HomeMy WebLinkAbout9 Wholesale Power Supply Agenda Item # 9
Public Utility District
Memorandum
To: Board of Directors
From: Stephen Hollabaugh
Date: February 13, 2003
Date of Board Meeting: February 19, 2003
Subject: Workshop: Discussion of wholesale power supply proposals and
RFP process
1. WHY THIS MATTER IS BEFORE THE BOARD
The District has a RFP for wholesale power supply out at the current time. Staff
will update the Board on the process in a workshop setting.
2. HISTORY
The District needs to acquire a new power supplier starting April 1, 2003. We
have sent out an RFP to several prospective power suppliers for indicative
pricing and contract terms. We plan to work with a short list of providers to
prepare final contract terms and eventually firm pricing that will come to the
Board in March.
3. NEW INFORMATION
The District has received the first round of RFP's from prospective power
suppliers. I will describe some of these proposals and the difference in products
that were proposed. I have attached the RFP that the District distributed to
prospective power suppliers and plan to discuss and describe it to the Board.
4. RECOMMENDATION
This is a workshop item for informational purposes only. No action is requested
on this item.
TRUCKEE DONNER PUBLIC UTILITY DISTRICT
Power Supply Agreement
Request for Proposals
The Truckee Donner Public Utility District ("District") is seeking proposals from power suppliers
("Seller")for a term purchase of firm capacity/energy. The District is interested in proposals from sellers
for any or all of the products described herein.
Back round
The District was formed and operates under the State of California Public Utility District Act. The
District provides electric and water service to portions of Nevada and Placer counties. The District is
situated in the Sierra Nevada Mountains, 180 miles northeast of San Francisco, 32 miles west of Reno,
Nevada and 12 miles north of Lake Tahoe. Truckee's close proximity to surrounding ski areas and Lake
Tahoe resorts has made the area a growing center of tourism, with peak loads often occurring on
weekends or holidays.
The District derives its revenues solely from electric and water system user charges. TDPUD does not
levy any taxes against real and personal property.
The Electric System
The District serves approximately 11,000 electric customers in the Truckee and Donner Lake areas.
Sierra Pacific Power Company and Pacific Gas and Electric serve surrounding communities. The
District's annual system peak and retail sales are outlined in the table below.
Peak Load System Retail Sales
(MW) (MWh)
1998 28.8 117,410
1999 28.6 122,767
2000 28.3 126,200
2001 29.0 122,482
2002 30.2 126,879
TDPUD does not own any generation capacity. The District purchases all of its energy through bilateral
contracts with entities outside the Truckee area. Power is brought to the District's four substations and
one metering point over Sierra Pacific Power Company's ("SPPC") transmission system under the terms
of a Network Integration Transmission Service Agreement ("NITS") pursuant to SPPC's Open Access
Tariff. The Northern California Power Agency serves as a scheduling coordinator for the District.
The District is currently purchasing energy under a full requirements contract that expires on March 31,
2003. TDPUD intends to execute one or more additional contracts for wholesale power that will
commence on April 1, 2003. Beginning January 1,2005, the District will receive an allocation of Federal
hydropower from the Western Area Power Administration, Sierra Nevada Region. The quantity of energy
anticipated from this allocation is reflected in Exhibit B.
1
Electric Rates
To cover increased purchased-power costs, the District implemented increases in residential electric rates
of 1.2 cents/kWh in August of 2001, 1.2 cents/kWh in January of 2002. 0.7 cents per KWh in February of
2002 and 0.9 cents/kWh in December 2002. The rate adjustments, which were also imposed on
commercial customers, represent a 58.7% increase over the rates that were in place in the summer of
2001. TDPUD's residential rates for permanent residents are currently 10.87 cents/kWh, which are
comparable to those of surrounding investor owned utilities.
Proposal Process
The District is initiating a two-part proposal process. Part one will identify interested parties who have
the capability to deliver one or more of the desired products. Additionally, part one will identify
contractual issues that will need to be negotiated with each supplier. It is contemplated that the District
will select a short list of firms from the initial proposals. The District intends to negotiate non-rate terms
and conditions of potential contracts with each short-listed supplier. Such contract negotiations are
expected to conclude by late February,2003.
Part two will be a request for firm prices for each of the potential contracts. The District will solicit bids
on a specific structure to all short-listed firms who have successfully completed contract negotiations.
