The Australian National Electricity Market (NEM) is ostensibly designed as a competitive, user-pays system where efficient pricing signals guide investment and consumption. However, a forensic examination of the underlying cost-recovery mechanisms, specifically within the regulated-monopoly components, reveals a profound deviation from these economic principles. This report demonstrates that the NEM has structurally devolved into a mechanism of regressive wealth transfer. The current regulatory framework, rather than allocating costs based on causation, effectively socialises the capital expenses of the energy transition while allowing privileged asset classes to privatise the benefits.

The audit identifies a tripartite hierarchy of market participants:

• Tier 1 (Heavy Industry): “Trade-Exposed” entities that utilise regulatory exemptions and bespoke connection deeds to bypass the shared costs of the grid.
• Tier 2 (Solar Owners): Asset-rich households that leverage Distributed Energy Resources (DER) to avoid volumetric contributions to fixed infrastructure costs, effectively engaging in a form of regulatory arbitrage.
• Tier 3 (Captive Renters): The residual customer base, comprising non-solar households, tenants, and apartment dwellers, who possess neither the political leverage of industry nor the capital leverage of solar owners.

This report synthesises data from the Australian Energy Regulator (AER), the Australian Energy Market Commission (AEMC), the Australian Competition and Consumer Commission (ACCC), and specific Distribution Network Service Provider (DNSP) pricing proposals for the 2024-2029 regulatory period. The analysis confirms that as Tier 1 and Tier 2 participants reduce their financial contributions to the system’s fixed costs, the burden is mathematically re-allocated to the captive Tier 3 base. This phenomenon is not merely an unintended consequence of policy but a structural feature of the revenue cap regulation mechanism, creating a “death spiral” of rising unit costs for those least able to pay.

This report examines four structural mechanisms: the capitalisation of the network monopolies (RAB), the cross-subsidies inherent in solar integration, the legislative exemptions for emissions-intensive industry (EITE), and the defensive inflation of fixed daily supply charges.

The single largest component of a residential electricity bill, often exceeding 40% of the total cost, is the charge for “Network Services.” These charges recover the costs of the transmission and distribution poles and wires. Unlike the competitive wholesale market, network costs are determined by a regulatory determination process that guarantees a return on capital.

The Regulatory Asset Base (RAB): A Mechanism of Perpetual Liability

The economic engine of the Distribution Network Service Provider (DNSP) is the Regulatory Asset Base (RAB). The RAB represents the accumulated value of past capital investments (Capex) in the grid, adjusted for inflation and depreciation. Under the National Electricity Rules (NER), DNSPs are entitled to earn a return on this asset base, calculated via the Weighted Average Cost of Capital (WACC).

The Legacy of “Gold-Plating” (2006-2013)

The current cost burden borne by Tier 3 consumers is inextricably linked to the investment decisions of the past. Between 2006 and 2013, the NEM experienced a surge in network capital expenditure, often referred to as “gold-plating.” Driven by stringent reliability standards and a regulatory framework that incentivised asset accumulation, networks expanded capacity significantly beyond what was required by actual demand growth.

The AER’s State of the Energy Market reporting explicitly acknowledges this legacy. It states that consumers will continue to pay for the overinvestment in network assets that occurred during this period for the remainder of the economic lives of those assets, a timeframe that extends up to 50 years.¹ This creates a generational liability. The “mortgage” on the grid infrastructure built nearly two decades ago is not being written down based on utilisation; it is being serviced by current ratepayers. As total grid consumption plateaus or declines due to energy efficiency and solar self-consumption, the unit cost required to service this fixed asset base inevitably rises, concentrating the debt on those who rely on the grid for 100% of their energy.

Current RAB Valuations and Revenue Determinations (2024-2029)

The most recent regulatory determinations for the 2024-2029 period reveal that the RAB continues to grow, ensuring that the revenue requirement for networks remains high.

Ausgrid (New South Wales): The AER’s Final Decision for Ausgrid’s 2024-29 distribution determination approves a total revenue recovery of $9,980.9 million ($ nominal) over the five-year period.² This revenue requirement is built upon an Opening RAB of approximately $16.55 billion as of July 1, 2024.³ Despite the maturity of the network, the RAB is projected to increase rather than depreciate. The decision forecasts a Closing RAB of $18.26 billion by June 30, 2029.³ This growth is driven by new capital expenditure (net capex) of over $550 million annually, alongside indexation. For the Tier 3 consumer, this signals that the “network mortgage” is increasing, not decreasing.

