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In this article, we combine the expertise of three industry professionals to acquaint the reader with an understanding of Power Markets, Utility Rate Programs, Tariff-based Energy costs and their relationship to analytics, controls and energy management strategies.

Leighton Wolffe, of Northbridge Energy Partners, will start the discussion by providing an overview of the rapidly evolving with national, regional and local power markets and how legislative, regulatory and energy policy changes, as well as emerging renewable energy resources such as solar, wind, storage, along with weather and consumer demand,  create increasingly complex scenarios of supply, pricing, and risk. These factors drive the costs of electricity in complex ways, impacting the opportunities for analytics and control technologies. Analytics need to go beyond fault detection and HVAC operations to be relevant in today’s sophisticated energy economy to provide building owners with a clear understanding of how their buildings operate in the context of market dynamics. This enables them to make informed decisions on how to buy and use energy. All of this creates business opportunities for the community.

Stephanie Fetchen, of RateAcuity, will present examples of rate differences and the substantial impact they can have on operating costs under the same levels of consumption and demand. As an example in some rate programs, operators can achieve lower overall costs by using more kWh to help avoid kW demand peaks. The key to these types of analysis is to combine tariff rate data with consumption and demand data. The inclusion of detailed electric rate information in analytics enables us to translate kWh and kW into dollars. Providing saving and/or cost information in dollars is much more meaningful to our end users than seeing it in kWh or kW. A tariff engine is essential to this calculation, but you need rate data to take advantage of it. But rates can be complex, hard to access and presented in many different formats. Complexity in electric rates is caused by the availability of multiple rate options, as well as varying levels of details within each rate schedule.

John Petze, of SkyFoundry, will discuss the final step in generating value from rate and consumption data – modelling rates and utilizing a Tariff Engine to calculate true energy costs and the presentation that information to operators to enable them to make better decisions on rate selection and energy management strategies.

US Energy and Utility markets are rapidly evolving in accordance with regulatory and legislative changes at the Federal, State, and Regional levels. What had been a historically staid and slow-moving industry has now become supercharged with the advent of renewable technologies and distributed energy resources.

Solar, Wind, Storage installations are becoming dominant resources to supplement traditional generating power plants. Beyond the technology, the introduction of these new forms of generation is responsible for changes resulting in the decentralization of the monolithic utility business model that has been in place for the past 100 years. Roll over Edison.

Given the pace of national and local activity, energy market models in place today will not stay the same as the regulated and competitive markets adjust to the increasing integration of grid-scale renewables. This new mix of firm and intermittent energy resources directly impact the way energy suppliers price power purchasing agreements and how consumers pay for electricity originating from multiple sources.

Utilities and firm generating resources (nuclear, coal, gas, hydro) have different costs to operate. Solar and Wind are intermittent resources and have minimal operating costs once installed – certainly when compared to conventional power plants. Additional costs that drive retail energy pricing include moving electrons from the source to the consumer with the transmission, and distribution charges being part of every electrical bill.

The output from renewables can cost less to produce than generating plants. With solar and wind peaking at different times in the course of the day, oversupply can cause power prices to plunge and additionally, power prices occasionally spike to untenable highs when demand peaks in supply-constrained localized areas – further compounding the inequities between supply, demand and wholesale energy prices.

Developers and utilities build new generating resources, based on assurances they can sell the output. These origination deals have ROI’s that are predicated on price commitments from buyers that are usually in place before the steel goes in the ground. Suppliers with under/oversupply can exercise options to buy and sell output on the spot market – with attendant risks and uncertainty due to market and pricing volatility.

Regardless, new wind and solar farms are being constructed in every region, and as cost curves continue to decrease, the localized cost for energy for solar has decreased by over 86%, and the wind has decreased by 67% in just 8 years. (Lazard Research)

Case in point – the adoption of solar in California had risen from 0.5% of total generation in 2010 to 10% in 2017. In fact, there is such a surplus at peak sunshine periods, at times California has to shunt power and pay other states (Arizona) to take the excess so as not to overload the grid.

In Texas, ERCOT’s installed wind capacity has nearly doubled since 2010, leaping from 9,400 megawatts seven years ago to over 23,000 MW today. In 2015, wind surpassed nuclear to become the grid operator’s third-largest power source. At the end of 2017, Texas had more than 22,000 megawatts of wind power, more than triple Oklahoma’s 7,500 megawatts of wind generating capacity, the second highest in the nation.

The famous California “Duck Curve” is one such example of how the introduction of renewables is radically changing the load curves of entire regions. Moreover, this is taking place faster than originally forecasted, further compounding the issues for suppliers to match output with demand.  