Bids will be accepted, reviewed, approved and awarded within a 24-hour period. Final bids are expected
to occur on March 5, 2003.
General Contract Terms
The District is not a member of the Western Systems Power Pool, but it is open to entering into a contract
based on many of the standard terms of the Western Systems Power Pool Agreement. Exhibit A lists
those provisions of the WSPP Agreement that the District would envision including in the final contract,
with certain modifications as noted. However, this list should not be viewed as a binding offer or
commitment by the District. As noted above, all non-rate terms of the contract will be open to negotiation.
Bidders responding to the first phase of this RFP are encouraged to propose contract terms tailored solely
for, and suitable for use as, the District's principal or sole power supply, particularly with respect to any
proposals for Product C.
1.Product A-Monthly Block Purchase
Contract Quantity A: Monthly deliveries are outlined on Exhibit B. All quantities are based on
blocks of power conforming to the following definitions: (1) Heavy Load
Hour (HLH) means scheduled deliveries from Monday through Saturday
(Except NERC Holidays) from hour ending 0700 through hour ending
2200; (2) Light Load Hour (LLH) means scheduled deliveries from
Monday through Saturday (excluding NERC Holidays)from hour ending
0100 through hour ending 0600 and hour ending 2300 through hour
ending 2400, and all hours Sundays and NERC Holidays; (3) Sunday
Heavy Load Hour (SHLH) means scheduled deliveries for Sundays and
NERC Holidays from hour ending 0700 through hour ending 2200.
Please note that during the hours 0700 through 2200 on Sundays and
NERC Holidays, the total contract quantity will he the sum of LLH and
SHLH.
Initial Delivery Date: April 1, 2003
2
Final Delivery Date: The District is interested in three possible terms:
December 31, 2005; December 31,2006; December 31, 2007
Delivery Location: The District's preferred delivery location is either Gonder/Pavant or
Midpoint. Seller will have the option to deliver at either location subject
to the constraints described in the paragraph below.
For the period April 1, 2003 through September 30, 2003, the District
has rights to import up to 18 MW into the SPPC control area over the
Gonder/Pavant interface, and to import any remaining load requirements
over the Midpoint interface. During this period, the District's total load
is unlikely to exceed 18 MW. Beginning October 1, 2003, the District
has the right to import its entire load requirements over the
Gonder/Pavant interface.
Alternate interfaces into, or within, the SPPC control area may be considered. However, any location
other than those specified will be contingent on the District obtaining necessary transmission
arrangements
Product Description: At least as firm as Firm Capacity/Energy Sale, as defined under the
Western Systems Power Pool Agreement(WSPPA), Schedule C.
Price Provisions: Fixed Price
U. Product B-Hourly Put/Call Option
Contract Quantity: I MW increments, not to exceed 15 MW
Quantity Restriction: The put/call option is intended to balance the District's loads and
resources. No calls may be exercised for resale (other than to the
District's retail customers), nor may any purchased energy be put to the
supplier.
Option Effective Date: April 1, 2003
Option Expiration Date: The District is interested in three possible terms:
December 31, 2005; December 31, 2006; December 31,2007
Exercise Period: Options may be exercised for any hour by 12:00 p.m., two days prior to
delivery.
Energy Delivery Location: The District's preferred delivery location is either Gonder/Pavant or
Midpoint. Seller will have the option to deliver at either location subject
to the constraints described in the paragraph below.
For the period April 1, 2003 through September 30, 2003, the District
has rights to import up to 18 MW into the SPPC control area over the
Gonder/Pavant interface, and to import any remaining load requirements
over the Midpoint interface. During this period, the District's total load
is unlikely to exceed 18 MW. Beginning October 1, 2003, the District
has the right to import its entire load requirements over the
Gonder/Pavant interface.
3
Alternate interfaces into, or within, the SPPC control area may be
considered. However, any location other than those specified will be
contingent on the District obtaining necessary transmission
arrangements.
Product Description: At least as firm as Firm Capacity/Energy Sale, as defined under the
Western Systems Power Pool Agreement(WSPPA), Schedule C.
Price Provisions: All energy called or put under the option shall be priced at a spread to
"Index". The District prefers the call/put premiums to be amortized in
the spread instead of an up-front payment. If Seller chooses to propose
on Product A and has embedded the premiums in the Product A fixed
price,please indicate the amount of the option premium included.
