Photo Treasury's "Conscience Fund" courtesy of the U.S. Library of Congress

How a one-line formula for rate making, zero-sum economics, and a utility's efforts to adapt to the duck curve reveal the true impact of distribution costs.

Gridium’s rate engine technology is crucial for building operations because it allows engineers and managers to clearly translate an energy pattern into a cost to make better decisions. Most of the time, these analyses are short term–should I start early to avoid a peak today? How much did advancing start time actually save me? Should I enroll in price response? For these questions all you need is the current rates and a system like Gridium.

Others are concerned with longer term questions. If I install a battery storage system, are my savings likely to increase every year? Or decrease? Should I fund a HVAC retrofit or a install LED lights? If I sign that lease with WeWork, how much will my bill go up? Should my campus go to transmission level voltage?

To answer these questions, some reading of the tea leaves in rates is crucial. And while the electricity system in the US is massively diverse, many trends start in states like California, where renewable policies, deferred maintenance, and low gas prices are providing a glimpse of the future.

Consider PG&E and its recent rate case. California follows “cost of service rate making” where rates are calculated with a simple formula: ( cost of service / sales ) = rates. Below is the key table of the spending increases desired. This will inevitably get haircut, especially given outrage about wildfire culpability, but the spending requests are what to focus on. These spending requests are graciously called “revenue requirements”, part of the poetic language of monopoly utility regulation.

Peak demand charges may rise about $50/kW/mo

Table from PG&E’s Test Year 2020 General Rate Case application.

Notice that the total request here is for $1.4B and 81% of it is related to distribution. Electric distribution alone is requested to rise a massive 23.3%! This is not a new trend. Below is the table of recent rate cases and the proportion of increases by distribution versus generation.

Trend of proportion of distribution costs in general rate cases for PG&E

Data from initial applications from PG&E General Rate Cases 2011, 2014, 2017, and 2020.

How will these increases affect bills in the long term? By looking closely at the current tariffs, we can see where these expense increases are likely to fall among PG&E’s fifteen different rate elements.

Currently on the most popular commercial rate, distribution charges are largely tariffed in demand charges while generation charges are largely allocated by consumption charges. A massive 83% of demand charges are distribution related; six months of the year there is no generation component of demand at all. Among those charges, service voltage matters — transmission level customers pay only 36% of the distribution expenses of secondary voltage customers. Put more simply, current expenses are largely “poles and wires” related and a function of the maximum demand and infrastructure required to deliver that demand.

If accepted, these rate increases will continue that trend. It’s quite probable that, in the near term, summer demand rates will crest $50/kW/mo, the highest in the US. For perspective, when we started Gridium in 2011, they were just $24/kW/mo.

Of course these changes are exacerbated by changes in the denominator of the rate formula as well. As more load disappears into the arms of solar and energy efficiency, the same costs must be spread over a shrinking rate base. California’s economy marches on at 5% growth, but electricity sales are down almost 3% per year.

So what does this all mean for you? With apologies to technology trade rags, the table below sums up these changes for popular project types.

Tired Wired
Energy Star Score Demand Management Program
Solar Solar + Storage
Architectural Lighting Tenant LEDs
Going back to PG&E Meter consolidation
Demand Response Peak shaving
Central Plants Pony chillers
VPPAs Customer owned grid
Electrify everything Fuel cells and Cogen

 

A final note. As we discussed in 2012, efficient building operations is a zero-sum game. If you’re reading this and planing a strategy around it, delight yourself in the fact that your competitors pay for your savings.

References

  1. PG&E’s General Rate Case website
  2. Archive of GRC documents
About Tom Arnold

Tom Arnold is co-founder and CEO of Gridium. Prior to Gridium, Tom Arnold was the Vice President of Energy Efficiency at EnerNOC, and cofounder at TerraPass. Tom has an MBA from the Wharton School of Business at the University of Pennsylvania and a BA in Economics from Dartmouth College. When he isn't thinking about the future of buildings, he enjoys riding his bike and chasing after his two daughters.

You may also be interested in...

Engineering in the ‘illions

Nigel Marcussen–VP, Head of Building Engineering at WeWork–discusses how his team delivers productive, collaborative environments at the world’s fastest growing real estate tech company.

BuiltWorlds Selects Gridium for the Building Tech 50 List...

Thousands of buildings across the U.S., from Massachusetts to San Diego, run Gridium technology to diagnose anomalous energy leaks, boost building occupant service levels, and extend asset uptime with usable preventive maintenance alerts.

Aggregating & coordinating electricity assets at scale

Ram Rajagopal–Associate Professor at Stanford University and Principal Investigator of Powernet–discusses this ARPA-E program to develop an end-to-end, open-source system that will enable real-time coordination of utilities’ centralized assets with millions of distributed energy resources.