The rapid upswing of alternative energy is wonderful news to meet renewable goals. Somehow though, the grid has to absorb these new sources of energy while maintaining the delicate balance of matching supply with demand – in real time. BUT, the sun is not always shining, and the wind may not be blowing when consumer demand needs it. So, the grid operators have to rely on the traditional mix of baseload generators and peaking plants to supply power to meet all the demand and still have some in reserve. As well, grid-level storage is increasing as a firm resource.  Demand Response has been part of the solution, but it can only go so far shedding load before impacting operations and tenant comfort.

These are complex issues that occur every day and every hour across the United States electrical grid, and the solutions are not easy. So, what happens when renewable energy is not available? Who is responsible for all this and managing the grid? How are electricity prices determined?

Energy Market Structures
To understand the breadth of these issues, and to appreciate the current and emerging methods used to address solutions - some background on those managing the electrical grid:

There are a number of agencies involved in the oversight and management of energy markets - these include: The Federal Energy Regulatory Commission (FERC) is the United States federal agency that regulates the transmission and wholesale sale of electricity and natural gas in interstate commerce. Each state has its own Public Utilities Commission appointed by governors to terms of varying length, but some are elected.

The US has regions that are either Regulated (vertically integrated utilities) or De-regulated (competitive energy markets). Many of the regions interoperate and share the power to ensure reliable power to the grid and to consumers.

Traditionally regulated electricity markets exist primarily in the Southeast, Southwest and Northwest where utilities are responsible for system operations and management, and for providing power to retail consumers. Utilities in these markets are frequently vertically integrated – they own the generation, transmission and distribution systems used to serve electricity consumers.

In the De-regulated energy markets, the independent systems operators (ISOs & RTU’s) operate the transmission system independently of the utilities and foster competition for electricity generation among wholesale market participants.

Each of the ISOs and RTOs has energy and ancillary services markets in which buyers and sellers could bid for or offer generation. The ISOs and RTOs use real-time bid-based markets to determine economic dispatch. While major sections of the country operate under more traditional markets, many of the nation’s electricity load is served in RTO regions.

US Electrical Regions:

In every market, region and zone, the grid operators have to find a way to deliver steady power in real time. However, increased demand can create hot spots, and additional supply resources are typically called upon with peaking plants – often being the costliest forms of energy. This drives the wholesale prices of electricity up – that has to be paid for by the supplier. In order for the suppliers to cover their costs and as an insurance hedge, power purchasing agreements include rates, tariffs, and demand charges that (hopefully) make up the difference more often than not. The customer sees these for every month on their bill.

Consumers are directly exposed to these complex energy market dynamics. In the wholesale and retail markets, there are structures in place to manage and regulate the relationships and financial transactions between the market participants and the consumers. While complicated, they follow similar practices as the stock market and financial trading operations between sellers and buyers – in this case, the commodity of electricity. The retailer energy provider serves as the broker or intermediary.

LMP Pricing Variations

New Business Models – New Pricing Models

As the energy markets evolve, new forms of managing risk will emerge – principally around pricing. In order for the new markets to work effectively across the entire energy chain, consumers need to be an active participant. This means having an awareness of market conditions to make business and operations decisions on when, and how to use energy. In order to do this, consumers need to monitor their own energy usage and operational patterns to make informed decisions to effect beneficial changes.

Collecting and analyzing meter data is the first step. That provides intelligence on usage at any given point in time. Historical and real-time meter data can be collected via a number of methods and applied to provide simple trend analysis, KPI’s, and with more sophisticated software programs, for comparative and qualitative analysis of large datasets where they can be especially effective to manage portfolios across multiple power markets. The challenge, however, is each market has its own tariffs, pricing structures, and issues around supply and demand. There is a wealth of intelligence contained in meter data alone, but it is only valuable if used and applied.

The second step is to assemble data from the building automation system (BAS) and building equipment to reveal what is happening when – that drive energy usage. Until recently, BAS’s were not designed to offer much more than temperature control and time clock functionalities and were not intended to share information with other systems freely, but now higher order analytic software programs are available from third parties to extract BAS data, integrate with energy data and apply sophisticated analytic tools.

The third step is to create operating strategies to manage demand in the context of market conditions – and within the terms and conditions of the power purchasing agreement. This is accomplished by enhancing the customer’s ability to manage their usage that comports with business, operational, and financial rules that are applied under different pricing thresholds.

When these three levels of data management are in place, the customer is ready to engage the new energy markets with confidence and with newfound ability to leverage and negotiate improved power purchasing agreements – because now the customer is able to self-manage risk, and the retail energy supplier has less risk to price.

The customers that have control over their equipment to adjust their demand are going to be the real beneficiaries of the new markets. Those without the ability to monitor and control their buildings will continue to operate blindly and will have to pay the price – whatever it may be.

