HomeMy WebLinkAboutAgenda Packet 10/12/2010VIII. Adjournment
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Utility Advisory Committee
Jack Pittis Conference Room
Port Angeles, WA 98362
October 12, 2010
AGENDA
I. Call To Order
II. Roll Call
III. Approval Of Minutes For September 14, 2010
IV. Late Items
V. Discussion Items:
A. Wireless Mobile Data System Grant Update
B. Bonneville Environmental Foundation (BEF) Photovoltaic System Grant
Acceptance for Feiro Marine Life Center
C. 2010 Utility Rate Studies Recommendation
D. Bonneville Power Administration (BPA) Power Sales Agreement
Exhibit F Revision
E. Bonneville Power Administration (BPA) Network Integration
Transmission Service Agreement Exhibit A Revision
VI. Information Only Items:
A. Bonneville Power Administration (BPA) Residential Exchange Program
Settlement Agreement (verbal report only)
B. Advanced Metering Infrastructure (AMI) System Project Update
C. Metropolitan Area Network (MAN) Services Agreement Core Switching
Equipment and Customer Premises Equipment Inspection Report
VII. Next Meeting Date November 9, 2010
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ORGANIZATION
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I. Call To Order
Vice Chairman Reed called the meeting to order at 3:00 p.m.
II. Roll Call
UAC Assigned Cherie Kidd, Max Mania
Councilmembers Present:
Other Councilmembers
Present:
Other Councilmembers
Absent:
UAC Members Present:
UAC Members Absent:
Staff Present:
Others Present:
III. Approval Of Minutes
Vice Chairman Reed asked if there were any corrections to the minutes of September
14, 2010. Councilmember Perry moved to approve the minutes. Councilmember Kidd
seconded the motion, which carried unanimously.
IV. Late Items:
Application
City Council Special Meeting/Utility Advisory Committee
Jack Pittis Conference Room
Port Angeles, WA 98362
September 14, 2010
3:00 p.m.
V. Discussion Items;
Pat Downie, Don Perry
Dan Di Guilio, Brooke Nelson, Brad Collins
Vice Chairman Reed
Paul Elliott
Kent Myers (3:30), Bill Bloor, Glenn Cutler, Dan McKeen,
Larry Dunbar, Steve Sperr, Mike Puntenney, Phil Lusk,
Kathryn Neal, Terri Partch, Cate Rinehart
John Mock Crestwood Convalescent Center
Richard Croston HD Supply Utilities
Tom Callis Peninsula Daily News
Perry Spring Clallam County DCD
Dick Goodman KONP
Utility Advisory Committee Medic 1 Representative
A. Utility Advisory Committee Medic 1 Representative Application
Dan McKeen, Fire Chief introduced John Mock, administrator for Crestwood
Convalescent Center. The representative application was reviewed and Mr. Mock was
interviewed.
Councilmember Perry moved to recommend City Council appoint Mr. John Mock
as the Medic 1 representative on the Utility Advisory Committee. Councilmember
Kidd seconded the motion, which carried unanimously.
B. Shared Resource Conservation Manager Program Update
Phil Lusk, Power Resources Manager, introduced Perry Spring as the new Shared
Resource Conservation Manager who will assist the city in establishing and
implementing long -term energy efficiency strategies. There was a brief discussion.
C. Combined Sewer Overflow Loan Application For FY2010
Kathryn Neal, Engineering Manager, reviewed the Phase 1 CSO project costs and project
funding. There was a lengthy discussion.
Councilmember Perry moved to recommend City Council authorize the Mayor to
sign the Fiscal Year 2012 Funding Cycle Application certification, in an amount not
to exceed $10,000,000. In addition, if a grant or loan is approved, authorize the
Mayor to execute the agreement. Councilmember Kidd seconded the motion with
Councilmember Mania in opposition.
D. Department Of Ecology Municipal Stormwater Capacity Grant
Application
Terri Partch, Stormwater Engineer, explained that the Department of Ecology has
approximately $23.5 million available which they are offering through a non competitive
grant program to National Pollutant Discharge Elimination System Phase I and Phase II
jurisdictions. There was a brief discussion.
Councilmember Kidd moved to recommend City Council authorize the City
Manager to sign the grant agreement with the Department of Ecology under the
Municipal Stormwater Capacity Grant Program in the amount of $121,229.00.
Councilmember Mania seconded the motion, which carried unanimously.
E. 2010 Utility Rate Studies Presentation
Larry Dunbar, Deputy Director of Power Systems, distributed a handout and gave a
power point presentation reviewing the various proposed rate and fee adjustments. There
was a lengthy discussion.
Councilmember Mania moved to recommend City Council proceed with a public
hearing on utility rate and fee adjustments for the Electric, Water, Wastewater,
Solid Waste Collection, Transfer Station, and Stormwater Utilities. Councilmember
Perry seconded the motion, which carried unanimously.
VI. Information Only Items
A. City Hall Energy Conservation Project Update
Phil Lusk, Power Resources Manager, provided an update on the construction schedule.
B. Advanced Metering Infrastructure System Project Update
Larry Dunbar, Deputy Director of Power Systems provided an update on the project.
C. Broadband Technology Opportunities Program Grant Update
Larry Dunbar, Deputy Director of Power Systems reported on the status of the City's
grant. Vice Chairman Reed commented that the long -term cost of operating and
maintaining a system needs to be reviewed, and that obtaining a copy of the accepted
grant application is essential.
