On 21 July 2025 Dawn reported that Prime Minister Shehbaz Sharif had, for a third time, ordered the Power Division to stand down from a campaign to revise net-metering buyback rates before a formal summary reached his office. The shelved plan, as described, sought to cut buyback from about Rs 27 to about Rs 11.3 per unit, alongside revised settlement mechanisms. The episode is more than political weather. It reveals the collision between cost-of-service regulation and a solarised middle class that does not trust the grid.
Power Minister Awais Leghari’s public comments days earlier framed the problem as unjustified returns and surplus capacity risk, while promising that existing adopters under policy would not be penalised. That distinction between legacy and new systems is the only politically viable bridge. The Power Division’s difficulty has been selling a bridge while running a campaign that sounds like a war on rooftops.
Official estimates cited in the same reporting put net-metered connections around 325,000 with about 6,500 MW of installed capacity, concentrated especially in Lahore and other urban centres. Whether every megawatt figure is audited, the direction is unmistakable: distributed solar is now system-relevant. Hybrid non-exporting systems, which officials called more dangerous for demand erosion, complicate any policy that only targets export credits.
Transition Economics Institute’s reading is that repeated pauses without an alternative package deepen uncertainty. Installers freeze. Banks hesitate. Households rush applications to beat rumoured cutoffs, creating administrative piles. A pause is useful only if it buys time for a consulted regulation with grandfathering, avoided-cost credits, and fixed charges. A pause that simply returns to the status quo leaves the cost-shift intact and the next campaign inevitable.
Public communication failed. Engaging the Ministry of Information to build a narrative against net metering, as officials described, treated citizens as targets rather than counterparties. Energy policy needs hearings, published models, and phased rules. It does not need a narrative war.
Cabinet rejection of earlier ECC-cleared changes should have triggered a stakeholder process, not a third covert summary. NEPRA’s regulatory track is the proper venue for buyback methodology. Political overrides that oscillate monthly destroy the regulator’s craft.
For non-solar consumers, the pause is not victory. They still fund capacity payments while volumetric sales to affluent prosumers shrink. Their interests need representation too, through transparent fixed-charge design rather than through sudden buyback confiscation. July 2025 should mark the end of campaign mode and the start of rulemaking mode.
Institutional accountability remains the missing hinge. NEPRA, the Power Division, CPPA-G, the system operator, and the DISCOs each hold a piece of the puzzle, yet none owns the full cash-conversion cycle. Until reporting, incentives, and penalties are aligned to the same monthly cash target, reform statements will continue to outrun results. Transition Economics Institute will keep measuring progress by whether billed energy turns into settled rupees, whether fixed generation obligations shrink in line with the demand profile, and whether consumers see durable relief rather than a temporary rebate financed by another round of arrears.