Table 1: Ausgrid RAB Trajectory 2024-2029 ($ Million, Nominal)

Financial Year	2024-25	2025-26	2026-27	2027-28	2028-29
Opening RAB	16,551.1	17,004.0	17,456.1	17,857.0	18,257.7
Net Capex	613.7	578.2	607.5	575.6	552.4
Indexation (Inflation)	426.5	440.2	452.3	464.3	475.0
Less: Depreciation	(524.9)	(565.5)	(607.7)	(639.0)	(626.6)
Closing RAB	17,004.0	17,456.1	17,857.0	18,257.7	18,658.5
Source: AER Final Decision Ausgrid 2024-29, Attachment 2 3

The table above illustrates the mechanics of asset inflation. Indexation (adjusting the asset base for inflation) adds nearly half a billion dollars to the RAB annually, almost negating the impact of depreciation. This ensures that the asset base and the return on capital derived from it, remains robust, protecting the DNSP’s revenue stream while inflating the cost base for consumers.

The WACC Guarantee

The rate of return allowed on this asset base is a critical driver of costs. The AER applies a “Rate of Return Instrument” to calculate the Weighted Average Cost of Capital (WACC). For the 2024-2029 period, the AER has applied the 2022 Instrument, which has seen an increase in the nominal vanilla WACC due to rising risk-free rates (government bond yields).

For Essential Energy, the AER Final Decision set a nominal vanilla WACC of 5.92% for the 2024-29 period, comprised of a return on equity of approximately 7.92% and a return on debt of 4.59%.⁴ For Ausgrid, the draft decision indicated a similar trajectory, with the WACC acting as the multiplier on the multi-billion dollar RAB. A WACC of ~6% on a $17 billion asset base generates over $1 billion annually in pure financing costs. This “return on capital” is the profit component for the network owners (often state governments or foreign infrastructure funds) and is a non-negotiable charge passed through to retailers and then to consumers.

Industrial Bypass: The “Prudential Discount” and TUOS Exemptions

While the RAB creates a fixed liability for the residential base, the “User-Pays” principle is frequently suspended for Tier 1 Industrial users. The regulatory framework acknowledges the threat of “economic bypass”, where a large user could build its own generation or leave the grid entirely, and responds by offering discounted access.

Transmission Use of System (TUOS) Methodology

Transmission networks recover their costs via Transmission Use of System (TUOS) charges. Standard methodology allocates these costs based on peak demand and energy usage. However, the NER allows for “Prudential Discounts” or “Prescribed TUOS discounts.” If a large user (e.g., a smelter) can demonstrate that the cost of grid transmission exceeds the cost of a standalone alternative, the Transmission Network Service Provider (TNSP) is permitted to offer a discounted rate to retain the load.⁵

The forensic implication of this mechanism is cost shifting. The TNSP operates under a revenue cap; it is entitled to recover its Maximum Allowed Revenue (MAR) regardless of who pays. When a discount is granted to a Tier 1 user, the unrecovered revenue is not written off. Instead, it is re-allocated to the “non-locational” component of the TUOS charge, which is levied on the remaining customer base. Effectively, Tier 3 households pay a surcharge to subsidise the retention of Tier 1 industries on the grid.

Case Study: Tomago Aluminium (NSW)

Tomago Aluminium is the largest single electricity consumer in New South Wales, accounting for over 10% of the state’s demand. Its relationship with the grid exemplifies the Tier 1 privilege. The smelter operates under bespoke power arrangements that insulate it from the full cost reflectivity of the market. In late 2024 and early 2025, facing the expiration of its electricity contracts in 2028, Tomago became the subject of intense government negotiation. The outcome, announced by Prime Minister Anthony Albanese, involves a “fixed-price power purchase agreement” supported by the federal and state governments to keep the smelter operational beyond 2028.⁷

This arrangement effectively transfers the risk of future energy price volatility from the private operator (Rio Tinto/partners) to the public sector (taxpayers) and potentially the broader consumer base via “firming” costs. Furthermore, transmission charging methodologies for such large loads often differ significantly from residential tariffs. While households pay for the “shared network,” industrial bypass agreements often argue that the user should only pay for the assets solely dedicated to them, exempting them from the broader costs of the meshed network they rely on for backup and stability.⁹

