Pennsylvania Industrial Electricity Costs: The PPL Settlement, the Transmission Rider, and Why Your Bill Changed Twice
Pennsylvania industrial electricity costs are rising through two separate channels: PJM’s regional capacity market, and state-level changes to how distribution, transmission and interconnection costs are assigned to large users.
Pennsylvania industrial bills are changing through two channels that must be separated: PJM capacity prices set regionally, and state-level changes to PPL Electric’s distribution rates and transmission cost allocation. Changing suppliers will not remove either one.
A state rate case will not lower a PJM capacity clearing price, and a lower commodity rate will not correct a misapplied tariff or billing determinant. A utility audit establishes which costs are valid, which are contract-driven, which are regulated and which may be recoverable.
Published by Discovery Energy | Updated September 2026
Pennsylvania is absorbing the PJM shock through two channels
These are related issues. They are not the same issue. A Pennsylvania facility can face the PJM capacity increase and a separate state transmission or distribution adjustment on the same bill.
PJM’s 2026/2027 Base Residual Auction cleared at $329.17 per MW-day, the approved auction cap. That was roughly 22% above the prior delivery year and approximately 1,038% above the $28.92/MW-day price for the 2024/2025 delivery year. The next two auctions also cleared at the price cap: $333.44/MW-day for 2027/2028 and $325.00/MW-day for 2028/2029. Discovery Energy’s PJM capacity briefing explains how the auction price reaches a facility’s bill.
Capacity charges are generally non-bypassable. They flow through to retail bills regardless of supplier unless a fixed-rate contract specifically hedges capacity.
Pennsylvania adds a second layer. The state is deciding how the costs of new transmission infrastructure, large-load interconnections and grid expansion should be allocated. That creates a separate financial exposure for facilities whose service territory or load profile places them under changing tariff provisions.
| Channel | What changed | How it reaches the bill |
|---|---|---|
| Regional: PJM capacity | RTO capacity price rose from $28.92 (2024/25) to $329.17 per MW-day (2026/27); later auctions cleared at the cap | Supply and capacity charges, regardless of supplier unless the contract hedges capacity |
| State: PPL rate settlement | $275 million annual distribution revenue increase, effective July 1, 2026; new LP-6 large-load class | Distribution rates and, for qualifying loads, LP-6 terms |
| State: proposed transmission rider | CPTR filed September 14, 2026; would replace the Transmission Service Charge if approved | Transmission charges, once a final tariff is approved |
Do not treat a Pennsylvania electricity increase as one line-item problem
Separate the PJM capacity exposure from the Pennsylvania transmission, distribution and tariff exposure before making a procurement decision.
What happened in Pennsylvania this year
The PPL Electric settlement ended a long base-rate gap
On June 4, 2026, the Pennsylvania Public Utility Commission voted 5–0 to approve, with modifications, a $275 million PPL Electric rate settlement. It was PPL Electric’s first base distribution rate increase since 2016.
The settlement followed an original PPL request of approximately $356 million and establishes new distribution revenues effective July 1, 2026. It also includes a two-year stay-out period, providing base-rate stability through 2028.
For industrial customers, the headline revenue figure is less important than the way the settlement changes the structure around large loads, customer classes and infrastructure responsibility. The settlement provides for:
- A new LP-6 large-load rate class for customers with a peak demand of 50 MW or more at a single facility, or 75 MW or more in aggregate across facilities served at 69 kV or above within a 10-mile radius.
- Long-term service agreements with an initial term of at least 10 years.
- Load-ramp schedules and minimum load guarantees, with ramps of up to five years; guarantees can be reduced under a voluntary interruptible option.
- Security for upgrade costs, equal to the cost of the upgrades needed to serve the load.
- Exit fees if a large customer leaves before the utility recovers assigned costs.
- A non-bypassable charge assigned to large-load customers, beginning in 2027.
These provisions are aimed primarily at large new loads, including data centers and similarly intensive facilities. Most established industrial sites fall below the LP-6 thresholds, but multi-facility campuses and planned expansions should be checked against the aggregation rule. The provisions also signal a broader regulatory shift: Pennsylvania is becoming more explicit about cost causation. The settlement preserves the ability to modify LP-6 to align with the PUC’s separate statewide proceeding on large-load model tariffs (Utility Dive; PPL Form 8-K).
