City of Warroad
Resolution 2008-07 of the Utility Commission
Adopting Retail Power Rates
Be It Resolved that the Utility Commission of the City of Warroad does hereby authorize and approve the following retail power rates for the customers of Warroad from the period March 20, 2008 to March 20, 2009
RETAIL POWER RATE
1.       Firm power and / or Interruptible Services
	A. Residential Customers
		1. Customer Charge	$7.50			/mo
		2. Energy Charge	$0.0762	76.2	mills	/kwh
		3. Electric Heat Energy Controlled (off-peak)	$0.0441	44	mills	/kwh
		4. Electric Heat (Uncontrolled)	$0.0900	90	mills	/kwh
	B. Small & Regular Commercial Customers
		1. Customer Charge	$10.00			/mo
		2. Energy Charge	$0.0749	74.9	mills	/kwh
		3. Electric Heat Energy Controlled (off-peak)	$0.0441	44	mills	/kwh
		4. Electric Heat (Uncontrolled)	$0.0900	90	mills	/kwh
	C. Large Commercial Customers
		1. Customer Charge	$23.00			/mo
		2. Energy Charge	$0.0630	63.0	mills	/kwh
		3. Electric Heat Energy Controlled (off-peak)	$0.0441	44	mills	/kwh
		4. Electric Heat (Uncontrolled)	$0.0900	90	mills	/kwh
		5. Capacity Charge	$0.8000		kva	/mo
	E. Industrial/Commercial Generators
		1. Customer Charge	$25.00			/mo
		2. Energy Charge	$0.03475	34.75	mills	/kwh
		3. Summer Demand	$6.000		kw	/mo
		4. Winter Demand	$6.000		kw	/mo
		5. Capacity Charge	$0.8000		kva	/mo
		6. Energy Charge During Peak Hours(IPP)	$0.080	80	mills	/kwh
	F. Internal City
		1. Customer Charge	$10.00			/mo
		2. Energy Charge	$0.0773	77	mills	/kwh
		3. Electric Heat Energy Controlled (off-peak)	$0.0441	44	mills	/kwh
		4. Electric Heat (Uncontrolled)	$0.0900	90	mills	/kwh
	G. Street Lights
		1. Customer Charge	$50.00			/mo
		2. Energy Charge	$0.0719	71.9	mills	/kwh
	H.  Reconnection Fee		$30.00
2.       Determination of Winter billing demand
	The annual winter coincidental metered peak demand shall be comprised of the average of three consecutive hour coincidental demands occurring at the time of the cities highest system peak load taken on up to three separate days, if possible, and occurring between November 20 and the following March 20.
3.       Determination of Summer billing demand
	The annual summer coincidental metered peak demand shall be comprised of the average of all  coincidental demands occurring at the time of the cities highest system peak load  and occurring between May 20 and the following September 20.
4.       Power Factor Adjustment:
	a.      Customers shall at all times take and use power in such a manner that the power factor shall be as near 100 percent as practical. At the option of the City when the power factor at any delivery point during any hour is less than 95 percent leading or lagging, the metered demands for said delivery point used for billing purposes shall be increased by the ratio:
		0.95
		The lowest hourly power factor
		(Lead or lag) recorded in the
		current billing month.
	b.     This option will only be excersized when that same clause in the cities rate schedule with our wholesale supplier is excersized.
5. Inadvertent Demand Insurance:
	The City's wholesale provider offers the City inadvertant demand insurance on various loads, therefore, the City is passing this option on to our customers that meeting criteria. Criteria and cost follow our wholesale supplier (NMPA) criteria & cost.
6. Increment Pricing Plan:
	This program is available to customers with generators that may choose to pay a supplemental payment in lieu of load control during certain load control events.
	A. Qualifications
		1.  Each customer load must be metered by a time synchronized, continuous operation, one-hour interval demand recorder.
		2.  Individual customer loads that participate must be place into the double order specific to the Increment Pricing Plan as documented in the Ripple Operating Guide.
	B.  Control Criteria
		1.  The customer double orders specific to the Increment Pricing Plan will not be controlled unless:
		a.  Load control is required because Minnkota is reaching capacity limit.
		b.  Minnkota is buying energy and the wholesale market price for that purchased energy would lead to an average purchased energy price greater than the pre-determined average for that season.
		c.  Load control is required for Schedule L cerifications
	C.  Data Reporting
		1.  The City Utility will report the hourly coincidental metered data for each qualifying customer for all load control hours normally scheduled for that load to Minnkota.
	D.  Rate Schedule
		1.  The customer must pay the city a supplemental charge per Retail Power Rate(section 1E-6) for loads for kWh recorded on the hourly coincidental meter(s) during all load control events normally scheduled for the qualifying customer.  The recorded kWh will start at the beginning of the clock quarter hour after activation begins and ending at the beginning of the clock quarter hour before the activation ends.
	E.  Metered Demand Credit
		1.  The city will credit each customer's hourly summer coincidental billing demand based on the hourly metered demand supplied in Paragraph C above except for the hours when control is required for capacity limitation, to avoid higher cost energy purchases or Scedule L certification as defined in Paragraph B above.
7. Service Conditions:
	The city reserves the right to require customers to correct any condition on its system, which causes a hazard to the city facilities and personnel, or to the quality of service provided by the city or its supplier to others. All motors, appliances or equipment connected to the customers system must be so designed, installed and operated as not to cause undo disturbance neither to others nor to handicap the city and supplier in maintaining system conditions.