Dynamic pricing models are coming – depending on which regions your buildings reside, it is either already happening – or coming your way.  For example, California's investor-owned utilities have already rolled out default time-of-use rates to millions of customers this year, and utilities around the country are watching closely. Electric rates that more accurately reflect market conditions will help utilities integrate more distributed resources, but customers have been on fixed-rate plans for decades – so this represents changes and new ways for customers to buy and use energy – and this all needs to be supported by solid data to make informed decisions.

  Unlocking Real Energy Costs with Rate Data
Stephanie Fetchen

Integrating electric rates with analytics has become an important topic in our industry in recent months. The main reason for this is simple; integration helps our customers, the end user building owners and facility managers, better understand electric spending within their buildings.  There are a few key benefits of integration.  One of the most useful of the benefits of including electric rates in analytics is the ability to translate reports that are traditionally shown in kilowatt hours or kilowatts into dollars. 

Reporting 

Historically, reports showing energy usage or potential energy savings information are presented as kWh or kW.  Let’s say a building owner knows that 17,000 kWh could be saved annually by the installation of a high-efficiency air conditioner.  That’s a good start to knowing the potential benefits of the equipment upgrade.  But what if we could provide the building owner information about the actual cost savings of that 17,000 kWh?  It would be much more useful information for evaluating the return on the equipment investment. 
In order to determine the actual cost savings, we need to know the utility and schedule the building is served under.  For purposes of this example, we will use a building that is in the Colorado Xcel Energy area. As shown in Table 1, the actual annual savings for this high-efficiency air conditioner varies significantly based on the rate schedule the building is served under. Presenting the building owner the savings in dollars based on the actual tariff schedule being used by the building can help significantly with making a well-informed decision. 

Billing

Integrating electric rates with SkySpark can also help end users answer billing questions.  For the next example, we will look at a facility that used 750,000 kWh of energy during the on-peak period, 672,000 kWh of energy during the off-peak period, and had a maximum demand of 2500 kW for the month of August.  Again, the facility is in the Colorado Xcel Energy service area.  Table 2 demonstrates the charges the facility would pay based on the different rate schedule options available.  As shown in the table, the same consumption and capacity can result in greatly varying charges based on the schedule the facility is served under.  This information can help the facility answer questions such as would it be better served under a different schedule, and how shifting usage patterns might benefit building expenses.  Some suggestions to reduce electric spending could include shifting usage from on-peak to off-peak periods of the day which will reduce costs even though there is still the same amount of consumption, and smoothing demand to be more equally distributed throughout the day, which will decrease the peak load which can save money. 

Rate Changes Over Time

Another benefit of integrating electric rates with SkySpark is capturing rates as they change over time. Electric rates change frequently; rate schedules for some utilities have changed a few times a month.  Others change less often.  SkySpark can save historical rates, so as rates change over time SkySpark can be useful in analyzing the changes and can use patterns to help predict rate changes in the future.  This can be very useful to the end user when trying to budget upcoming electric expenses.

The complexity of rate schedules and how they are implemented is an ever-increasing challenge. We see changes in rate design from traditionally simple rate structures to more complicated designs. Many rate plans are now including demand charges when in the past they just included charges for consumption.  Demand response programs are also becoming more prevalent, and more complex. As an example, Southern California Edison’s Critical Peak Pricing demand response program imposes an extremely high surcharge from 2 to 6 PM twelve times a year on the highest system use days. In SCE’s TOU-GS-3 schedule, the additional charge per kWh is $1.37453 for all consumption during the Critical Peak event.  The end user account needs to be aware of these charges to avoid use during these events as much as possible. 

Because of the high frequency of rate changes, and the complexity of the rate schedules needed, it can be a good option for most to consider using a rating service.  Rate providers, such as RateAcuity, can be used to download rates directly into the SkySpark platform saving the end user or integrator from the tasks of finding the correct electric rates, building them into SkySpark correctly, and keeping them up to date.
 

Being able to calculate actual energy costs for electricity and other resources such as water, fuel oil, and natural gas is a critical element in applying data analytics to drive financial benefits for building owners and operators. We have just seen the substantial impact utility rates can have on energy costs as well as the challenges involved assigning actual costs to energy use and analytic findings due to rate complexity.

In order to understand the impact rates will have on a facility under actual operating conditions, we need to be able to able to calculate the cost of usage and correlate those costs to equipment operation and performance issues and faults identified by analytic rules.

In order to achieve that goal, we need software that can “model” the various charges that make up a rate and perform the complex calculations necessary to turn energy use into dollar equivalents based on those charges. By doing so, a Tariff Engine enables precise calculation of actual energy costs.