VII. Next Meeting Date: October 12, 2010
VIII. Adjournment: 5:12 p.m.
Don Perry, Deputy Mayor Janessa Hurd, City Clerk
Dean Reed, Vice Chairman Cate Rinehart, Administrative Specialist II
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Date:
From:
To: Utility Advisory Committee
W A S H I N G T O N U.S.A.
Utility Advisory Committee Memo
October 12, 2010
Terry Gallagher, Police Chief
Dan McKeen, Fire Chief
Glenn A. Cutler, P.E., Director of Public Works and Utilities
Subject: Wireless Mobile Data System Grant Update
Summary: At the direction of City Council, staff and Columbia Telecommunications
Corporation prepared a federal Broadband Technology Opportunities Program grant application
for a wireless mobile data system in partnership with the Northwest Open Access Network®
(NoaNet). The grant application was successful and NoaNet accepted the grant on September 15,
2010 and is in the process of preparing the City's sub -grant.
Recommendation: For information only, no action requested.
Background/Analysis: A wireless mobile data system covering the City of Port Angeles
would be a technological enhancement that would result in more efficient, effective and safer
operations for both Police and Fire services. The Public Works and Utilities Departments would
also benefit from this technology.
The system would provide field personnel with instant access to information that would otherwise
have to be relayed through slower multiple communications networks, which can often make the
difference in achieving a successful outcome. Information is critical to effective law enforcement,
and is vital to the safety of both our police and fire personnel. A wireless mobile data system
would allow local public safety agencies to move into the 21 Century in terms of data
management and the more efficient use of their very limited time and resources.
The Clallam County Public Utility District No. 1 (District) and Northwest Open Access Network®
(NoaNet) allowed the City to be a sub grantee under their application. The allowance was in
exchange for engagement in more discussion intended to produce a mutually beneficial agreement
to allow expanded District telecommunications facilities within the City and consent to provide
wholesale telecommunications services within the City. On September 15, 2010, NoaNet accepted
the BTOP grant, a sub -grant offer to the City for the wireless mobile data system from NoaNet is
anticipated in the near future. The BTOP grant only allows the City two years to complete the
wireless mobile data system.
N \UAC \Final \BTOP Grant Acceptance Consulting Services Amendment No 2 doc
Wireless Mobile Data System Grant Update
October 12, 2010
Page 2
Staff plans to negotiate the allowances described above as part of an amendment to the District's
Telecommunications Right -of -Way license, which is expiring next year. An amendment has been
drafted and is being reviewed by the City Attorney's office prior to negotiation with the District.
At their last meeting the Utility Advisory Committee suggested a request be made to NoaNet to
provide a complete copy of the grant application to the City. The request was made, however,
only partial information has been provided at this time.
As part of the City's sub -grant application, the City's consultant, Columbia Telecommunications
Corporation (CTC), prepared a preliminary business plan for the wireless mobile data system that
anticipated outsourcing services for design, construction, operation and maintenance. The
business plan also envisioned that excess network capability could be used by a vendor to provide
Internet access services to the public.
Staff has contacted other agencies experienced in wireless mobile data systems such as the Cities
of: Ripon, CA; Lebanon, OR; Prineville, OR; and Brookline, MA. Based on the experience of
other cities staff now anticipates a much longer equipment life (previously 7 years was assumed
and now from 12 to 20 years is reasonable which is similar to voice radio equipment) and that
outsourcing design, construction, operation, maintenance, and services to the public would
significantly lower the City's ongoing costs. Staff plans to update the business plan and return to
the Utility Advisory Committee with more realistic financial planning expectations next month.
Mr. Dick Bull, the former Chief of Police for the City of Ripon, CA, will be joining the meeting by
conference call to share his knowledge and experience operating and maintaining a wireless
mobile data system. Mr. Bull is currently serving as the Outreach Specialist for the National Law
Enforcement and Corrections Technology Center as a wireless mobile data system subject matter
expert.
N: \UAC \Original \Solar4R Schools Funding Agreement.doc
W A S H I N G T O N U.S.A.
Utility Advisory Committee Memo
Date: October 12, 2010
To: Utility Advisory Committee
From: Phil Lusk, Power Resources Manager
Subject: Bonneville Environmental Foundation Solar4R Schools Funding Agreement
Summary: The Bonneville Environmental Foundation offered the City a Solar 4R Schools
Funding Agreement for a renewable energy demonstration and education program at the Feiro
Marine Life Center.
Recommendation: Forward a recommendation to City Council to authorize the City
Manager to sign the Solar 4R Schools Funding Agreement with the Bonneville Enironmental
Foundation for the Feiro Marine Life Center.
Background/Analysis: In July 2009, the Feiro Marine Life Center (FMLC) requested
support from the City of Port Angeles for a renewable energy education program. The City
submitted a request to the Bonneville Power Administration (BPA) for funds under the
Conservation Rate Credit (CRC) Renewables Option (RO) for the renewable energy education
program at the FNLC. The City received an allocation $18,739 from BPA for the CRC RO. The
FMLC has moved forward with their proposal for a renewable education program.
The FMLC applied to the Bonneville Environmental Foundation (BEF) under the Solar 4R
Schools program for additional funding and support for the renewable energy education program.
The Solar 4R Schools program provides hands -on teaching tools such as science kits, lesson plans
and photovoltaic solar arrays so students can learn about solar, wind and other renewable energy
technologies. BEF approved the FMLC application and is proposing to install a 2kW photovoltaic
(PV) system along with monitoring equipment, teacher training, science kits, and renewable
energy guides for the renewable energy education program at the FMLC. The estimated cost for
the project is $35,400. BEF has submitted a Solar 4R Schools Funding Agreement to the City
requesting the $18,739 in RO funds for the project, which is reimbursed by the Bonneville Power
Administration. BEF will pay the remainder of the project cost.
