exv10w17



 





EXHIBIT-10.17



Interstate Pcwer and Light Co.

An Alliant Energy Company




8000 Chavenelle Road

Dubuque, IA 52002-9670




Office: 1.800.822.4348

www.alliantenergy.com




June 13, 2006




Western
Dubuque Bio Diesel, LLC

Attn: Ed Recker, Project Manager

Cascade, IA 52033




RE: Provision of service confirmation




Dear Mr. Recker:



This letter is to confirm Alliant Energy-Interstate Power and Light Co. will be providing
electricity to the planned Western Dubuque bio diesel plant in Farley, Iowa. Electricity is
provided in accordance with regulatory rate and service standard tariffs filed with the Iowa
Commerce Commission.



Should you have other questions concerning this or another matter, please contact me.




Sincerely,




	 	 	 	 	 
	 	 	 
	/s/ Randy Dunkel	 	 
	 	 	 
	Randy Dunkel

Operations Manager


RD/vd 	 	 













 






	 	 	 	 	 



	 
	Interstate Power and Light Company

	ELECTRIC TARIFF

	Filed with the I.U.B.







	 	 	 
	 

	 	Second Revised Sheet No. 26
	 
	 	 
	ORIGINAL TARIFF NO. 1

	 	Canceling First Revised Sheet No. 26





 





Electric Large General Service Usage




Rate Codes: 300, 307-8, 320, 327-8, 440, 447-8, 807-8
 





Applicable:



Large General Service Usage customers for all electric uses in one establishment adjacent
to an electric distribution circuit of adequate capacity. No resale of service is permitted.
Customers on this rate must have energy usage of 20,000 kWh            or more in each billing
month. Customers falling below required metered usage levels will be placed on the General
Service Usage rate for a minimum of one year. Service hereunder is also subject to
company’s Rules and Regulations.




Character of Service;



60 Hertz alternating current single or three-phase, at secondary voltage through one meter and
one point of delivery or by customer’s option a higher available voltage. The Company shall
provide only one transformation. Alternative voltages and/or service is available in accordance
with the Rules and Regulations and Excess Facilities Charge.




Billing Provisions




Monthly Demand Charge:




	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Zone	 	IES
— North Zone		 	IES
— South Zone		IES
— South Zone		IPC Zone	 	 	 	 
	Rate Codes	 	807-8	 	300, 307-8	 	320, 327-8	 	440, 447-8	 	 	 	 
	Season	 	Winter	 	Summer	 	Winter	 	Summer	 	Winter	 	Summer	 	Winter	 	Summer	 	 	 	 
	First 200 kW
	 	$	11.60	 	 	$	17.49	 	 	$	8.91	 	 	$	13.21	 	 	$	9.49	 	 	$	14.40	 	 	$	9.07	 	 	$	14.69	 	 	 	R,I	 
	Next 800 kW
	 	$	10.34	 	 	$	16.53	 	 	$	8.42	 	 	$	13.07	 	 	$	8.67	 	 	$	14.07	 	 	$	8.70	 	 	$	14.63	 	 	 	R,I	 
	Next 9,000 kW
	 	$	9.55	 	 	$	15.96	 	 	$	7.97	 	 	$	12.81	 	 	$	8.08	 	 	$	13.69	 	 	$	8.37	 	 	$	14.51	 	 	 	R,I	 
	Next 20,000 kW
	 	$	9.24	 	 	$	15.69	 	 	$	7.82	 	 	$	12.63	 	 	$	7.94	 	 	$	13.60	 	 	$	8.28	 	 	$	14.46	 	 	 	R,I	 
	Over 30,000 kW
	 	$	8.16	 	 	$	14.00	 	 	$	6.87	 	 	$	11.10	 	 	$	6.94	 	 	$	11.97	 	 	$	7.38	 	 	$	12.95	 	 	 	R,I	 
	Daily Customer Charge
	 	NA	 	NA	 	NA	 	NA	 	NA	 	NA	 	$	1.4620	 	 	$	1.4620	 	 	 	R	 





Note: IPC zone monthly customer charge of approximately $44.47 to be phased out through the Rate
Equalization process.




Energy Charge per kWh:




	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 
	Zone	 	IES
— North Zone		 	IES
— South Zone		IES
— South Zone		IPC Zone	 	 	 	 
	Rate Codes	 	807-8	 	300, 307-8	 	320, 327-8	 	440, 447-8	 	 	 	 
	Season	 	Winter	 	Summer	 	Winter	 	Summer	 	Winter	 	Summer	 	Winter	 	Summer	 	 	 	 
	On Peak
	 	 	1.232	¢	 	 	1.984	¢	 	 	1.655	¢	 	 	2.450	¢	 	 	1.214	¢	 	 	1.910	¢	 	 	1.237	¢	 	 	1.940	¢	 	 	R,I	 
	Off Peak
	 	 	0.486	¢	 	 	1.232	¢	 	 	0.744	¢	 	 	1.526	¢	 	 	0.553	¢	 	 	1.214	¢	 	 	0.600	¢	 	 	1.069	¢	 	 	R,I	 
	Non TOD Option
	 	NA	 	NA	 	 	1.108	¢	 	 	1.910	¢	 	 	0.837	¢	 	 	1.518	¢	 	 	0.866	¢	 	 	1.510	¢	 	 	R,I	 






Summer Period:




From June 16 to September 15.




Billing Demand:



The kW demand to be used for billing purposes each month shall be the sum of the highest
15-minute demand during on-peak hours of the current month plus 50% of the amount by which the
highest 15-minute demand during off-peak hours exceeds the highest on-peak demand, but not less
than 75% of the highest monthly billing demand similarly determined during the previous months
of June, July and August. In no month shall the monthly billing demand be less than 50 kW.