Case Study: Portland Aluminium (Victoria)

The Portland Smelter in Victoria provides a documented precedent for direct wealth transfer. Following power outages in 2016 and rising costs, the Victorian Government entered into a support agreement. Forensic audits of this period reveal that the government agreed to waive fixed line transmission charges for the smelter, a subsidy valued at approximately $40 million over four years.¹⁰ Simultaneously, the smelter participates in the Reliability and Emergency Reserve Trader (RERT) mechanism. Under RERT, the Australian Energy Market Operator (AEMO) pays large users to reduce consumption during grid emergencies. This creates a perverse duality: Tier 1 Industry is paid millions to reduce demand during peaks, while Tier 3 households are charged punitive peak rates to achieve the same outcome. The cost of RERT payments is recovered from market customers, ultimately appearing on household bills.

The Network Cost Disparity

The disparity in the “Network Component” of the bill highlights the regressivity of the system. For a typical residential customer in the Ausgrid zone, network charges (Distribution + Transmission) constitute approximately 22% to 40% of the total bill, depending on the retail markup and specific tariff.² This fixed and semi-fixed cost is unavoidable. In contrast, for Tier 1 Industrial users, the network component is often a much smaller fraction of their total energy cost, diluted by their massive volume and suppressed by prudential discounts and special connection deeds. The “energy” (wholesale) component dominates their bill, which they can hedge directly, unlike the residential consumer who pays a bundled rate.

This section investigates the integration of Distributed Energy Resources (DER), specifically rooftop solar photovoltaics (PV). While celebrated as a decarbonisation tool, the current tariff and recovery structures governing solar integration have created a structural cross-subsidy that penalises non-solar households.

The Physics of Inequity: Voltage and Reverse Flow

The distribution grid was engineered for one-way power flow: from the zone substation down to the household. The widespread adoption of rooftop solar has introduced two-way flows, creating specific technical liabilities for the DNSP:

1. Voltage Rise: The export of power from residential inverters raises the voltage on the low-voltage (LV) network. To prevent inverters from tripping off (which occurs at 253V-258V), DNSPs must invest in voltage regulation measures, such as tap-changing transformers and line augmentation (re-conductoring) to reduce impedance.
2. Thermal Constraints: Reverse flows can exceed the thermal ratings of transformers designed only for peak import loads.

Forensic Finding: These costs are classified as “Augmentation” or “DER Integration” expenditure. Under the prevailing “common postage stamp” pricing approach, these capital costs are added to the RAB and recovered from the general customer base via standard network tariffs. Consequently, a Tier 3 renter living in an apartment pays for the transformer upgrade required to allow their Tier 2 neighbour to export excess solar generation to the market.

Quantifying the Cross-Subsidy

The existence and magnitude of this cross-subsidy have been documented by major regulatory and economic bodies.

• ACCC Retail Electricity Pricing Inquiry (2018): The ACCC’s comprehensive review explicitly identified the solar cross-subsidy. It noted that solar customers, by netting off their consumption against their generation, significantly reduce their contribution to the recovery of fixed network costs. Since the network costs are largely fixed (sunk costs of poles and wires), the “residual” cost that is not recovered from solar households must be recovered from non-solar households through higher volumetric rates.¹²
• Macquarie Research & AEMC: Analysis by Macquarie Research and the AEMC has framed this as a wealth transfer. Macquarie’s analysis suggested that the cross-subsidy flows from younger, non-homeowning demographics (who cannot install solar) to older, asset-rich homeowners. The “death spiral” effect ensures that as more wealthy users exit the funding pool, the burden concentrates on the remainder.¹³
• Dollar Value Estimates: Various submissions and reports have attempted to quantify this transfer. Estimates for the “hidden tax” paid by non-solar households range from $50 to over $200 per year, depending on the network topology and the penetration of solar.¹⁴ This amount represents the difference between the network costs a solar user causes versus what they pay, a deficit that is cross-subsidised by the non-solar base.

The “Residual Cost” Recovery Mechanism

To understand how the transfer occurs, one must analyse the tariff structure.

