At two o’clock on a summer weekday, an Oklahoma household can become a small participant in electricity economics. Run the dryer now, and power costs more. Wait until evening, and it costs less. That is the bargain behind OG&E’s SmartHours. It is also a useful introduction to its parent, OGE Energy Corp., which is confronting a much bigger version of the same problem: what happens when everyone wants more electricity?
- OG&E supplies about 913,000 customer accounts in Oklahoma and western Arkansas.
- Its Google agreements put dedicated connection costs and minimum payments on the new customer.
- SmartHours shows why a clever price needs people who can actually respond.
01 / The cloud needs a connection
In April 2026, OG&E announced agreements to supply three new Google data centers in Muskogee and Stillwater. The geography matters. A data center can serve users everywhere, but its electricity arrives through particular wires, attached to particular equipment, paid for by somebody nearby.
Under the announced terms, Google commits to covering all costs of connecting its sites to the grid, paying contracted costs regardless of actual energy use, and paying its share of required generation. Capacity arrangements from two solar facilities add another piece of supply. Google’s own announcement describes a long-term financial commitment to infrastructure built for its growth.
This is the part of the cloud worth reading twice. A forecast of future consumption is useful; a payment obligation is more useful when equipment must be built before consumption arrives. The agreement tries to connect those two things.
02 / A utility with a defined patch
OGE Energy is the listed holding company. OG&E is the operating utility: it generates electricity, moves it across transmission lines and distributes it to homes and businesses. Its roughly 30,000-square-mile territory includes Oklahoma City and Fort Smith. Customers range from households to shops, factories, oilfields and public authorities.
That makes comparisons with ordinary consumer companies awkward. An existing customer generally cannot shop among OG&E, Entergy Arkansas and Public Service Company of Oklahoma as though choosing a phone plan. Their service territories and regulatory arrangements matter. OG&E’s advantage is its installed network and responsibility to serve its territory; its constraint is oversight of what it charges.
The holding company was incorporated in 1995 and became the parent in 1997. The operating utility dates to 1902. That distinction prevents a familiar corporate biography mistake: giving today’s legal entity every birthday in the family.
03 / The thermostat that people didn’t want
Long before the Google deal, OG&E was learning that electricity demand is partly a behavioral problem. SmartHours launched in 2012. A 2013 smart-grid report put the wider modernization project at $357 million, including $130 million from the U.S. Department of Energy. Meters and communications made time-based pricing practical.
Then came the awkward measurement. In 2014, the utility expected SmartHours to deliver roughly 160-170 megawatts of demand reduction against a 210-megawatt goal. Enrollment was doing well. The expected reduction was not. Weather complicated comparisons, and about 30% of participants were not using the utility’s programmable thermostat.
“Looking back, we thought everyone would want a thermostat”Mike Farrell, OG&E customer-programs director, 2014
Some customers lacked central heating and air conditioning. Some preferred the thermostat they already owned. Customers without the enabling technology delivered about a third of the demand reduction, the utility said. OG&E planned to keep promoting the program in 2015 instead of merely maintaining enrollment.
The lesson travels well beyond utilities: measure the behavior your product needs, rather than treating registration as the result. The first assumption to crack was that customers would all welcome the same device.
04 / Five hours that change the arithmetic
Today, SmartHours offers Daily and Fixed plans, plus an Oklahoma-only Overnight option. The ordinary summer weekday peak runs from 2 p.m. to 7 p.m., June through September. Daily customers can also face separately notified critical events, including outside that usual window. Rates and eligibility depend on the plan and state.
Shift flexible chores. Keep comfort in the calculation.
A household can compare plans using actual usage, move laundry or vehicle charging, and consider pre-cooling before the afternoon peak. First-time participants get a Best Bill Guarantee: after one year, charges are compared with the previous plan using actual consumption, with a credit if SmartHours cost more.
That makes experimentation easier. It does not make every household equally flexible. Someone who needs cooling throughout the afternoon has fewer choices than someone who can comfortably shift it. A price signal works best when the person receiving it has something they can change.
05 / Follow the money into the wires
OGE’s 2026-2030 capital estimate totals $7.285 billion. More than half goes to distribution in Oklahoma and Arkansas. Transmission, generation reliability, capacity projects and technology take the rest. These are estimates for maintaining and expanding a physical system, not a completed spending tally.
The model is familiar utility finance: operating cash, borrowing and equity fund assets; regulated rates determine recovery and returns. OGE reported $3.2601 billion in 2025 revenue and $470.7 million in net income. Building more creates an opportunity to earn, alongside depreciation, financing costs and the task of securing regulatory approval.
The focus has narrowed. By September 2022, OGE had sold all its Energy Transfer units, collecting $1.0672 billion in pretax net proceeds and leaving primarily an electricity business. The company said proceeds would help repay debt and support general corporate purposes.
06 / Growth needs terms and conditions
The Google arrangement is a test of cost allocation, not proof of a particular household saving. At September’s hearing, an administrative law judge recommended settlement approval. Reporting distinguished that recommendation from a final commission order and described future reviews of effects on other customers.
Separately, OG&E filed a proposed tariff for new loads of at least 75 megawatts. It includes upfront funding, minimum payments and customer protection provisions. The two arrangements should not be confused: their conditions differ.
The practical idea is copyable: agree who bears the risk before building for promised demand. Its usefulness depends on enforceable commitments, credible customers and regulators willing to examine shared costs. In electricity, a welcome new neighbor still needs a carefully addressed bill.