Staff recommends that the Utility Advisory Committee forward a recommendation to City Council
to authorize the City Manager to sign the Solar 4R Schools Funding Agreement with the
Bonneville Enironmental Foundation for the Feiro Marine Life Center.
ITEM
11;,'itrtr �r411�
240 SW First Ave, Portland, OR 97204
Phone: 503- 248 -1905
Fax. 503 248 -1908
Funding Partner
City of Port, Angeles
Kent Myers
321 E 5th Si
Port Angeles, WA 98362
360 417 4718
Project Quote
Pricing
DESCRIPTION Mechanism
Project Management Fee Fixed
Site Survey Fixed
Weather Station/ Data monitorini equipment Pass Through
2 kW PV System Pass Through
S4RS Kiosk Fixed
Flash Page Fixed
Add Fiero Marine Life Ctr to S4RS Web Site Fixed
Teacher Training workshop Fixed
Advanced Science Kit Fixed
Renewable Energy Activity Guide Fixed
Travel Fixed
QetaiCed Uesc�jpfjon o£ rProrcts and
S evice s
r ,av
Solar4R Schools Funding Agreement
DATE: 9/21/2010
Agreement <Contract Number>
Job Name: Fiero Marine Life Center
Installation Location
Fiero Marine Life Center
Deborah Moriarty
315 North Lincoln St
Port Angeles,WA 98362
360 417 6254
Units UNIT PRICE
1 5
1
1
1
1
1
1 300
1 750
1 2,500
3 100
20 5 75
ANTICIPATED TOT/
6,000
800
2,500
15,000
3,750
2,000
TOTAL
6,000
800
2,500
515,000
3,750
2,000
300
750
2,500
300
1,500
535,400
BEF may deliver as many as three types of products and services under this Agreement. BEF charges a fixed
Project Management Fee, based on project complexity and time required. BEF also sells intemally- developed
Educational and Marketing Products and related services at the rate provided on the most current pricing list.
Finally, BEF passes through all "Hard Costs" directly to our customers with no markup. These are costs incurred by
BEF in the course of completing the project, and include installation or contractor labor, inverters, balance of
systems, data monitonng equipment, and other related hardware.
The City of Port Angeles agrees to pay for products and services requested under this Agreement in an amount
not to exceed $18,739, unless both parties agree to such a modification in an official, signed Change Order.
After completing a project, BEF will submit to City of Port Angeles an invoice and supporting documentation that
itemizes the actual costs of the project. The City of Port Angeles will remit payment in full within 30 days of receipt.
AAd'drtionai Coaditi'c`'ris45° ,;4 1: 4
1 This Agreement is not intended to form a partnersip or joint venture between the Parties.
2. Each Party will indemnify and defend the other Party and its directors, officers employees, agents,
representatives, and affiliates and hold them harmless from and against any and all losses, liabilities, damages,
claims, suits, actions, judgments, assessments, costs and expenses, including without limitation interest, penalties,
attomey fees, any and all expenses incurred in investigating, prepanng or defending against any litigation,
commenced or threatened, or any claim whatsoever, and any and all amounts paid in settlement of any claim or
litigation asserted against, imposed on, or incurred or suffered by any of them, directly or indirectly, as a result of or
arising from the negligent or wrongful acts or omissions of the other Party, from any breach of this Agreement.
3. No amendment to this Agreement will be effective unless it is in writing and duly executed by authonzed
representatives of the Parties. This Agreement will not be varied, supplemented, qualified or interpreted by any
pnor course of dealing between the Parties or by any usage of trade.
4. This Agreement shall be govemed in accordance with the laws of the State of Washington.
;Aborovartol3egifi VYot
The person signing below represents that he or she is authorized to approve the terms and conditions of this
Agreement on behalf of the Party for whom they sign. By signing this Agreement he or she authorizes BEF to begin
work.
Authorized by Organization Date
Kent Myers, City Manager
Please address any questions about this Agreement to Dick Vi andersche /d,• dwanderscherd@b -e-f org, phone: 503- 1
248 -1905
W A S H I N G T O N U.S.A.
Utility Advisory Committee Memo
Date: October 12, 2010
To: Utility Advisory Committee
From: Larry Dunbar, Deputy Director of Power Systems
Subject: 2010 Utility Rate Studies Recommendation
Summary: In 2008, FCS Group completed comprehensive rate studies for the Electric, Water,
Wastewater, Solid Waste Collection and Transfer Station utilities. Staff will seek a
recommendation from the Utility Advisory Committee on the recommended retail rate and fee
adjustments at today's meeting.
Recommendation: Forward a favorable recommendation to City Council to proceed with
the proposed rate and fee adjustments for the Electric, Wastewater, and Transfer Station
Utilities.
Background/Analysis: In 2008, FCS Group completed comprehensive rate studies for the
Electric, Water, Wastewater, Solid Waste Collections, and Solid Waste Transfer Station utilities.
For the last two years staff has updated the studies and has not used a consultant.
On September 14, 2010, the Utility Advisory Committee recommended that City Council proceed
with a public hearing. The City Council public hearing was held on October 5, 2010. The
proposed rate and fee adjustments would be effective January 3, 2011. City Council directed staff
to return to the Utility Advisory Committee to further discuss and consider electrical work permit
fees and water connection fees. At today's meeting staff will summarize the input received at the
October 5, 2010 public hearing and any additional input received since then.