1. Fixed vs. Variable Costs: A DNSP’s cost structure is roughly 90% fixed (capital assets, debt service) and 10% variable.
2. Variable Revenue Recovery: Historically, tariffs recovered revenue primarily through variable (c/kWh) charges.
3. The Solar Effect: A Tier 2 Solar Owner generates electricity behind the meter, reducing their grid purchase volume by 50-80%. Consequently, they avoid 50-80% of the variable network charges.
4. The Revenue Cap Trap: Because the AER guarantees the DNSP a fixed total revenue (Revenue Cap), any shortfall in volume caused by solar self-consumption must be met by increasing the unit price (c/kWh) for the remaining volume.
5. The Result: The Tier 3 Renter, who cannot reduce their volume, pays the higher unit rate on 100% of their consumption. They are effectively paying the fixed network costs that the solar owner has avoided.

Regulatory Failures and “Export Tariffs”

In recognition of this inequity, the AEMC modified the rules in 2021 to allow DNSPs to implement “two-way pricing” or export tariffs, effectively charging solar owners for the use of the grid to export power.¹⁶

• Implementation Lag: While Ausgrid, Energex, and SA Power Networks are moving toward these tariffs (e.g., Ausgrid’s “Export Tariff” opting for a free threshold before charging), the rollout is gradual and often “opt-in” for existing customers or limited to new connections.
• Grandfathering: Legacy solar systems are often grandfathered onto old tariff structures, preserving their ability to free-ride on the network costs.
• Meter Compatibility: A significant portion of the rental stock relies on legacy accumulation meters (“dumb meters”). These customers cannot access time-of-use tariffs that might offer cheaper off-peak rates (the “solar soak” periods). They are trapped on flat-rate standing offers where the inflated variable rate penalises them most severely.¹⁷

Table 2: Network Contribution Discrepancy

Consumer Profile	Grid Usage (Physical)	Network Contribution (Financial)	Net Impact
Tier 2: Solar Owner	High peak demand (evening import) + High export stress (midday).	Low: Avoids variable charges during day; pays only for net imports.	Subsidised: imposes costs (voltage, peak) but pays less than cost-to-serve.
Tier 3: Non-Solar Renter	Standard usage profile; low peak variance.	High: Pays variable charges on 100% of energy consumed.	Subsidiser: Pays premiums to cover the revenue shortfall left by Tier 2.

This section identifies a direct legislative wealth transfer embedded in the environmental policy framework. The Renewable Energy Target (RET) and the Small-scale Renewable Energy Scheme (SRES) mandate that electricity retailers purchase certificates to fund renewable generation. These costs are passed through to consumers. However, the legislation includes a “trapdoor” for heavy industry known as the Emissions-Intensive Trade-Exposed (EITE) exemption.

The Mechanism of EITE Exemptions

The Renewable Energy (Electricity) Act 2000 establishes the EITE framework to prevent “carbon leakage”, the theoretical risk that Australian industries would relocate to jurisdictions with laxer environmental standards if forced to pay green levies.

• Exemption Scope: Activities defined as “highly emissions-intensive” receive an exemption from 90% of their RET liability. In practice, the formula for “partial exemptions” often results in near-total avoidance of these costs for major smelters and refineries.¹⁸
• Eligible Industries: The Clean Energy Regulator (CER) maintains a register of EITE activities. These include Aluminium Smelting, Alumina Refining, Petroleum Refining, Production of Ammonia, Manufacture of Newsprint, and Integrated Steel Manufacturing.²⁰

The Cost Re-Allocation Shell Game

The critical forensic finding is the mechanism of “Cost Re-Allocation.” The cost of the exemptions granted to Industry is not absorbed by the Federal Government (i.e., funded by general taxation). Instead, it is re-allocated to the remaining electricity users.

The Formulaic Transfer:

The mechanism operates through the calculation of the Renewable Power Percentage (RPP) and the Small-scale Technology Percentage (STP).

The RPP is calculated as:

As the volume of EITE exemptions increases (removing the massive loads of smelters from the denominator), the RPP percentage must increase to recover the fixed target of renewable generation. This higher percentage is then applied to the liable acquisitions of retailers serving households and small businesses.

Forensic Consequence: Every megawatt-hour exempted for Rio Tinto or Alcoa directly increases the RPP/STP liability attached to the megawatt-hour consumed by a Tier 3 renter. The non-exempt customer base is effectively paying a surcharge to cover the green liability that industry has been excused from.

Quantifying the Exemption Value

Data from the Clean Energy Regulator’s Exemption Certificate Register provides the scale of this transfer.