Index: "Index" shall mean the daily On-Peak and Off-Peak prices as published
by Dow Jones, or other acceptable publication applied as appropriate to
the hour the call is exercised. The following indices are preferred, but
not required:
HLH Ql-Q3 Mid-C
HLH Q4 Palo Verde
LLH Palo Verde
III. Product C-Full Requirements
Contract Quantity: The District's hourly pre-scheduled load. Historical load data is
available in Excel format.
NITS Band: The District must provide SPPC a schedule in I MW increments. Pre-
scheduled quantities may be within 2MW(+/-)of actual projected load.
Delivery Date: April I,2003
Termination Date: The District is interested in three possible terms:
December 31,2005; December 31, 2006; December 31, 2007
Energy Delivery Location: The District's preferred delivery location is either Gonder/Pavant or
Midpoint. Seller will have the option to deliver at either location subject
to the constraints described in the paragraph below.
For the period April 1, 2003 through September 30, 2003, the District
has rights to import up to 18 MW into the SPPC control area over the
Gonder/Pavant interface, and to import any remaining load requirements
over the Midpoint interface. During this period, the District's total load
is unlikely to exceed 18 MW. Beginning October 1, 2003, the District
has the right to import its entire load requirements over the
Gonder/Pavant interface.
Alternate interfaces into, or within, the SPPC control area may be
considered. However, any location other than those specified will be
4
contingent on the District obtaining necessary transmission
arrangements.
Product Description: At least as firm as Firm Capacity/Energy Sale, as defined under the
Western Systems Power Pool Agreement (WSPPA), Schedule C.
Price Provisions: Fixed Price
Proposal Form
Interested parties are asked to provide indications on the attached proposal and to provide any other
provisions or exceptions to the terms described above. The District is willing to consider alternate
arrangements that result in substantially similar economics to the products described above.
Proposals will be received by fax or by e-mail until the close of business on February 7, 2003. Please
send a copy of your proposal to both:
Mr. Stephen Hollabaugh Mr.Michael McDonald
Assistant General Manager Principal
Truckee Donner Public Utility District McDonald Partners
P.O. Box 309 222 High Eagle Rd.
Truckee, California 96160-0309 Alamo, CA 94507
Fax (530)587-1189 Fax: 925-743-8425
E-mail: stephenhollabaugh@tdpud.org E-mail: michael@mcdonaldpartners.com
Additional Information
Any questions regarding this Request for Proposals should be submitted to Mike McDonald at (925) 743-
8475.
The District reserves the right to select qualified proposers in its sole discretion. The District is not bound
to purchase any energy from any proposal pursuant to the RFP. No binding commitment shall arise on
the part of the District or Seller until and unless the parties sign a definitive agreement. The District shall
have the right, upon its sole and absolute discretion, to reject any proposal, with or without cause.
5
TRUCKEE DONNER PUBLIC UTILITY DISTRICT
POWER PURCHASE CONTRACT
PROPOSAL FORM
Name of Seller:
Contact Person for Seller:
Name:
Address:
Phone:
Fax:
E-mail:
1)Product A -Block Purchase
a) Fixed Price $/MWh
b) Does Fixed Price include a put call premium?If so,please specify: $/MWh
c) Any other terms and conditions:
2)Product B-Put Call Option
a) Energy Call Price: index+/-$ /MW h
or,
Index S read($/MWh)
HLH Q 1-Q3
HLH Q4
LLH
b) Energy Put Price: index+/- $ /MWh
Index S read($/MWh)
HLH Q1-Q3
HLH Q4
LLH
6
c) Any other terms and conditions:
3)Product C-Full Requirements
a) Fixed Price $/MWh
b) Any other terms and conditions:
4)General Terms and Conditions
7
Exhibit A—Proposed Master Sale Agreement
UTILIZATION OF WSPP AGREEMENT TERMS
The contract would incorporate by reference, and make a part of the contract, the following
provisions set forth in the WSPP Agreement effective as of September 1, 2002:
Section 9 ("Payments")
Section 10 ("Uncontrollable Forces")
Section 11 ("Waivers")
Section 12("Notices")
Section 14 ("Transfer of Interest in Agreement")
Section 21.3 as discussed below
Section 29 ("Taxes")
Section 33 ("Performance, Title, and Warranties for Transactions Under Service Schedules")
Sections C-3.1 through C-3.6, C-3.8, and C-3.10 of Schedule C.