Staff recommends that the Utility Advisory Committee forward a favorable recommendation to
City Council to continue the public hearing, close the public hearing, then adopt rate and fee
ordinance amendments.
N: \UAC\Final \Utility Retail Rate and Fee Adjustments Recommendation.doc
October 12, 2010
Utility Advisory Committee
Utility Rate Study Presentation
?ORT
Cs e'
Larry Dunbar, Deputy Director of Power Systems
Proposed Agenda
1. Review current proposed rates fees
2. Review City Council and public
comments
3. Recommendations
1
2011 Proposed Rate Adjustments
Residential Customers
2011 Proposed
Utility 2010 Residential Rates Monthly Increase
Electric Base $11.00 /month $2.00
Electric Consumption 0 0582 /kWh $0.00
Storrnwater 6 00 /month $0 00
Collections Weekly Pickup 27.20 /month $0 00
Collections EOW Pickup 19 75 /month $0 00
Water Base 26 75 /month $0.00
Water Consumption 2 08/100 CF $0 00
Wastewater 44 30 /month $0 00
Wastewater CSO 430 CF 14.95 /month $2.65
Average Customer Total $212.00 /month $4 65
1,300 kWh 655 CF Without CSO $2.00
2011 Proposed Rate Adjustments
Transfer Station Utility
2
2010 Rates 2011 Proposed
Transfer Station (per ton) Increase (per ton)
Collection Entities Tons $98.20 $4.57
Self Haulers Base $10 00 $0 00
Self Haulers Tons $120.10 $5.75
Yard Waste Collection Entities Tons $27 70 $0 00
Yard Waste Self Haulers Base $5 00 $0.00
Yard Waste Self Haulers Tons $44 95 $0 00
Biosolids Collection Entities Tons $48.40 $2.25
Blue Mountain Self Haulers Base $5 00 $0.00
Blue Mountain Self Haulers Tons $204 65 $0.00
3
2
2011 Proposed Fee Adjustments
2011 Proposed
Electnc Utility 2010 Fees Fee Increase
Electrical Work Permits $119 90 $29 98
Pole Attachments $13 80 $1 20
Water Utility Residential
Connection 5/8 Inch $1,160 $120 00
Connection 3/4 Inch $1,160 $120.00
Connection 1 Inch $1,260 $130 00
Water Utility Commercial
Connection 1 Inch $1,710 $0 00
Connection 1 -1/2 Inch $3,200 $365.00
Connection 2 Inch $3,200 $365 00
Public Hearing Comments
1. Website information for water rates
questioned (correction made)
2. What's driving the electric utility base charge
increase?
3. Would a colder than average winter enhance
the electric utility's financial position?
4. How many water connections are estimated
this year?
5. Why is the proposed electric work permit fee
item "V" a 50% increase?
4
5
3
Public Hearing Comments (Continued)
6. Electrical work permit fee input requested
and received from 3 contractors
7. Could we coordinate with Sequim and Forks
to facilitate electrical inspections if the State
Department of Labor Industries takes over?
8. Wireless system grant collaboration with
County, housing authority, ambulance
authority, etc
9. Discontinue electric utility contribution to
economic development?
Public Hearing Comments (Continued)
10.No reply to City Council email about
alternative for CSO from west PA to hook?
11.Increase transfer station solid waste
recycling to reduce transport and disposal
costs
12.Future utility cost increases beyond 2011?
13.Community survey increasing utility costs
a concern
6
7
4
Public Hearing Comments (Continued)
14,(nformation technology supplemental budget
requests utility rate impacts:
Electric $79K or 0.4%
Water $42K or 1.1
Wastewater $27K or 0.5%
$9,000
$8,000
$7,000
$6,000
$5,000
$4,000
$3,000
$2,000
$1,000
Solid waste collection $16K or 0.5%
Transfer station /landfill $19 or 0.5%
Stormwater $2K or 0.2%
Electric Unrestricted Cash Balance
2.1% proposed base rate adjustment
0.2% proposed fee adjustments
3.0% remaining revenue deficiency
7\,
2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011
Electric Utility —EES Consulting
8
9
5
Utility Rate Study Summary
Fee adiustments proposed:
Electric work permits
Pole attachments
Water connection fees
Retail rate adjustments proposed:
Electric 2.3% All Retail Rates
Wastewater 4.5% All Retail Rates
Transfer station 5.0% Most Retail Rates
No retail rate adjustment proposed:
Water, solid waste collection, stormwater
Recommendations
Endorse or revise staff's recommendation
to City Council
Continue public hearing
Close public hearing
Consider adoption of 4 ordinance
amendments
Chapter 3.70 PAMC Chapter 13 57 PAMC
Chapter 13.12 PAMC Chapter 13.65 PAMC
10
11
6
October 7, 2010
I will agree that the service of the inspectors is of good quality. I feel that Trent and his crew are doing a fine
job! I feel that, unless the City of Port Angeles makes obtaining permits easier, in the same manner as WA L &I
does online, they should let L &I handle the inspections. It is inconvenient for us to obtain a permit when after
hours events occur. Also, they should meet the same requirements that L &I does for inspections, or have a
regular update that goes out notifying any changes to the code, as L &I does.lt is inconvenient to have a
correction due to a code change that was not published in a reasonable time before the work performed.If these
changes can be made in a reasonable time frame, I would agree that the city should perform the inspections and
issue the permits. Basically: System upgrades are needed and notices need to be sent in a reasonable time
before changes occur.
