelmingly from projects that are not Australian LNG export operations. Bass Strait, operated jointly by Woodside and Esso/ExxonMobil and predominantly an oil and condensate field, alone accounts for approximately $1,314 million, or 70% of FY2022-23 PRRT receipts. The North West Shelf, which produces gas and condensate but operates under the legacy hybrid regime where pre-2012 royalties and excise are credited against PRRT, contributes approximately $237 million, or 13%. Cooper Basin and other smaller offshore projects make up the residual. The Australian LNG export projects that dominate the public debate about gas taxation - Chevron's Gorgon and Wheatstone, INPEX's Ichthys, Shell's QCLNG and Prelude, Woodside's Pluto - paid zero PRRT in FY2022-23. None of these projects appears in the ATO Corporate Tax Transparency PRRT details sheet for that year06.

When industry representatives describe an annual PRRT contribution from "the gas sector" of one to two billion dollars, the figure is correct only at the level of corporate group aggregation across diversified portfolios. At the project level, the LNG export projects under the standard PRRT regime contributed nothing in FY2022-23. The receipts that do exist come from offshore oil (Bass Strait), from the NWS legacy hybrid, and from older conventional oil and gas. The PRRT is doing real work on conventional petroleum production and on the pre-2012 legacy. It is not doing real work on Australia's LNG export industry.

Per-company accumulated PRRT deduction credit balances are not publicly disclosed anywhere. The 2017 ATO disclosure of the aggregate $238 billion figure remains the only published number01; no comparable per-company breakdown has ever been published. Each company's credit pool is held in internal ATO tax records and does not appear in the Corporate Tax Transparency Report, in company annual reports, or in any other public dataset. The Senate Select Committee on the Taxation of Gas Resources, reporting on 7 May 2026, may produce an updated aggregate figure02; an updated per-company disaggregation has never been on the public agenda.

The mechanism that produces this outcome is uplift compounded over decades. Project costs that cannot be deducted in the year they are incurred are carried forward and grow each year by an uplift rate. Until 1 July 2019, exploration expenditure carried forward at the long-term bond rate plus 15 percentage points; general project expenditure at the long-term bond rate plus 5 points09. The Treasury Laws Amendment (2019 Petroleum Resource Rent Tax Reforms No. 1) Act 2019 reduced the exploration uplift to LTBR plus 5 points from 1 July 2019, and stepped pre-2019 exploration balances down to the same LTBR plus 5 rate on the same date09. The Treasury Laws Amendment (Tax Accountability and Fairness) Act introduced a 90% cap on the deductions claimable against PRRT assessable income in any year, with denied deductions carried forward at long-term bond rate plus 1 percentage point11. The cap took effect 1 July 2023.

In FY2023-24, the first full year under the cap, the PRRT-paying population grew from 11 entities to 16 and the new entrants are informative13. Woodside Burrup Pty Ltd (the Pluto LNG entity) appeared in the PRRT data for the first time at $151 million; Woodside Energy Julimar Pty Ltd ($38 million) and KUFPEC Australia (Julimar) Pty Ltd ($21 million), both Wheatstone partners, also appeared for the first time. Pluto LNG paying PRRT for the first time, six years into the project, is consistent with cap attribution; neither the ATO nor Treasury has formally attributed the entry to the cap. Smaller new entrants included Midocean Pluto ($7m), Kansai Electric Power Australia ($7m, NWS partner), Vermilion Oil and Gas Australia ($4m), and MEPAU Otway Basin ($3m). Chevron's Gorgon and Wheatstone projects did not pay PRRT in FY2023-24; Chevron's first PRRT payment was made in August 2025 and will appear in the FY2025-26 transparency data when it is released.

Despite the cap and the new entrants, total PRRT receipts fell from $1,867 million in FY2022-23 to $1,483 million in FY2023-2413. Bass Strait receipts dropped roughly $570 million on lower oil prices and volumes, more than offsetting the $230 million the cap brought in from new LNG-side entrants. VERIFIED The cap binds at the boundary between deduction-stack-exhausted and deduction-stack-positive - principally Pluto LNG and Wheatstone partner stakes. It does not bind on producers whose accumulated and uplifted deductions still exceed any plausible profit stream for the life of the asset, which remains the position of Chevron's Gorgon and Wheatstone, INPEX's Ichthys, and Shell's QCLNG. A reform that retains the deduction architecture and merely raises the headline rate of 40% applies a larger negative number to a base that is structurally not yet positive for the projects that are not yet paying. The deduction stack is the design, not a flaw in the design.

The Australia Institute's comparative analysis puts Australia's total government take on LNG at approximately 2% of export value. Qatar takes approximately 23%. Norway takes approximately 64%03. ESTIMATED

"Short-term tax increases and ad hoc changes risk deterring investment, reducing domestic supply over time and ultimately diminishing rather than increasing long-term government revenue while also weakening Australia's energy security."

Graham Tiver, Chief Financial Officer, Woodside Energy. Senate Select Committee on the Taxation of Gas Resources, Perth hearing, 24 April 2026.

Why the export levy bites

A 25% export levy applies at the point of export, on the gross sale value of LNG sent abroad. It is calculated on volumes shipped and prices realised. There is no deduction stack to absorb it07. VERIFIED

The Australia Institute, in its December 2025 analysis The Great Gas Rip Off, estimates a 25% gas export tax would raise approximately $17 billion per year while PRRT continues to collect zero from LNG operations08. ESTIMATED An equivalent uplift to the PRRT rate from 40% to 60% would raise approximately $0 over the same period. The accumulated deduction balance simply absorbs the increase. The deduction stack is the design, not a flaw in the design09.

The point-of-export mechanism is not novel. Japan has imposed a tax on imported oil and gas since 1978 and extended it to coal in 2003. Over the last five years, that tax has averaged AUD $8 billion per year for the Japanese Government, of which approximately $1.8 billion per year is collected on imports of Australian gas alone10. ESTIMATED Australian PRRT receipts have averaged approximately $1.4 billion per year across the same five-year window per the Australia Institute's comparative analysis10; the most recent two single-year actuals reported above ($1.87B in FY2022-23, $1.48B in FY2023-24) sit higher than that longer-window average. The Japanese state collects more tax on Australian gas than the Australian state does. The Australia Institute's counterfactual modelling indicates that a 25% LNG export levy applied from 2022 would have raised approximately $69 billion to date, and that each week of further delay forgoes roughly $350 million in public revenue10. ESTIMATED

The Senate Select Committee on the Taxation of Gas Resources, established 30 March 2026 under Senator Steph Hodgins-May, is the current parliamentary venue for the debate02. The Perth hearing of 24 April 2026 produced direct testimony from industry representatives including the Woodside CFO quoted above and the Chief Executive of the Australian Energy Producers, Samantha McCulloch.

What this means

A reader could conclude that the PRRT is broken and needs reform. The ATO submission, the ANAO audit, and the Corporate Tax Transparency data together support a narrower and more useful conclusion: the PRRT is not broken. It is operating exactly as it was drafted to operate.

A reform that retains the deduction architecture while raising the headline rate raises no revenue. A reform that disallows uplift on legacy balances would raise revenue but faces a constitutional acquisition argument. A levy at the point of export, applied to a saleable commodity at a known price, is the only instrument that touches the cashflow before the deduction stack consumes it. ILLUSTRATIVE A modelled 25% export levy clears the constitutional question, raises material revenue, and does so without amending the PRRT statute at all.

Whether the government will adopt it is a separate question. The mechanics, on the public record, are not in dispute.