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By C. Rhodes, P.Eng., Ph.D.

This web page addresses practical aspects of implemenation of an Interruptible Electricity Service (IES).

The amount of power available for IES customers is the difference between the moment by moment total available non-fossil generation capacity and the moment by moment total Uncontrolled Electricity Service (UES) load. Thus the Independent Electricity System Operator (IESO) must be able to modulate the total IES load in accordance with moment by moment grid requirements. This modulation can be achieved by dividing the total IES load into approximately uniform block sizes and then using a computer to automatically turn individual blocks on and off in a cyclic fashion with a software controlled on/off timing ratio such that total IES load in a distribution zone is nearly constant at an IESO controlled set point while the available IES electricity is fairly distributed over all the IES load blocks with minimum load switching. Note that due to relatively frequent (10 minute cycle typical) load switching IES electricity is poorly suited to powering motors with large inertial loads. IES electricity is much more suitable for powering thermal energy storage, hybrid heating and electro-chemical processing.

As the UES load decreases below the total non-fossil generation capacity the IESO would gradually enable an increasing fraction of the IES load until 100% of the IES load is enabled. Similarly, as the UES load increases or the non-fossil generation capacity decreases the total IES load fraction enabled would gradually decrease.

System reset software limits the rate of IES load turn-on after an IES load dump.

This IES load control concept is not a new idea. This control methodology was originally developed by this author and others at ADMIC during the period 1977 - 1978 and was used for peak demand control in numerous electrically heated high rise apartment buildings in the Greater Toronto Area (GTA) up to 1999. Thereafter the equipment was taken out of service due to changes in the electricity rate structure that gave building owners more financial incentive for electrical energy conservation than for peak load control.

The present Uncontrolled Electricity Service (UES) rate regime in Ontario does not have sufficient dynamic price variation to financially enable behind-the-meter customer energy storage and use of surplus non-fossil electricity for fossil fuel displacement and for electro-chemical processing. A major source of this lack of dynamic price variation is the present allocation of the Global Adjustment to kWh instead of to peak kVA. Another source of this lack of dynamic range is the December 2015 OEB approval of a fixed delivery charge for small loads rather than a charge per peak kVA.

In order to achieve effective utilization of all of the available non-fossil electrical kWh the Global Adjustment and the delivery charge must both be allocated to kVA. In an efficient non-fossil electricity system the object is to minimize kVA, not kWh. Hence a new electricity rate is required to financially enable behind-the-meter customer energy storage and use of surplus non-fossil electricity for fossil fuel displacement and for electro-chemical processing.

In practice IES customers are also UES customers, so the metering and billing system must measure the customer load profile and must separate UES billing from IES billing.

The proposed methodology is to base UES billing primarily on peak kVA, to base IES charges on extra kWh consumed during IES availability periods and to bypass the UES peak demand recording mechanism at times when IES electricity is available.

In a non-fossil electricity system the cost of servicing a particular UES customer is approximately proportional to that customer's peak kVA during the billing period. In the proposed UES billing arrangement a customer pays a higher blended charge per kWh when his instantaneous rate of energy usage rises above his average rate of energy usage. The logic behind this UES billing arrangement is that peaking energy costs a lot more per kWh to generate and transmit than does base load energy.

The logic behind the IES billing arrangement is that there is only a finite amount of non-fossil IES energy available. Those who are willing to pay for it get it. The IES rate is entirely market driven and must compete against export alternatives available to the IESO and fossil fuel alternatives available to load customers.

The proposed new electricity rate and metering arrangement has the support of the Ontario Society of Professional Engineers (OSPE). A major advantage of this new rate structure is that the UES billing formula accurately reflects the actual costs of generation and transmission.

The administrative and legal costs related to obtaining Ontario Energy Board (OEB) approval for sale of electricity under an IES rate are onerous. There must be legislative changes with respect to allocation of the Global Adjustment. The regulatory obstacles are so high that today electricity distributors simply refuse to offer an Interruptible Electricity Service (IES), in spite of its inherent economic and environmental merits. Sometimes generators and load customers who deal in Interruptible Electricity avoid OEB regulation by directly exchanging energy without use of the public electricity grid.

From an IESO perspective implementation of an IES rate would raise the Ontario electricity system load factor, which would result in more electricity revenue without corresponding capital costs, which would financially benefit all electricity consumers. This benefit would be in addition to the benefits available from contemplated demand response measures.

One method of reducing the amount of energy storage required at wind and run-of-river generators is to sell part of their electricity output as interruptable power. Interruptable power is electricity that can displace another fuel such as oil, gasoline, diesel fuel, propane, ethanol, etc. For example, the electricity might be used for hybrid heating, for charging the batteries of a plug-in hybrid vehicle or for production of electrolytic hydrogen. Provided that the customer has a fully functional alternative fossil fueled energy system, then the electricity is interruptable. The IES is not as reliable as the FES but the IES provides electrical energy at a much lower cost per kWh.