• Aluminium Smelting: For the 2024 application year, exemption certificates issued for “Aluminium Smelting” covered 22,822,998 MWh (approx. 22.8 TWh) of electricity.²⁰
• Alumina Refining: Exemption certificates for “Alumina Refining” covered millions more MWh.
• Financial Value:

• LGC Value: With Large-scale Generation Certificates (LGCs) trading in the range of $40-$50 per certificate, a 22 million MWh exemption represents a liability avoidance of over $1 billion in LGC costs alone.
• STC Value: The SRES (rooftop solar subsidy) is also recovered via this mechanism. The Register lists a specific “Estimated STC Value” for exemptions. For example, Alcoa Portland Aluminium’s exemption was valued at over $27 million in STC liability for a single year.²¹

Table 3: The EITE Wealth Transfer Matrix

Metric	Tier 1: EITE Industry	Tier 3: Residential/Small Biz
RET/SRES Liability	Exempt: ~90-100% exemption.	Surcharged: Pays >100% of “fair share” to cover shortfall.
Exemption Volume	>25 TWh (nationally) removed from liability base.	N/A
Financial Impact	Saves >$1 Billion annually in green levies.	Bills are inflated by ~3-5% to fund the industrial exemption.
Beneficiary	Shareholders of Trade-Exposed Entities.	N/A

This establishes a direct financial link: The Tier 3 Renter pays for the solar panels on the Tier 2 roof (via SRES) and pays the green liability for the Tier 1 Smelter (via RPP inflation).

This final section analyses the structural changes in retail pricing. As grid consumption per household declines, driven by solar adoption and energy efficiency, DNSPs and retailers have responded by shifting revenue recovery from the “variable” component (c/kWh) to the “fixed” component (Daily Supply Charge). This strategy insulates their revenue from the “death spiral” but imposes a regressive poll tax on the grid’s poorest users.

Historical Analysis of Supply Charges (2020-2025)

A longitudinal comparison of pricing proposals, the AER’s Default Market Offer (DMO), and the Victorian Default Offer (VDO) reveals a systematic inflation of the fixed charge.

Victoria (Powercor Zone)

The Powercor distribution zone serves western Victoria and has high solar penetration.

• 2020: The Victorian Default Offer (VDO) established a benchmark daily supply charge. In 2020, standing offer prices typically featured a supply charge of approximately $1.26 per day (inclusive of GST).²²
• 2025: The Essential Services Commission’s Final Decision for the 2025-26 VDO sets the daily supply charge for Powercor at $1.5905 per day.²³
• Trend: This represents an increase of approximately 26% in the fixed cost of access. A household in this zone now pays over $580 per year just to be connected, before consuming a single kilowatt-hour.

New South Wales (Ausgrid Zone)

• 2020/21: Network price lists and the DMO indicated daily supply charges generally in the range of 88 cents to 100 cents per day for residential customers.²⁴
• 2024/25: The Ausgrid Network Price List for 2024-25 lists the standing charge for the Residential Demand tariff. Retail offers benchmarked against the DMO now frequently feature daily supply charges exceeding $1.25 per day, with some market offers reaching as high as $2.84 per day.²⁵
• Mechanism: The increase is partly driven by the recovery of “residual” costs, those fixed network costs that can no longer be recovered via volumetric charges due to the erosion of the consumption base by solar.

Queensland (Energex Zone)

• Trend: The Queensland Competition Authority (QCA) and AER determinations for Energex show a similar trajectory. The “Fixed NEM Fee” and other jurisdictional levies are now explicitly recovered via the daily supply charge to ensure stability.²⁷ The inflation of this charge is a direct counter-measure to Queensland’s world-leading rooftop solar penetration.

The Regressive Impact on Tier 3

The inflation of the Daily Supply Charge is inherently regressive because it is insensitive to income or usage.

• The “Thrift” Penalty: Low-income households often attempt to manage their energy poverty by rationing usage (e.g., heating less, turning off lights). However, as the fixed-charge component of the bill increases, the efficacy of this strategy diminishes. A renter who reduces their consumption by 20% may see only a 10% reduction in their bill because the fixed charge remains unchanged.
• The Solar Shield: Conversely, a Tier 2 solar household, despite relying heavily on the grid for backup and export services, pays the same fixed charge as the renter. The fixed charge fails to distinguish between a user who incurs high peak costs (a solar owner) and one who incurs low peak costs (an apartment dweller).