All definitions set forth in Section 4 that are necessary for the implementation of the referenced
and incorporated provisions.
Section 21.3 of the WSPP Agreement would apply to determine damages for non-delivery or
non-receipt of power under the contract, except that with respect to any product other than
Product A, damages for non-delivery or non-receipt of power would arise only as a result of
deviations between scheduled quantities and quantities actually delivered or received, in
recognition of the fact that the Contract Quantity would be, in each hour, the amount scheduled
by TDPUD (or its authorized agent) under the contract. Further, the contract would specify that
(i) the term "firm transmission service downstream of the delivery point" in the context of
Section 21.3 refers to transmission service required to bring power to the designated points of
receipt on the Sierra Pacific transmission system and (ii) notwithstanding anything to the
contrary in the WSPP Agreement, Replacement Costs for TDPUD may include or consist of
imbalance energy charges and penalties.
In addition to those provisions of the WSPP agreement set forth above, the contract would
include the following provisions:
1. Dispute Resolution
In the event that a dispute should arise between the Parties concerning the terms and
enforcement of this Agreement and the Parties are unable to agree on a mutually
acceptable resolution, the Parties agree to attempt to resolve the issue through
mediation. Each Party shall bear its own cost of mediation, however, the mediator's
fee and expenses shall be borne equally by both Parties.
Parties may agree in writing to submit the dispute to binding arbitration. In the event
mediation is unsuccessful, the Commercial Arbitration Rules of the American
Arbitration Association shall apply. Upon their agreement to arbitration, the Parties
shall endeavor to select a single arbitrator who, by reason of his/her education and
experience, is qualified and mutually acceptable to both Parties.
8
If the Parties are unable to agree on a mutually acceptable arbitrator(s) within thirty
(30) days of their written agreement to arbitrate, either Party may withdraw its
agreement to arbitrate and pursue remedies available to it at the Commission, or in a
court of competent jurisdiction."
1I. Additional Representations and Warranties
Truckee Donner represents and warrants, which representations shall continue
throughout the term of this Agreement, as follows:
i. Truckee Donner's obligations to make payments hereunder are
operating and maintenance costs which enjoy first priority of payment
at all times under any and all bond ordinances or indentures to which
Truckee Donner is a party.
ii. Truckee Donner will increase rates and charges to its customers as
may be necessary to avoid default on its payment obligations under
this Agreement.
9
Exhibit B-Monthly Block Requirements(')
HLH
2003 2004 2005 2006 2007
Jan 20 20 20 20 21
Feb 19 19 19 19 20
Mar 18 18 18 18 18
Apr 16 16 14 14 15
May 15 15 14 14 14
Jun 16 16 15 15 15
Jul 16 16 15 15 15
Aug 16 16 15 15 15
Sep 16 16 15 15 15
Oct 15 15 15 15 15
Nov 18 18 18 18 18
Dec 21 21 21 21 22
LLH
2003 2004 2005 2006 2007
Jan 16 16 17 17 17
Feb 16 16 17 17 17
Mar 15 15 16 16 16
Apr 12 12 12 13 13
May 11 11 11 12 12
Jun 11 11 11 12 12
Jul 12 12 12 13 13
Aug 11 11 11 12 12
Sep 11 11 11 12 12
Oct 11 11 11 12 12
Nov 16 16 17 17 17
Dec 17 17 18 18 18
SHLH
2003 2004 2005 2006 2007
Jan 5 5 5 5 5
Feb 5 5 5 5 5
Mar 4 4 4 4 4
Apr 2 2 2 2 2
May 4 4 4 4 4
Jun 3 3 3 3 3
Jul 4 4 4 4 4
Aug 4 4 4 4 4
Sep 4 4 4 4 4
Oct 4 4 4 4 4
Nov 4 4 4 4 4
Dec 5 5 5 5 5
(1) Preliminary, subject to change.
10
Truckee .Donner .Public Utility District
2003 Power Supply ,R.FP Status
Schedule
Send out RFP to potential Power January 17
Suppliers — To get indication of interest
Receive Power Supply Indications of February 7+
Interest — Including some contract
language and indicative pricing
Select Short List: Work out Enabling February 10-28
Agreements: including Credit and
Collateral Requirements
Send out Final RFP to Short List February 24-28
Approve Power Supply Contract , March 5
Select Power Supplier
tart receiving power April 1, 2003
2
Western Power Markets
• TDPUD has been directly impacted by price movements in the
western power markets
• The District is situated on or near the borders of three distinct, but
closely related, energy markets
Western Energy Coordinating Council Regions
Northwest Power Rocky Mountain
Pool Area Power Area
California-Mexico
Power Area
Arizona-New Mexico-So.