In an electricity system with a UES but no IES the system power is regulated by constraining the total electricity generator output power to match the uncontrolled load power.

In a UES the required amounts of reserve generation and reserve transmission/distribution capacity are not apparent to the load customer. The actual amounts of these reserves vary depending on time of year, time of day, outside air temperature, wind conditions, equipment maintenance issues, etc. However, provision of redundant generation and transmission capacity for load following and for electricity supply reliability represents about half of the cost of non-fossil electricity delivered to a UES load customer.

In theory the UES rate should contain sufficient dynamic price variation that every non-fossil kWh that can be generated can be sold at a positive price. However, the practical experience in Ontario has been that most UES load customers prefer stable electricity rates rather than highly variable electricity rates. However, stable electricity rates per kWh lead to electricity generation surpluses at certain times of the day, during certain seasons of the year, at moderate outside air temperatures and during high wind conditions. A practical approach to UES rate minimization is to provide an Interruptible Electricity Service (IES) that can realize revenue by sale of surplus non-fossil electricity, when it is available, at a low marginal price. Since provision of the IES has little marginal cost to the electricity system, almost the entire IES revenue stream can be applied to UES rate reduction.

The line voltage is further regulated by IESO control of the IES portion of the total grid load power so that both provincially and locally the load matches the available non-fossil generation and transmission capacity. Since both UES and IES co-exist on the same distribution circuits, the IES power capacity is the difference between the currently available non-fossil generation capacity and the sum of the uncontrolled UES loads plus transmission/distribution losses.

The IES loads must be able to tolerate frequent and prolonged electricity service interruptions with no notice. Typically the IES capacity factor is small during extremely cold winter weather and extremely hot summer weather but rises to almost 100% in moderate temperature weather when neither heating nor air conditioning systems are operating in most of Ontario. The IES capacity factor also varies due to time of day and variability of wind, solar and run-of-river hydroelectric generation.

In order to have an IES Rate it is necessary to use a metering system that distinguishes IES electricity from UES electicity because IES electricity is provided at a different rate than UES electricity.

For practical reasons, both equipment and administrative, the IES should be implemented as an add-on rate to an existing FES account at the same address. Thus in reality there is no separate IES rate. Instead there is one combined rate that effectively provides the load customer the IES rate for the portion of his load that actually operates in synchronization with the IESO control signal. If a customer tampers with the IES control system then that customer is subject to the UES rate on his entire electricity consumption.

An issue with the IESO having direct cotrol of customer loads is that such control can potentially lead to higher demand peaks in a local distribution systems than would otherwise occur. Hence, when the IESO exercises such control it must also bypass the peak kVA meter(s) feeding the Local Distribution Company.

The required smarter electricity meter has standard smart meter interval kWh features plus interval kVA features plus an additional input channel which is used to flag metering intervals during which the customer's IES load is enabled by the IESO. There must be either a wireless or a hard wired communication link between the electricity meter and the Internet connected IES load controller. An fault in this communication link effectively disables the IES price discount.

An important element of the IES rate is that the IES metering system inherently prevents IES electricity being used to displace existing UES load. If a load runs when commanded off by the IESO the electricity associated with that load is billed at the UES rate.

The cost of IES electrical energy should be in the range $.01 / kWh to $.04 / kWh to compete with fossil fuels. This price range gives the purchaser of the interruptible electricity various viable application options. This price is usually more than the IESO is able to realize via the spot export market. At the time of writing the Hydro One rural residential UES blended end user rate is about $.25 / metered kWh. Most of the revenue from the IES rate could be returned to UES electricity rate payers via a reduction in the Global Adjustment.

In order for an Interruptible Electricity Service to make financial sense for the participating parties, the marginal cost of providing IES energy must be close to zero. Hence:
1. Fossil fueled electricity generation should not be operating when use of interruptible electricity is enabled by the IESO;
2. Provision of IES energy should not require any upgrade to the transmission/distribution system beyond normal upgrades required for providing reliable FES energy. Customers will require peak demand control systems to limit their total demand at times when there is no IESO control signal;
3. The IESO must have Internet based dispatch control of the interruptible load, which will be geographically distributed throughout Ontario. This dispatch control should progressively enable IES loads when there is no fossil fuel generation running at the margin. Assuming that the load customer already has an Internet connection and a local router the cost of equipment for providing the required IES load control is quite small;
4. The main issue may be obtaining Ontario Legislature and Ontario Energy Board approval for the new electricity rate. There must be an implementation agreement between the IESO and the local electricity distributor;
5. There are also smarter meter, software and data access issues related to collection and analysis of the required electricity meter data.
6. The smarter electricity meter records the cumulative total kWh, the cumulative total kVAh and the IESO control flag status every 15 minutes. The kVA, sliding average peak kVA and the kW are locally displayed and are recalculated after the end of each billing period.