Rate Modelling. When we refer to “modelling” a rate we mean the ability to capture the various charges that make up an electric rate. Costs for energy go far beyond simple consumption (kWh) and demand (kW). Utility rates often have a wide range of charges including:

The Tariff Engine. Once the “charges” that make up a tariff rate are defined, the next step is to assign the tariff to the meters that measure energy use. The Tariff Engine then calculates energy costs based on the charges and actual energy consumption data. Analytics rules and algorithms can then use those detailed cost calculations to calculate the cost associated with issues it detects in the operation of equipment systems. The result is a precise calculation of costs associated with the use, and misuse, of energy resources.

They are addressing Charges that Change Over Time. As discussed earlier, tariff charges often change over time. This adds additional complexity to cost calculation. The tariff engine needs to be able to use a historical record of charges over time to accommodate this situation.

Presenting tariff-based Energy Costs. The final step is to present tariff-based energy costs to operators in a meaningful way. The view below shows the presentation of energy consumption and demand correlated to tariff-based costs over the course of a month for 3 separate facilities. The lines show consumption and demand and the bars show tariff-based costs.

If we drill into the next level of detail, we see energy use correlated with equipment operation (shown first in a weekly view) and finally equipment operation correlated with energy consumption shown in a detailed daily view. This provides a direct correlation between the operation of equipment systems and the resulting impact in energy use, demand and cost.

One of the key benefits this level of detail provides is the clarity and visibility it brings to understanding the impact of operational issues. It gives facility operators financial and reporting tools on par with the sophisticated tools used in other departments enabling them to more effectively make their case to justify maintenance priorities and capital expenditures to improve facility performance and reduce operational costs. Data, when presented correctly truly, is a powerful tool. Being able to present cost data enables facility managers to:

• Develop more comprehensive proposals and justifications for upgrades, repairs and improvements
• Plan operating and capital budgets
• Communicate the financial implications of operational issues to others in corporate management

Today, the ability to calculate the true costs associated with energy use by utilizing detailed tariff rates provides owners with actionable insight to drive more efficient, intelligent data-driven facilities management.

About the Authors:

Leighton J. Wolffe, the co-founder of NorthBridge Energy Partners, has more than 25 years of experience in the facilities, process and energy industries. His interest in technologies led to leadership positions with energy companies, manufacturers and systems integration firms designing and developing innovative hardware and software applications.

Leighton’s experience across multiple industries and customer segments enables him to play an integral role in the development and deployment of successful strategic business initiatives and enterprise level projects. Leighton provides expertise and domain knowledge to help clients navigate their way through the highly dynamic intersection of energy markets, emerging technologies and industry players.

He is professionally active on a national level with manufacturers, software developers, systems integrators, facility professionals, government agencies and serves in key roles as owner’s advisor, technical consultant and facilitator providing knowledge of technology and industry trends. In a previous position as VP Strategy for Constellation Energy, Leighton founded the NewEnergy Alliance and formed commercial relationships with over 40 energy technology companies to develop applications and deliver solutions around Constellation’s VirtuWatt Platform, which connected buildings directly to energy markets and Constellation’s trading desk. Leighton is co-developer for this ground-breaking platform.
 
Contact information:
leighton@northbridgeep.com

Stephanie Fetchen is a Co-President at KFR Services, Inc., the parent company of RateAcuity.  RateAcuity is a comprehensive database of electric utility rates throughout the US.  Stephanie has been at KFR Services, Inc. for over 25 years, beginning as a software developer and working through various roles in the MIS and Operations departments.  Currently, she directs all oversight of software development activities, including program specification and design, scheduling, coding and testing.  She also developed and champions the data quality program that has enabled accuracy exceeding 99.98% for product delivered to customers.
 
Contact Information:
Co-President, KFR Services, Inc.
sfetchen@kfrservices.com
www.rateacuity.com

John Petze is a partner and Co-Founder at SkyFoundry, the developers of SkySpark™, an analytics platform for smart device and equipment data. John has over 30 years of experience in automation, energy management and M2M/IoT, having served in senior level positions for manufacturers of hardware and software products including: President & CEO of Tridium, VP Product Development for Andover Controls, and Global Director of Sales for Cisco Systems Smart and Connected Buildings group and is a member of the Association of Energy Engineers. He is the Executive Director of Project-Haystack.org, an open source, 501C trade association focusing on standards and technology to make device data self-describing to enable software applications to automatically consume, interpret, analyze and present data from devices and equipment systems thereby unlocking the value of the data.
 
Contact Information:
John D. Petze
Principal, Co-Founder, SkyFoundry
john@skyfoundry.com