Nevada Power Area
wN , . ....... ............... ---M------- 3
TDPUD Replacement Power Supply Strategy- Near Terra
• The District is currently soliciting bids for a replacement power
contract through 2007
• Seven firms responded with indications of interest on
February 7
• Six firms have been short listed to enter into negotiations
— Enabling Agreement
— Credit and collateral requirements
Morgan Stahl Duke nergy PacifiCorp
Constellation A.PS Sierra Pacific
• Final bids will be accepted on March 5
_ _. M ..... �� .. t. ._ _.... .. 4
Replacement Power Supply — Contract Terms
• The District will purchase blocks of energy to meet its average
demand.
• Blocks will be purchased for on-peak, off-peak and Sunday high
load hour periods.
— 2% Load Growth Assumed
• The winning bidder, or NCPA, will provide shaping service by the
hour.
High Load Hours-MW Low Load Flours-MW Sunday Higb Load Hours-MW
Jan 20 20 21 21 22 Jan 16 16 17 17 17 Jan 5 5 5 5 5
Feb 19 19 20 20 21 Feb 16 16 17 17 17 Feb S 5 5 5 5
Mar 18 18 19 19 19 Mar 15 15 16 16 16 Mar 4 4 4 4 2
Apr 16 16 16 16 17 Apr 12 12 12 13 13 Apr 2 2 2
May 15 15 16 16 16 May 11 Il 11 12 12 May 4 4 4 4 4
Jun 16 16 17 17 17 Jun it It I1 12 12 Jun 3 3 3 3 3
Jul 16 16 17 17 17 Jul 12 12 12 13 13 Jul 4 4 4 4 4
Aug 16 16 17 17 17 Aug 11 11 11 12 12 Aug 4 4 4 4 4
Sep 16 16 17 17 17 Sep 11 11 11 12 12 Sep 4 4 4 4 4
Oct 15 15 16 16 16 Oct 11 11 11 12 12 Oct 4 4 4 4 4
Nov 18 18 19 19 19 Nov 16 16 17 17 17 Nov 4 4 4 4 4
Dec 21 21 22 22 23 Dec 1 17 17 18 18 18 Dec 5 5 5 5 5
M _.,. _.._....... ., 5
_. ............
Replacement Power Supply - Risk Mitigation
• TDPUD's average annual market exposure will be limited to
approximately 1% of total energy purchases
• Hourly buys and sells are nearly off-set in any market.
Total Projected Load (MWh) 138,379 140,449 143,970 146,849 149,786
Total Contract Purchase (MWh) 135,848 141,968 144,144 145,504 150,406
Net Short Position (MWh) 2,531 (1,519) (174) 1,345 (620)
% of Total Load
Hourly Peak Demand (MW) 32 31 33 34 34
Hourly Maximum Buy (MW) 12 10 12 11 12
Hourly Maximum Sell (MW) (10) (11) (11) (13) (16)
Annual Block Cost $6,249,008 $6,530,528 $6,630,624 $6,693,184 $6,918,676
Annual Buy Cost 369,970 256,189 292,613 319,175 272,512
Annual Sell Benefit (205,131) (297,762) (252,489) (227,133) (278,741)
Annual Net Cost $6,413,846 $6,488,955 $6,670,747 $6,785,226 $6,912,447
% Fixed Cost 1` ; ±;g,",. ;fr,w 91,
6
Flat Load Profile Mitigates Risk
January 2002 April 2002
25,000 "tiz.a , ., ..-�.�. ^v'w 60.00 li 25,000 -.,, .k ,". t lww? *'w"av''°' '' `''• ^t '�",h' '"'.', e- 60.00
.;- „,+,i ,'s ;.y4 �'•v ,�:.2's ,,�_ 50.00
20,000 `w% "^w,. 50.00 20 000 ' ,"'F4�++ 1 W�`x xw`'w.x �,n }' •t°�"`%,
+•"iS ,.'«. +xwYa w, : 40M s 15000
3 y
t 15 000 K 30.00 ` F ' ��j„.�„,„'' ",.w<.. ` "• ` 30.00 Z,
10 000 : 10,000 n w` "t` � w`'w `*" ' }2 • �, - 20.00
20.00 �`"S *?., %.~•v'� �%%fig t`•sue+, , w ,�,s
5,000 s a so~ti* w k , k. . "`�" 10.00
10.00 %. ` wy ,», F r w , .„ ,. . ,
;`}^, rwyw ,;w. i'a "'� Yk... ` {.';',';",."v'K ,^'``.,%F•v`"'<s{w+A
vw.":'r 1. ✓ r ",�,� y "oF .,v w`:"*: � F''''}i w.. {.x✓"�r,,'"�.,"'*-v "} F "'+,w {w..,*}
`^w".'�.."', %u, Y`',; '"vw.4 .w{i i"! " y?v r x� ta{ :4. M .S.%%• ...'••e S..}F ...'}. .