Andrea Hana, Sequim Valley Electric
October 11, 2010
For what it's worth,
Ken Lofstrom, Peninsula Heat
Email message responses received from 3 electrical contractors
I do not support the raising of these fees at this time. The fees are all ready higher than the state fees and I
haven't seen any added service with the past fee increase. The process for applying for a permit is lethargic and
slow with faxing and manual paperwork. Also it's hard enough now to get people to pay for permitting at the
current costs and think this increase will be detrimental to those of us trying to do the right thing by following
rules and regulations.
Also I would like to better understand how the pricing structure was developed. As an example, a common
permit bought in the county (4 circuits) costs $50.60 and the newly proposed increase for the same permit (4
circuits) is 101.80 over double. How come?
I would like to see benefit to the fee increase that has already happened before supporting any new increases.
For instance, an online permitting system similar to the one the state has implemented, which has been very
helpful and time saving.
I appreciate the work that Trent has done, especially being one man but really believe that improvement needs
to happen, especially to the application process.
Scott Smasal, Extra Mile Tech Electrical
October 12, 2010
I personally feel that the increase in the fees for low voltage thermostats should not increase as they are usually
done in conjunction with the line voltage work on a retrofit job which is also permited separately by the
electrician and inspected at the same time as the low voltage. We have the option now of going wireless on our
systems which would now be about the same cost to us and a lot less hassle. This increase may reduce the
overall permit revenue to the city if elected.
October 7, 2010
Good Afternoon,
Email message from Glenn Cutler to approximately 30 electrical contractors
I need your input concerning electrical work permit fees. You have been responsive in the past, and I hope you
will take a few minutes and share your thoughts.
A few years ago, the city met with electrical contractors to discuss increasing electrical work permit fees. At
that time, it was explained that the fees were not recovering the city's costs and that a 75% increase was
necessary. It was also discussed that the Department of Labor Industries could provide the service instead of
the city.
It was the consensus of electrical contractors at that time that the city provides a high quality and responsive
service, and there was a strong support to increase the fees. Over the last two years, the City has increased the
fees 25% annually for a total of 50 We are proposing the last 25% increase in January 2011. The proposed
fees for electrical inspections performed by the City, including all applicable taxes, are as follows:
(Intentionally left blank)
I would like your input and feedback before the issue is discussed at the Utility Advisory Committee meeting
next week. I recognize that there is never a good time to increase fees, but we are trying to provide a self
supporting and responsive service to you, our customer.
I invite you to contact me to share your thoughts on this matter and request that you do so prior to noon on
Tuesday, October 12th. I am out of the office this week and will return on Monday, October 11. Please send
me your comments via e -mail at gcutler @cityofpa.usor call me on Monday at 360 -417 -4800.
CITY OF
W A S H I N G T O N U.S.A.
Utility Advisory Committee Memo
Date: October 12, 2010
To: Utility Advisory Committee
From: Larry Dunbar, Deputy Director of Power Systems
Subject: Bonneville Power Administration Power Sales Agreement Exhibit F Revision
Summary: The Bonneville Power Administration offered the City a revision to Exhibit F of the
new Power Sales Agreement that will reduce the City's requirements for the Morse Creek
hydroelectric project.
Recommendation: Forward a favorable recommendation to City Council to authorize the
City Manager to accept the revision to Exhibit F of the Power Sales Agreement.
Background/Analysis: On October 18, 2008, City Council accepted a new Power Sales
Agreement with the Bonneville Power Administration. The City's Electric Utility currently has a
Power Sales Agreement with the Bonneville Power Administration (BPA) that is in effect through
September 2011. The new Power Sales Agreement will commence on October 1, 2011 and
conclude on September 30, 2028. The primary change in the new Power Sales Agreement is a
shift from average embedded melded rates to a Tiered Rate Methodology (TRM).
In accordance with the new Power Sales Agreement, BPA has revised Exhibit F to remove many
of the obligations included in section 4 of Exhibit F regarding generating resources that are not
scheduled to load (i.e., Morse Creek hydroelectric project). The current language, required
customers to provide BPA with prescheduling and scheduling information for these Dedicated
Resources. With the proposed revision, BPA is creating a contractual mechanism to identify that
certain listed resources do not need any sort of scheduling, and for those resources the obligations
in Exhibit F will not apply. In practical terms, this relieves the City of providing BPA schedulers
generation forecasts for resources that BPA has no scheduling need for that information.
While Revision No. 1 to Exhibit F is currently being offered by BPA to roughly 80 Load
Following customers like the City, only a handful of customers have resources that currently do
not require scheduling and therefore need the additional provision in their Exhibit F revisions to
acknowledge and address the non applicability of those requirements. A copy of the revised
Exhibit F is attached for more information.
Attachment: Proposed revision to Exhibit F of the BPA Power Sales Agreement
N: \UAC\Final\BPA Power Sales Agreement Exhibit F Revision.doc
1.1 Definitions
Revision No. 1, Exhibit F
TRANSMISSION SCHEDULING SERVICE
Effective on the Date Executed by Both Parties
This revision replaces Exhibit F to incorporate the terms and conditions of the
Transmission Scheduling Service, which includes the Transmission Curtailment
Management Service (TCMS) provisions, associated with Port Angeles' Above -RHWM Load
elections for the first Purchase Period (FY 2012 FY 2014).