 





	 	 	 
	Date Issued: May 25, 2007
	 	 
	By: James P. Maher, Manager — Regulatory Pricing, Iowa & Minnesota

	 	Effective Date: June 30, 2006
















 






	 
	Interstate Power and Light Company

	ELECTRIC TARIFF

	Filed with the I.U.B.







	 	 	 
	 

	 	Substitute Original Sheet No. 27
	 
	 	 
	ORIGINAL TARIFF NO. 

	 	Canceling Original Sheet No. 27





 





Electric Large General Service




Usage Rate Codes: 300, 307-8, 320, 327-8, 440, 447-8, 807-8



 





Time of Day:



On-Peak/Off-Peak Definition: On-peak hours shall be from 7 a.m. to 8 p.m. CST (8 a.m. to 9 p.m.
during daylight savings time), Monday through Friday. Off-peak hours are all other times.




Excess Facilities Charge:



Any standard facilities required to provide non standard service, in excess of that permitted
under this Schedule or the Company’s Rules and Regulations, shall be provided at a monthly
amount equal to 1.6% of the Company’s investment in such facilities.




Primary Service Discounts:



Where primary service is available and provided the Customer purchases primary service and
furnishes the approved transformation and protective devices, the following discounts on demand
charges will be allowed: 4.42% for 4,160 to 34,500 volt service (when 34,600 volt service
reflects Company transformation from 69,000 volts and the 34,500 volt system is not further
transformed to supply a lower voltage Company distribution primary system), 7.50% for 69,000
and 34,500 volt service (where 34,500 volt service reflects transformation by Company from
greater than 69,000 volts, or if transformed from 69.000 volts, the 34,500 volt line is further
transformed to supply a lower voltage Company distribution primary system) and 10.00% for 115
kV service and above, A customer is not eligible for both point of delivery discounts and
primary service discounts.




Meter not at point of delivery:



Where metering is no,: done at the point of delivery such as primary metering with
secondary voltage delivery or secondary voltage metering with primary voltage, there will be a
2.0% decrease or increase in metered kW demand and kWh respectively before above rate
schedule is applied. A customer is not eligible for both point of delivery discounts and
primary service discounts.




Power Factor:



The above rate schedule is based on a power factor of 90% or higher Where the power
factor is less than 85%, the net demand charges will be increased by 1% for each whole 90% the
power factor is below 90%; likewise where the power factor is higher than 95%, the demand
charges will be decreased by 1% for each whole percent point the power factor is above 90%. The
power factor shall be determined by suitable recording instruments.




Second Nature Program:



A voluntary program, which allows customers to support generation technologies that rely on
renewable energy resources. The Second Nature program affects the Energy Cost Adjustment, see
Rider SECNAT.




Energy Cost Adjustment:



Billing under this schedule wilt include an adjustment per kWh, computed monthly to compensate
for changes in the cost of fuel as described in the Energy Adjustment Clause, Rider EAG.




Tax Adjustment Clause:



This price is subject to a Tax Adjustment, see Rider TAX.




Economic Development Clause:



See Rider ECON.




Energy Efficiency Bill Credit:



See Rider EECR.




	 	 	 
	Date Issued: June 9, 2006
	 	 
	By: James P. Maher, Manager — Regulatory Pricing, Iowa & Minnesota

	 	Effective Date: June 30, 2006
















 






Energy Efficiency Cost Recovery




Clause: See Rider EECR.




	 	 	 
	Date Issued: June 9, 2006

	 	 
	By: James P. Maher, Manager — Regulatory Pricing, Iowa & Minnesota

	 	Effective Date: June 30, 2006
















 






	 
	Interstate Power and Light Company

	ELECTRIC TARIFF

	Filed with the I.U.B.







	 	 	 
	 

	 	Substitute Original Sheet No. 27
	 
	 	 
	ORIGINAL TARIFF NO. 

	 	Canceling  Original Sheet No. 27





 





Electric Large General Service Usage




Rate Codes: 300, 307-8, 320, 327-8, 440, 447-8, 807-8
 





Prompt Payment Provision:




After 20 days, add 1 1/2% on the past-due amount.




Interruptible Service Option:




See Rider INTSERV.




Interruptible Demand Transfer Service Option:




See Rider IDTS.




Day Ahead. Hourly Time Of Use Service Option:




See Rider DAHP, Day Ahead Hourly Time Of Use.




Standby Service



This LGS Usage schedule is designed assuming the customer will take its entire electrical
requirement from Company. Company’s system is not to be used for standby or supplemental purposes
except as agreed to by Company, and as subject to inn following terms and conditions:




     I. Contracted Maximum Standby Capacity: Established by contract between Company and Customer.
The Contract Maximum Standby Capacity represents the highest 15-minute demand which Company must
stand ready to serve.



     II. Billing
Demand: Billing Demand shall be the sum of the highest 15-minute demand during the
current month plus 50% of the amount by which the Contracted Maximum Standby Capacity exceeds the
highest 15-minute demand, but not less than 75% of the highest monthly billing, demand
so determined during the previous months of June, July and August.



     III. Excess Demand: Should Customer’s highest 15-minute demand exceed its Contracted Maximum
Standby: Capacity, the following provisions shall apply:




A. The Contracted Maximum Standby Capacity shall automatically increase to the
highest 15-minute demand, and may not be decreased for a period of twelve billing
months.




B.
A one-time fee of $26.27 per kW of such excess shall be charged.



 




	 	 	 
	Date Issued: June 29, 2006
	 	 
	By: James P. Maher, Manager — Regulatory Pricing, Iowa & Minnesota

	 	Effective Date: October 20, 2006