t 3 5 7 9 11 13 15 17 19 21 23 1 3 5 7 9 11 13 15 17 19 21 23
Hour Ending Hour Ending
; I—Peak Day HourlyLosd—Cmtract Purchase•^^^^^•Hourly Pnces ^^^^^Hourly index; i I�^Peak Day Hourly Load®Contract Purchase--Hourly Prices ^^^^^^Hourly Index!
July 2002 October 2002
i 25,000 - w.ti �,,• �,.. 60.00 i 25000 u ., ��.� - s ,`x�.
v �.v "^w ";5, �;.;�.'`s • i, w %• ry,"'#L�'swr% "w �y�„i"v '�i+'"w '�j ��y,s„w'i„t'�.yF,`,{„ 60.00
� 5^.`+w� "y "1""+.'` ;:'^" + X K,,ti+�i• 50.00
20,000 , ' . % 20000k$. +,".,w Yv h`"+x•b.,�'`'`' *`^ a7';
"% ""'"x i
ry`t'w `".s. `} ..„ '$""•,4 ,y' ri" x 'w"3"w,?'w`*`'- 40.00
15,000 - `». .wtio % `v, '% t 15,000
s
3 ". �' •• 30,00 F .?`k'• + wyt� 2t ` ?�$k'w. 'v ",n''" 30.00
10,000 "' `'• w % "+S'.w ;.°% 10000 - c..' : , ^,,�„ ,` ;'°.'t'`w »
'kyi - 20.00 r,,. ,,� "%''fi' %„u s,7 •Fh^ $ *^„% . 20.00
5,000 " `.�% �•.�."`*., ^.,,na"•"ay. `?��. ,. 10.00 5,000 • �, �• �"�• '�"' #+� �c,r '%fit '�^ 10.00
"�+•�Yw^b h'�*�{ "% ^"ww�"` •_
1 3 5 7 9 11 13 15 17 19 21 23 1 3 5 7 9 11 13 15 17 19 21 23
Hour Ending Hour Ending
-^^*^-Peak Day Hourly Loatl'm^-�Contract Purchase Henry^'^•M Prices....:•'Hwrly Index I� �"'""'" Y Y'i _ - 1 Peak Da Houd Load—Contract Purchase^°°*'^^^Hwd Pnces Hourly Index I— ,
Transaction Results — Rate impact
• Terminating the contract and financing the settlement will avoid
significant near term rate increases.
• Fully loaded cost, including debt service, is substantially below effective
prior contract cost.
TDPUD Wholesale Power Cost
$120.00
$100.00
$80.00 r
$60.00
$40.00a
� ;y
III h`M\K�.Yy ` � �i""s� � ."yµryi"4`' .+.'. ...} '✓1��.".*t"Si ✓`:.^. ti'!✓nn � �"4{�1
$0.00
2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012
—Original Contract Replacement Contract
Based on interest rates as of Janaury 31,power curves as of February 6, and
Supplier indications submitted February 7,2003.
8
Schedule
Send out RFP to potential Power January 17
Suppliers — To get indication of
interest
Receive Power Supply Indications of February 7+
Interest — Including some contract
language and indicative pricing
Select Short List: Work out Enabling February 10-28
Agreements: including Credit and
Collateral Requirements
Send out Final RFP to Short List February 24-28
Approve Power Supply Contract , March 5
Select Power Supplier
Start receiving power April 1, 2003
.. �.. 9