1. DEFINITIONS, PURPOSE AND PARAMETERS
1.1.1 "Planned Transmission Outage" means an event that reduces the
transmission capacity on a segment of the transmission path used to
deliver Port Angeles' Dedicated Resource prior to the initial approval
of the E -Tag.
1.1.2 "Transmission Curtailment" means an event that is initiated by a
transmission provider through a curtailment to the E -Tag as a result
of transmission congestion or an outage on the path used to deliver
Port Angeles' Dedicated Resource.
1.1.3 "Transmission Event" means a Planned Transmission Outage or a
Transmission Curtailment.
1.2 Purpose
Transmission Scheduling Service is provided by Power Services to help Port
Angeles manage certain aspects of its BPA Network Integration
Transmission Service Agreement (BPA NT Agreement), to allow BPA to use
the inherent flexibilities of Port Angeles' network rights in combination with
other network customers' rights to manage BPA's power resources efficiently,
and to provide seamless scheduling for Transfer Service customers.
1.3 Parameters of Transmission Scheduling Service
Beginning October 1, 2011, and through the term of this Agreement, Power
Services shall provide and Port Angeles shall purchase Transmission
Scheduling Service. Power Services shall schedule Port Angeles' federal
power and Dedicated Resources to Port Angeles' Total Retail Load under Port
Angeles' BPA NT Agreement and/or other transmission agreement(s). Power
Services shall not provide Transmission Scheduling Service for anything
other than delivery to Port Angeles' Total Retail Load.
Power Services shall perform all necessary prescheduling and real -time
scheduling functions, and make other arrangements and adjustments,
consistent with any RSS products and any other products and services Port
Angeles is purchasing from Power Services. Port Angeles shall continue to be
responsible for all non scheduling provisions of its transmission agreement(s)
used to serve Port Angeles' Total Retail Load, in accordance with the
09PB- 13093, Port Angeles 1 of 9
applicable OATT, including, but not limited to, the designation and
undesignation of Network Resources, as defined by the applicable OATT.
Port Angeles shall be subject to the rates, terms and conditions for
Transmission Scheduling Service specified in BPA's applicable Wholesale
Power Rate Schedules and GRSPs.
2. ASSIGNMENT OF SCHEDULING RIGHTS
Prior to Power Services providing Transmission Scheduling Service, Port Angeles
shall:
(1) notify Transmission Services that Power Services is the scheduling entity for
service taken under Port Angeles' BPA NT Agreement;
(2) assign Power Services the right to acquire and manage secondary service
pursuant to section 28.4 of the BPA OATT as necessary to fulfill BPA's
obligations under this Agreement; and
(3) provide copies of Port Angeles' transmission agreement(s) used to serve Port
Angeles' Total Retail Load.
Additionally, over the term of this Agreement, Port Angeles shall provide Power
Services with any additional transmission agreements Port Angeles enters into
which are used for service to its Total Retail Load and all amendments and
modifications to current copies of Port Angeles' transmission agreement(s).
3. LOAD FORECAST
If a daily load forecast is required by Port Angeles' transmission agreement(s), then
BPA shall develop the daily and hourly load forecasts for Port Angeles' Total Retail
Load. Port Angeles shall cooperate with BPA in all load forecasting. If any load
specific information is needed for developing a daily or hourly load forecast, then
Port Angeles shall provide such information in a timely manner.
4. SCHEDULING OF PORT ANGELES' DEDICATED RESOURCES
This section 4 shall not apply to Port Angeles' following Dedicated Resource(s):
Morse Creek. BPA may unilaterally revise this list pursuant to section 9 of this
exhibit.
4.1 Prescheduling
Port Angeles shall submit a delivery schedule to Power Services for its
Dedicated Resources for delivery to its Total Retail Load which shall include
information such as the source, any points of receipt, any Open Access Same
time Information System (OASIS) reservation reference numbers needed for
the delivery of non federal power, the daily megawatt profile, and all
purchasing selling entities in the path. This delivery schedule shall be
submitted to Power Services by the earlier of one hour prior to the close of the
firm transmission prescheduling deadline associated with the transmission
agreement(s) used to deliver power to Port Angeles' Total Retail Load, or
1100 hours Pacific Prevailing Time (PPT) on the preschedule day.
09PB- 13093, Port Angeles 2 of 9
Revision No 1, Exhibit F, Transmission Scheduling Service
Port Angeles shall submit all required prescheduled information in a format
specified by Power Services.
At Power Services' request, Port Angeles shall provide Power Services
information on real power losses associated with Port Angeles' transmission
agreement(s).
4.2 Real -Time Scheduling
Power Services shall accept megawatt adjustments to Port Angeles'
Dedicated Resource schedule(s) up to the earlier of 45 minutes prior to the
hour of delivery or 25 minutes prior to the earliest of the transmission real
time scheduling deadlines associated with delivery of power to Port Angeles'
Total Retail Load.
Port Angeles shall submit all required real -time scheduling information in a
format specified by Power Services.
4.3 Transmission Curtailments
4.3.1 Notification Preference
Prior to the delivery of Port Angeles' Dedicated Resources to Port
Angeles' load, Port Angeles shall notify BPA whether it wants to
receive either an electronic copy of the E -Tag or an e -mail of a
Transmission Curtailment that impacts any of Port Angeles'
Dedicated Resources. If Port Angeles chooses notification of
Transmission Curtailments by e -mail, then Port Angeles shall provide
BPA a single e -mail address for BPA to send such notifications to, and
the Parties shall revise the table in section 4.3.6 below to include the
e -mail address. BPA shall notify Port Angeles no later than
ten minutes after a Transmission Curtailment.