Wholesale costs also moved higher
PJM wholesale electricity prices averaged $82.30 per MWh in 2025, up 48.3% from 2024, and rose another 75.5% in the first quarter of 2026 compared with the same quarter a year earlier, according to Pennsylvania Independent Fiscal Office data reported by Environment+Energy Leader.
Wholesale prices do not translate one-for-one into any customer’s bill. They do show why a facility may see a higher supply component even when its physical consumption has not changed materially. An industrial bill can move because of:
- PJM capacity costs
- Energy commodity prices
- Transmission charges
- Distribution base rates
- Utility riders
- Demand charges
- Peak-load contributions
- Contract pass-through provisions
- Rate-class changes
- Metering or billing corrections
A facility that reviews only the total invoice misses the cause of the increase.
The Customer Protection Transmission Rider would change cost allocation
On September 14, 2026, PPL Electric filed a proposed Customer Protection Transmission Rider (CPTR) with the Pennsylvania PUC. If approved, the CPTR would replace the current Transmission Service Charge, make transmission costs more visible on customer bills, and create a mechanism to assign certain transmission network upgrade costs associated with serving large-load customers directly to those customers.
The proposal is a structural change in cost allocation, not simply another rate increase. It builds on the LP-6 framework from the rate settlement. A facility may not qualify as a large-load customer under LP-6, but it may still be affected by changes to transmission recovery, distribution rates or demand-related billing determinants.
Follow the Pennsylvania PUC’s electricity proceedings, and do not assume that a proposed rider is already being billed as described. The effective date, tariff language, rate class and utility territory control the actual invoice.
A Pennsylvania rate case will not fix your PJM capacity cost
This is the nuance many buyers miss. PJM establishes regional capacity-market prices through its auction process. Pennsylvania state proceedings allocate costs associated with distribution service, retail transmission recovery, interconnection and retail tariff design. Those proceedings do not reduce the PJM capacity clearing price.
A Pennsylvania facility may therefore experience:
- A higher PJM capacity charge embedded in its retail supply cost.
- A separate PPL or other utility distribution-rate adjustment.
- Transmission charges or riders that change based on the utility’s approved tariff.
- Demand-related charges based on the facility’s peak usage or assigned billing determinants.
- New infrastructure obligations if the facility expands or materially changes its load.
The same principle applies to competitive supply. A supplier can offer a lower energy adder while passing capacity and transmission costs through at cost. Another supplier can offer a bundled fixed price that hedges some or all of those components. The contract language determines the exposure.
The question is not who has the lowest cents-per-kilowatt-hour rate. It is which components of the bill are fixed, indexed, pass-through, regulated, or subject to future reconciliation.
What a Pennsylvania facility can actually do
A utility bill audit should precede a procurement decision, budget revision or demand-management program.
Discovery Energy’s utility bill audits are contingency-based, with no upfront audit fee. Under the agreed terms, Discovery Energy is paid when the client receives qualifying refunds, credits or realized savings.
The audit should establish a verified baseline across historical bills, utility tariffs, supply contracts, meters and operating data. Depending on the account and the agreed scope, the audit may examine rate classifications, tariffs, meter readings and multipliers, demand calculations, riders and available government utility exemptions. For Pennsylvania facilities, it should specifically test the following.
Rate classification verification
Confirm that each facility is assigned to the correct Pennsylvania utility rate class. Industrial sites can be billed under the wrong classification for years, particularly after expansions, ownership changes, load reductions or operational changes. A rate class can affect demand charges, customer charges, transmission allocation, standby provisions and eligibility for specific tariff schedules.
Capacity pass-through versus fixed contract coverage
Review the supply contract line by line. Determine whether the agreement:
- Passes PJM capacity through at the applicable zonal or customer-specific value
- Uses a fixed capacity adder
- Includes a full requirements product
- Hedges only energy while leaving capacity open
- Contains reconciliation language
- Applies different terms to different facilities
- Allows supplier markups on capacity or ancillary services
Transmission charge exposure
Identify every transmission-related line item and compare the billed rate to the applicable tariff and effective-date notice. Determine whether the charge is a utility tariff component, a supplier pass-through, a formula-based charge, a temporary rider, a reconciliation, or a charge tied to demand, energy or peak contribution. Do not treat “transmission” as one uniform cost across all Pennsylvania facilities.