Table 4: Daily Supply Charge Inflation 2020-2025 (Indicative)

Distribution Zone	~2020 Daily Charge ($)	~2025 Daily Charge ($)	% Increase	Annual Impact
VIC (Powercor)	$1.26 22	$1.59 23	+26%	+$120/yr
NSW (Ausgrid)	~$0.90 – $1.00	~$1.25 – $1.40 (DMO)	+25-40%	+$100-$150/yr
Forensic Note	Base connection cost.	Includes “residual” recovery.	Outpaces CPI.	Unavoidable tax.

Synthesising data from the four mechanisms examined above enables us to construct a comprehensive model of the NEM’s structural wealth transfer. The market is not a single pool of users but a stratified hierarchy in which costs flow downward and benefits flow upward.

The Tier Definitions

Tier 1: The Industrial “Untouchables”

• Profile: Heavy Industry (Smelters, Refineries).
• Mechanisms:

• Network: Bypasses shared grid costs via Prudential Discounts and bespoke transmission deeds.
• Green: Exempted from 90-100% of RET/SRES liabilities via EITE certificates.
• Volatility: Shielded by government-backed fixed-price PPAs and RERT payments.
• Net Position: Subsidised.

Tier 2: The Solar Landed Gentry

• Profile: Homeowners (Detached Housing) with Capital.
• Mechanisms:

• Network: Avoids variable recovery charges via self-generation (“Death Spiral” beneficiary).
• Green: Receives SRES subsidies (upfront cash) paid for by the general pool.
• Volatility: Hedged physically by PV/Battery assets.
• Net Position: Hedged / Free-Rider.

Tier 3: The Captive Renter

• Profile: Tenants, Apartment Dwellers, Low-Income Households.
• Mechanisms:

• Network: Pays full “gold-plated” RAB costs + “residual” costs of solar integration.
• Green: Pays the “re-allocated” share of Industry’s exemption + the cost of Solar Owner subsidies.
• Fixed: Pays inflated Daily Supply Charges that negate thrift.
• Net Position: Exploited. The payer of last resort.

The Hidden Transfer Matrix

The following table summarises the invisible financial flows identified in this audit, mapping the generation of costs versus the allocation of payments.

Table 5: Forensic Map of Hidden Wealth Transfers

Cost Component	Generated By (Driver)	Paid By (Allocation)	Mechanism
Network Augmentation	Peak Demand (AC) & Solar Export (Voltage)	Tier 3 (Renters)	Solar avoids variable charge; Industry gets TUOS discounts.
SRES (Solar Subsidy)	Federal Policy to aid Tier 2	Tier 3 (Renters)	SRES levy on bills; Tier 1 is exempt, Tier 2 receives cash.
RET (Large Renewables)	Federal Policy	Tier 3 (Renters)	EITEs (Tier 1) are exempt; cost re-allocated to the non-exempt base.
Grid Reliability (RERT)	System Instability	Tier 3 (Renters)	Industry (Tier 1) is paid to reduce load; renters are charged peak rates.
Legacy Asset Debt (RAB)	2006-2013 Gold Plating	Tier 3 (Renters)	Fixed “Mortgage” recovered via volume; Renters have no volume exit.

This forensic audit confirms: The Australian energy grid has shifted from a “user-pays” model to a “regressive tax” model.

The evidence gathered from AER reports, pricing proposals, and legislative instruments demonstrates a systemic shielding of wealthy and industrial actors.

1. Tier 1 Industry utilises its economic leverage to secure “Trade Exposed” exemptions and “Prudential Discounts,” effectively opting out of the rising costs of the grid and the green transition.
2. Tier 2 Solar Owners use their capital leverage to circumvent the network’s variable recovery mechanisms, leaving the fixed costs to others.
3. Tier 3 Renters act as the financial shock absorber for the entire system. They pay the “Green Premium” that Industry avoids, and they pay the “Network Mortgage” that Solar Owners bypass.

The rise in Daily Supply Charges and the continued inflation of the Regulatory Asset Base suggest that this inequity is not a temporary aberration but a structural feature of the NEM’s design. Without significant regulatory intervention to implement true cost-reflective pricing for solar exports and to fund industrial protections via general taxation rather than electricity levies, the “Death Spiral” will continue to accelerate the transfer of wealth from the energy-poor to the energy-rich.

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