4.3.2 Transmission Curtailment Management Service (TCMS)
As a feature of Transmission Scheduling Service, BPA shall provide
Transmission Curtailment Management Service (TCMS) for certain
Port Angeles Dedicated Resources that require an E -Tag for delivery.
TCMS coverage shall apply when Transmission Events impact eligible
resources, with certain limitations as described throughout this
section 4.3.
In accordance with the BPA GATT, TCMS coverage shall not apply
while Transmission Services is redispatching Port Angeles' Dedicated
Resource(s) to serve Port Angeles' load during a Transmission Event.
4.3.3 Curtailment and Outage Terms and Conditions for Resources
without TCMS
This section 4.3.3 shall apply to Port Angeles' Dedicated Resources for
which Power Services is not providing TCMS coverage.
09PB- 13093, Port Angeles 3 of 9
Revision No. 1, Exhibit F, Transmission Scheduling Service
4.3.3.1 If a Transmission Curtailment occurs prior to 45 minutes
before the hour of delivery, then Port Angeles shall be
responsible for securing replacement energy or alternate
transmission, arranging delivery to the Balancing Authority
Area in which Port Angeles is located, and notifying Power
Services of the revised delivery schedule prior to 45 minutes
before the hour of delivery.
If Power Services is unable to secure secondary network
transmission for the replacement resource because Port
Angeles did not notify Power Services of the revised delivery
schedule prior to 45 minutes prior to the hour of delivery or
secondary network transmission is unavailable, then Port
Angeles shall be subject to charges consistent with the
provisions of this Agreement and all related products and
BPA's power rate schedules, including UAI charges.
4.3.3.2 Power Services shall not accept replacement delivery
schedules for Transmission Curtailments that occur less than
45 minutes before the delivery hour. Port Angeles shall be
subject to charges consistent with the provisions of this
Agreement and all related products and BPA's power rate
schedules, including UAI charges.
4.3.3.3 If a Planned Transmission Outage is announced prior to Port
Angeles' submission of a delivery schedule in pre schedule,
then Port Angeles shall be responsible for securing
replacement energy or alternate transmission, arranging
delivery to the Balancing Authority Area in which Port
Angeles is located, and notifying Power Services of the
revised delivery schedule prior to the preschedule deadline
described in section 4.1 of this exhibit.
4.3.4 TCMS Coverage Eligibility, Determination and Termination
4.3.4.1 Eligibility of Resources for TCMS Coverage
Power Services shall provide TCMS coverage for Port
Angeles' Dedicated Resource if such resource has been
granted firm transmission by all applicable transmission
providers or if Port Angeles has submitted a request for firm
network transmission to Transmission Services for such
resource and that resource has been granted firm
transmission by all other applicable providers, except as
described in section 4.3.7.1 of this exhibit.
4.3.4.2 Termination of TCMS Coverage
If BPA is providing TCMS coverage to Port Angeles for a
Dedicated Resource that has not been granted firm network
transmission and the request for firm network transmission
09PB- 13093, Port Angeles 4 of 9
Revision No. 1, Exhibit F, Transmission Scheduling Service
for such Dedicated Resource is withdrawn, or if such request
declined or invalidated without a timely resubmission of a
similar request, then Port Angeles shall notify BPA
immediately and BPA shall terminate the provision of TCMS
for Port Angeles' Dedicated Resource ten Business Days after
such notification.
4.3.5 Initial Resource Exception to Certain TCMS Limitations
In order to facilitate customer acquisition of non federal resources in
the Transition Period described in sections 4.3.5(1) and 4.3.5(2) below,
and in recognition that there may be delays in obtaining firm network
transmission, BPA will make the exception described in this
section 4.3.5.
For certain Dedicated Resources that have not yet been granted firm
network transmission by all applicable transmission providers, BPA
shall provide TCMS without the limitations described in
section 4.3.7.1.
A Dedicated Resource is eligible for these exceptions only if it meets
each of the following criteria:
(1) the Dedicated Resource is first used to serve Port Angeles'
Above -RHWM Load in FY 2012 or FY 2013 for a period of up to
five Fiscal Years;
(2) the Dedicated Resource is delivered in both a Flat Annual
Shape and Flat Within -Month Shape and used to serve Port
Angeles' Above -RHWM Load for at least one Fiscal Year in
duration;
(3) the Dedicated Resource is a market purchase consistent with
the terms of the Western Systems Power Pool Service
Schedule C;
(4) the Dedicated Resource is delivered at a point of receipt
between the BPA Balancing Authority Area and the source
Balancing Authority Area, delivered to the Northwest Market
Hub on firm transmission, or delivered to the Mid -C hub as
defined in Transmission Services Business Practices with a
contractual arrangement that allows a new schedule to
originate from the Mid -C hub; and
(5) the Dedicated Resource is recognized by Transmission Services
as a firm resource for purposes of designation as a Network
Resource and a request for firm network transmission for the
Dedicated Resource has been submitted to all applicable
Transmission Providers, and Port Angeles is actively in the
09PB- 13093, Port Angeles 5 of 9
Revision No. 1, Exhibit F, Transmission Scheduling Service
Yes
I
process of obtaining firm network transmission for the
Dedicated Resource.
Name and E -mail
Name of Dedicated address of Port
Resource Angeles scheduling
contact
None at this time 1
All Applicable Contract path for
Firm Network TCMS Coverage OASIS Assignment delivering resource (Source
Transmission Reference Numbers pOR- POD Sink)
(AREF)
1
If a Dedicated Resource ceases to meet any of the conditions described
in this section 4.3.5, BPA shall only provide TCMS, a s described in all
other sections of this exhibit.