Demand ratchets and peak-load contributions
Demand ratchets can cause a prior peak to influence charges for multiple future billing periods. Peak-load-contribution calculations can also affect capacity responsibility even when current monthly consumption falls. The audit should compare billed demand with interval usage, operating schedules, shutdowns, production changes and the tariff’s exact measurement rules.
Meter multipliers and billing determinants
Verify meter multipliers, transformer ratios, interval data, account numbers, service addresses and billing periods. A correct rate applied to an incorrect multiplier still produces an incorrect bill.
Transmission is one line on the bill. Verify it separately.
| Charge | Basis | Amount |
|---|---|---|
| Energy charge | 1,245,000 kWh × $0.0720/kWh | $89,640.00 |
| Capacity | 2,100 kW capacity obligation × $10.01/kW-month | $21,021.00 |
| Transmission service charge | 1,245,000 kWh × $0.0045/kWh | $5,602.50 |
| Distribution | 1,245,000 kWh × $0.0310/kWh | $38,595.00 |
| Demand charge | 2,500 kW × $12.50/kW | $31,250.00 |
| Total electric charges | $186,108.50 |
Illustrative. Quantities and rates are examples. Capacity uses $329.17/MW-day expressed per kW-month. If approved, PPL’s proposed CPTR would replace the Transmission Service Charge.
For the transmission line, verify:
- Tariff: the charge appears in the approved tariff schedule
- Effective date: the rate was in force for the billing period
- Rate class: it matches the account’s service class
- Billed determinant: the correct unit and quantity (kWh, kW or PLC)
- Rider status: the proposed CPTR is not in effect until approved
The billing determinants a utility audit verifies
| Determinant | What it measures |
|---|---|
| Billing demand | kW billed for the period |
| Coincident peak | kW at the system peak |
| Noncoincident peak | The facility’s own maximum kW |
| Power factor | Lagging or leading adjustment |
| Load factor | Average demand relative to peak demand, % |
| Service voltage | Primary, secondary or transmission service |
| Meter multiplier | Ratio applied to meter reads |
| Billing days | Days in the billing period |
Practical actions for Pennsylvania electricity buyers
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Audit first
Establish the verified cost baseline before changing suppliers, curtailing production or approving capital projects.
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Map every facility to its utility, rate class, PJM zone and contract structure
A Pennsylvania portfolio is not one cost center if locations have different utilities, meters, service voltages or supply agreements.
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Review contract timing around PJM auction cycles
Do not let a calendar-based renewal force a decision without reviewing forward capacity costs, energy markets and the contract’s pass-through language. Once the billing baseline is verified, the contracting decision falls into one of the three positions in the table below.
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Benchmark similar Pennsylvania facilities
Compare effective costs by rate class, service voltage, production output, load factor, peak demand and capacity treatment. A total cents-per-kilowatt-hour comparison alone is not enough.
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Separate recoverable errors from unavoidable market costs
PJM capacity charges may be unavoidable under the applicable structure. Incorrect rate classifications, meter multipliers, demand ratchets and misapplied riders are different. Those may be corrected or recovered.
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Centralize the data in TaraBase
TaraBase is Discovery Energy’s client portal, with dashboards for savings, energy usage, contracts and ESG metrics. One shared dataset closes the gap between what finance sees, what operations manages and what procurement is negotiating.
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Use the audit findings to shape procurement
Discovery Energy manages electricity and natural gas RFPs, using competitive bidding and market timing, after the account data has been verified.
| Position | When it applies |
|---|---|
| Buy | Lock a fixed price when budget certainty is worth more than further market flexibility, the offer’s risk-adjusted price is acceptable, and the contract states exactly which components, including capacity, are fixed. |
| Wait | Hold the current position when contract terms allow, the organization can tolerate price movement, and a defined market trigger or decision date is in place. |
| Hedge | Fix a portion of volume or selected cost components when a full fixed position costs too much but unprotected exposure is unacceptable. |
The objective is not to chase the lowest headline rate. It is to reduce avoidable cost, hedge the risks the business can tolerate, and document the financial logic behind each decision.
