Guest Blog post by Gopal Shanker, Récolte Energy President

Last December PG&E reached its 5% cap for net energy metering (“NEM 1.0″) — the program that solar customer-generators have been using to offset their annual electricity bills. For the next few years, net metered projects will be interconnected under the NEM successor program (“NEM 2.0”).

NEM 1.0 and 2.0 are similar in that solar photovoltaic (PV) customers will be compensated at full retail rates for their kWh exports for 20 years from the date of interconnection. The programs are different in that 2.0 customers have to pay non-bypassable charges on every kWh imported from PG&E and for interconnection costs, both of which 1.0 customers were exempt from paying. On the plus side, 2.0 projects don’t have the system size limitations that constrained 1.0 projects.

Consumers can model these changes when evaluating the feasibility of a PV project. Estimates can be made both for the amount of electricity imported from PG&E to calculate non-bypassable charges as well as for interconnection costs. Adjunct monitoring systems can be used to verify if PV systems are producing as projected and if electricity consumption matches historical patterns. The causes of any variances between projected and actual production, usage, and net usage can be determined.

What we can no longer do is calculate electricity bill savings by assuming fixed PG&E rates and annual inflation percentages, without also considering the timing of electricity production and consumption. The static assumptions in our current models have worked thus far, even though PG&E routinely adjusts its rates many times a year, because the productive hours and seasons of PV have coincided with PG&E’s peak periods and the gaps between peak and off-peak rates have remained wide.

See, for example and a bit of color, how PG&E’s solar friendly A-6 rates have fluctuated by time of day and season between 2001 and 2016.

line graph illustration, shows PG&E solar rates, by time of day and season between years 2001 and 2016

But disruptive rate changes are looming. From April, new customers with demand between 75 kW and 500 kW will be ineligible for A-6. PG&E’s proposed rates and time-of-use (TOU) periods are decidedly unfriendly to solar.

If or when PG&E’s proposals get implemented, affected customers won’t receive the level of compensation that current customers do, and peak rates will be in effect even after PV systems have shut down for the night. The value of our PV systems will decline, unless we export less and consume more of what we produce, by dynamically optimizing the timing of production, consumption, and storage.

PG&E has 250,000+ solar customers, more than any other utility. Consumers adopted solar so enthusiastically because we had a significant problem – high electricity bills – and a viable solution – affordable solar. We still have a significant problem. See PG&E’s rate increases for 2017 vis-à-vis 2016 in the table below.

table illustration, shows PG&E rate increase in the year 2017

Consumers still have, I believe, a viable solution, even in the face of PG&E’s looming proposals, not just because PV system costs continue to decline and the 30% investment tax credit, accelerated depreciation, and NEM are still available, but also because of the possibilities offered by batteries, electric car chargers, and/or other electricity demand and supply management options.

All MCE customers are also subject to PG&E’s rules regarding NEM 2.0.

The opinions expressed by RE-Source Guest Bloggers are theirs alone, and do not necessarily reflect the opinions of MCE, its employees, or contractors. MCE reviews all posts but is not responsible for the accuracy of  any of the information supplied.

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