At a customer's premises two binary control signals comes from the IESO via the Internet. There should be no IES consumption when fossil fueled generation is running at the margin. The IESO can divide the IES load into a number of smaller load blocks so that the IESO can modulate the IES load. This load division can be accomplished by using digital signal decoding at the Internet receivers.

The effect of the IESO control signal which enables IES loads is to raise the setpoint of the customers load control system and to set a flag in the "smarter" meter which bypasses the peak demand recording system. The other IESO signal resets the local display peak demand calculation. Both signals are recorded as to time received in the "smarter meter" memory.

The customer's peak demand control system must be engineered to provide desired load cycling, to prevent load short cycling and to limit load during recovery from an AC power failure and when the line voltage is below its specified minimum.

If communication via the Internet fails for more than one minute the IES load enable control output should automatically go to zero until after Internet communication is restored.

For at least one 8.6 hour interval per billing month, on a day and time when the total Ontario grid load is believed by the IESO to be maximum for that month, the IESO does not enable any IES loads. During the period when no IES load is enabled each customer's electricity meter will precisely measure and record the customer's uncontrolled electricity peak kW or peak kVA demand.

Potential IES customers include:
1. Parties with hybrid electric/ fossil fuel heating systems;
2. Parties with thermal energy storage systems;
3. Parties with battery type energy storage systems;
4. Parties with compressed gas type energy storage systems;
5. Bio-methanol producers;
6. Wood pellet producers;
7. Electrolytic hydrogen producers (methanol producerss):
8. Ammonia producers;
9. Nitrogen fertilizer producers;
10. Aluminum, lithium, sodium, chlorine amd fluorine producers.

The most easily accessible IES load is displacement of furnace oil and propane by electricity for rural space and domestic hot water heating. The largest and most important potential IES load is distributed electrolytic hydrogen generation for synthesis of methanol from water and farm/forest waste biomass. Many rural IES customers will have equipment for electrolysis of water, for temporary storage of the resulting hydrogen and for nearly immediate on-site consumption of the hydrogen for production of methanol.

Other potential IES customers are bulk metered high rise residential and commercial buildings. As long as the instantaneous building electrical demand is less than the building's monthly peak demand and as long as the IES electricity energy rate is below the marginal cost of natural gas such high rise buildings can absorb a lot of IES energy for displacement of natural gas. The economies of scale in high rise buildings are such that new storage tanks can often be added to enhance interim energy storage. Often in high rise residential there are three isolated heating zones (space heating, high zone domestic hot water and low zone domestic hot water). Subject to adequate main electrical switch gear and conductor capacity it is often physically simple to add an in-line electric immersion heater to each heating zone.

One of the economic realities in Ontario during the past decade has been a substantial increase in the prices of both electricity and furnace oil, while the price of natural gas has fallen. This issue has doubled the cost of space and domestic hot water heating in rural areas that are not serviced by natural gas while the cost of space and domestic hot water heating in urban areas with natural gas service has remained constant or has decreased. This issue has contributed to a severe urban/rural split in elected members in the Ontario provincial legislature. If the Liberals want to remain in government it is essential that they offer some form of cost relief to rural property owners who presently have no economically viable automatic heating fuel options other than the liquid fossil fuels. Offering these rural property owners interruptible electricity at $.02 / kWh for space and domestic hot water heating, when that energy is otherwise going to waste via non-fossil generation constraint, would provide cost relief for rural property owners, would increase electricity system revenue and would decrease liquid fossil fuel consumption, all at no cost to anyone except the rural property owner who would have to fund purchase and installation of an electric hot water heater in series his existing oil fired hot water heater, and a furnace plenum electric duct heater. With this equipment a typical home owner would likely experience a furnace oil cost saving of about $2500 per year, an increase in electricity cost of about $1000 per year resulting in a net energy cost saving of about $1500 per year and would likely realize a two year simple payback on his investment. It is likely that over 100,000 single family homes in Ontario would ultimately participate, leading to an increase in electricity revenue from this small market sector of over $100 million per year and a reduction in liquid fossil fuel purchases of as much as $250 million per year.

It is contemplated that the above described heating retrofits would be installed and maintained by the oil fired appliance field service technicians that are currently dispatched by rural oil delivery firms such as Shell and Ultramar - CST.

Several times as much additional revenue revenue should be available from parties involved in wood pellet and methanol production provided that the IES energy pricing makes business sense for them. Wood pellet producers require energy for feedstock drying. Distributed methanol producers require electrical energy for production of electrolytic hydrogen.

This web page last updated May 26, 2017.

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