Pakistan Cuts Solar Export Rates 50%, Grandfathers Old Deals, but Approval Speed Masks the Payback Crash

On February 9, 2026, Pakistan's National Electric Power Regulatory Authority (NEPRA) announced a seismic shift in how prosumers, households and businesses generating their own power, get paid for surplus electricity fed to the grid. The Prosumer Regulations 2026 scrapped net metering, the 1:1 credit system that had governed solar since 2015, and replaced it with net billing: exports would be compensated at the national average energy purchase price rather than the retail rate prosumers pay to buy power back.^[5] Six months later, in August, NEPRA streamlined approvals for systems up to 25 kilowatts, delegating authority from the federal regulator to local distribution companies (DISCOs).^[9] The news outlets covering the August move celebrated it as consumer-friendly deregulation. What they missed is the April mechanism, the one that matters for a system's economics.

Under the old net metering rules, a prosumer who exported 100 kilowatt-hours and consumed 100 kilowatt-hours received a credit at the same rate paid for consumption, a true 1:1 swap. The new net billing system severs that symmetry. Exports are now credited at roughly Rs. 11 (about $0.13 USD) to Rs. 13 (about $0.16 USD) per kilowatt-hour, the wholesale energy purchase price, while prosumers continue buying grid power at the full retail tariff, Rs. 44 (about $0.53 USD) to Rs. 60 (about $0.72 USD) per kilowatt-hour depending on consumption slab and location.^[7],[8] This is an effective export-rate cut of roughly 50 percent compared to the old system. The payback period on a residential solar installation lengthens accordingly; the financial case that drove Pakistan's explosion from near-zero rooftop solar to 6,000 megawatts of capacity and 466,000 prosumers^[3] has been rewritten in real time, mid-project for families already committed to the transition.

The approval streamlining, delegating permitting to DISCOs, is genuine deregulation and likely lowers soft costs for small systems. But it obscures what happened in February. Utilities worldwide use this same playbook: sweeten the administrative path while narrowing the financial return, so the announcement noise drowns the payback math. California's Net Billing Tariff (NEM 3.0) cut export rates by roughly 75 percent compared to the prior retail-credit regime; installations collapsed in 2023 and 2024, with battery attach rates jumping from minority to majority as self-consumption became the only way to recover value. Pakistan is running the same sequence at a smaller rate cut, but the direction is identical.

The sting is sharpened by grandfathering. NEPRA's April amendment to the regulations protected existing net metering agreements, prosumers who interconnected before February 9, 2026, kept their old 1:1 export rates for the duration of their contracts, typically 10 years or longer.^[2],[6] For new installations, the net billing trap applies immediately. This splits the market: established prosumers keep their favorable rates while new entrants face a halved export credit. The political effect is to muffle opposition, existing solar owners are shielded, so they have no incentive to lobby against the change, while demand destruction falls on future installers and the supply chain that depends on them. Installers and equipment vendors in Pakistan, many of whom ramped up capacity to meet the pre-2026 boom, now face a suddenly thinner margin on new sales and longer payback horizons that shrink the addressable market.

The deeper mechanism is rate design as discipline. Net billing works by decoupling the export price from the import price; when a prosumer can no longer bank a credit at the rate they pay, the financial case for oversizing systems evaporates. Under net metering, installing a 10-kilowatt system to cover 120 percent of annual consumption made sense, the excess units were nearly as valuable as the consumed ones, so the risk of underestimation was cheap insurance. Under net billing, oversizing shrinks the return on each extra kilowatt exported at half price; a rational system-designer now targets consumption more precisely and pairs storage to capture self-use gains. This is a feature, not a bug: it shifts the solar market from export-centric design to storage-first design. In countries with cheaper battery costs and local assembly capacity, this could be salutary; in Pakistan, where battery costs remain imported and expensive, it simply flattens demand.

The grandfathering clause reveals the political cost-benefit. NEPRA could have imposed net billing on all prosumers, old and new, in a single stroke; instead it carved out a protected class. This is generous to 466,000 existing solar users and terrible policy for the next cohort, because it leaves no constituency pushing back. The alternative, honest retroactive application to new commercial and industrial prosumers while protecting residential net metering at the 1:1 rate, would be economically coherent (commercial prosumers have load profiles that export less and less reliably) and politically survivable (protecting households keeps the consumer coalition alive). Instead, NEPRA created a two-tier market that will shrivel the new-installation pipeline and leave rooftop solar's momentum stalling exactly where it matters: among lower-income households turning to solar to escape load-shedding and rising tariffs.