Frequently asked questions about Pennsylvania industrial electricity costs
Why did my Pennsylvania industrial electricity bill increase?
The increase may reflect PJM capacity pricing, higher wholesale energy costs, a PPL Electric or other utility distribution rate adjustment, transmission charges, demand changes, or a combination of these factors. A utility bill audit separates the causes instead of treating the increase as one unexplained percentage.
Will switching electricity suppliers eliminate the PJM capacity increase?
Usually not. Capacity charges are generally non-bypassable and may flow through regardless of supplier. A fixed-rate contract may hedge capacity, but the contract must clearly define which capacity costs are included.
Does the PPL Electric settlement reduce industrial electricity costs?
Not necessarily. The settlement increases PPL Electric’s annual distribution revenue by about $275 million and creates a new LP-6 large-load rate class. It does not reduce PJM’s regional capacity clearing price.
Does the LP-6 large-load rate class apply to my facility?
Only if the facility meets the thresholds: a peak demand of 50 MW or more at a single facility, or 75 MW or more in aggregate across facilities served at 69 kV or above within a 10-mile radius. Most established industrial sites fall below these levels, but multi-facility campuses and planned expansions should be checked against the aggregation rule.
What is the Customer Protection Transmission Rider?
PPL Electric filed the Customer Protection Transmission Rider (CPTR) with the Pennsylvania PUC on September 14, 2026. If approved, it would replace the current Transmission Service Charge, show transmission costs more clearly on bills, and allow certain transmission network upgrade costs tied to large-load customers to be assigned directly to those customers. It is a proposal, not a billed charge, until the PUC approves a final tariff.
Are Pennsylvania transmission charges the same for every facility?
No. Transmission costs can vary by utility, rate class, service voltage, load profile, contract structure and billing determinants. Facilities in the same state may have materially different delivered electricity costs.
What does a utility bill audit examine?
Depending on the account and the agreed scope, a utility bill audit may examine rate classifications, tariffs, meter readings and multipliers, demand calculations, riders and available government utility exemptions. It also tests capacity treatment, transmission charges and billing determinants against the applicable tariff and supply contract. Discovery Energy seeks the maximum recovery period available under the rules applicable to each account. That period varies by jurisdiction and utility.
Can a utility audit reduce Pennsylvania electricity costs even when market prices are rising?
Yes. A utility audit will not change a PJM auction clearing price, but it can identify billing errors, incorrect classifications, misapplied tariffs, missed government utility exemptions and avoidable demand exposure. Those findings can reduce the portion of the bill that is not actually required.
What should a Pennsylvania multi-site organization do first?
Start with a utility audit. Then centralize the verified billing and contract data, benchmark each facility, and develop an energy procurement strategy based on risk tolerance, contract exposure and PJM market timing.
Related: PJM electricity prices are rewriting industrial budgets. Published results are in the Discovery Energy case study library.
Sources
- Pennsylvania PUC, PUC Issues Decision in PPL Electric Rate Proceeding (June 4, 2026)
- Utility Dive, PPL Electric rate case settlement and large-load tariff (March 2026)
- PPL Corporation, Form 8-K on the rate case settlement (March 2026)
- PPL Electric, Customer Protection Transmission Rider announcement (September 14, 2026)
- Environment+Energy Leader, reporting Pennsylvania Independent Fiscal Office data on PJM wholesale prices (July 2026)
- PJM, 2028/2029 Base Residual Auction Report (July 14, 2026)
- NJBPU, An Investigation of PJM’s Capacity Market (August 2026), for historical auction prices
- Published by
- Discovery Energy
- Updated
- September 2026
- Regulatory status
- LP-6 approved June 4, 2026; CPTR proposed, not approved, as of September 2026
- Illustrations
- Bill examples are illustrative, not client data
Separate the channels before you buy
Talk with Discovery Energy about a documented review of your Pennsylvania utility portfolio.