4.3.6 TCMS Coverage by Resource
The Parties shall list Port Angeles' Dedicated Resources that require
an E -Tag in the table(s) below, and indicate whether Port Angeles
shall purchase TCMS for each resource. BPA shall update the table(s)
below as needed.
Location of Resource
(Balancing
Authority Area)
In
No Process
Yes No
Name and E -mail
address of contact at
resource
4.3.7 Curtailment and Outage Terms and Conditions for Resources
with TCMS Coverage
For Dedicated Resources with TCMS coverage identified in
section 4.3.6 above, BPA shall deliver replacement power to Port
Angeles during any Transmission Event that is announced for the
hour(s) of delivery that affects Port Angeles' Dedicated Resource,
through the duration of the Transmission Event, if any of the
following occur:
(1) the Transmission Event affects any firm Point -to -Point
Transmission used to deliver the resource to Port Angeles' load,
as identified in section 4.3.6 of this exhibit; or,
(2) the Transmission Event affects the Secondary Network
Transmission used to deliver the resource to Port Angeles' load,
as identified in section 4.3.6 of this exhibit; or,
(3) Transmission Services has curtailed firm network transmission
pursuant to section 33.6 or 33.7 of the BPA GATT.
If the Transmission Event is multiple hours in duration, BPA shall
provide TCMS coverage for the entire Transmission Event. During
any Planned Transmission Outage that impacts Port Angeles'
Dedicated Resource with TCMS coverage, BPA may, at BPA's sole
09PB- 13093, Port Angeles 6 of 9
Revision No. 1, Exhibit F, Transmission Scheduling Service
discretion, obtain alternate transmission from such resource to Port
Angeles' load instead of delivering replacement power to Port Angeles'
load. If a Planned Transmission Outage affects a Dedicated Resource
with TCMS coverage, then Power Services shall notify Port Angeles of
such Planned Transmission Outage.
If a Planned Transmission Outage is cancelled or adjusted such that
Port Angeles is able to deliver any portion of the resource to load
normally during any portion of the previously announced Planned
Transmission Outage, then Port Angeles shall do so.
4.3.7.1 Limitations on the Frequency of TCMS Coverage
If Port Angeles is purchasing TCMS for a Dedicated Resource
with firm transmission from all applicable providers, or if
Port Angeles is purchasing, TCMS for a Dedicated Resource
as provided for in section 4.3.5, then BPA shall provide TCMS
without the following limits identified in this section 4.3.7.1.
If, pursuant to section 4.3.4 above, BPA has allowed Port
Angeles to purchase TCMS for a resource that has not yet
been granted firm network transmission, then throughout
each Fiscal Year for each such resource, BPA shall
periodically assess how frequently TCMS has been needed
during that Fiscal Year. If BPA determines that in such
Fiscal Year TCMS has been used to replace such Dedicated
Resource in ten separate occurrences, where each occurrence
TCMS was used was due to a separate Transmission Event
on a different day, and for a cumulative total of at least
168 hours, BPA may terminate Port Angeles' TCMS coverage
for such resource 30 days after providing notice to Port
Angeles.
4.3.7.2 TCMS Payment Obligations
Port Angeles shall be subject to charges for Transmission
Scheduling Service, including applicable costs for TCMS,
consistent with the provisions of this Agreement and BPA's
Wholesale Power Rate Schedules and GRSPs, including any
applicable UAI charges. Additionally, during a Transmission
Event, BPA shall not assess a UAI charge on a Dedicated
Resource with TCMS coverage.
4.3.8 TCMS Coverage after Termination
If TCMS coverage is terminated, pursuant to section 4.3.4 or 4.3.7.1 of
this exhibit, Port Angeles shall be responsible for obtaining
replacement power during any Transmission Event that impacts such
Dedicated Resource and for any applicable UAI charges that may
apply pursuant to section 4.3.3 above.
09PB- 13093, Port Angeles 7 of 9
Revision No. 1, Exhibit F, Transmission Scheduling Service
9. REVISIONS
In addition, for any resource for which BPA has terminated TCMS
coverage due to frequency of use, as described in section 4.3.4 or
4.3.7.1 of this exhibit, BPA shall allow Port Angeles to resume
purchasing TCMS for the resource only after Port Angeles notifies
BPA that such resource has obtained firm network transmission.
5. E -TAGS
To the extent E -Tags are required by transmission provider(s), Power Services shall
create all E -Tags necessary for delivery of energy to Port Angeles' Total Retail Load.
6. GENERATION IMBALANCE
Port Angeles shall be responsible for costs associated with deviations between the
scheduled Dedicated Resources for an hour and the actual generation produced
across such hour; provided, however, if Port Angeles submits a delivery schedule
consistent with all provisions of this exhibit and BPA receives that delivery
schedule, and a generation imbalance results from a BPA scheduling error, then
BPA shall accept responsibility for the generation imbalance associated with the
BPA scheduling error.
7. PENALTIES
If Port Angeles fails to submit prescheduling or real -time scheduling information to
BPA as required and by the deadlines in section 4 of this exhibit, then Port Angeles
may be subject to applicable UAI charges, consistent with BPA's applicable
Wholesale Power Rate Schedules and GRSPs.
8. AFTER THE FACT
BPA and Port Angeles agree to reconcile all transactions, schedules and accounts at
the end of each month (as early as possible within the first ten calendar days of the
next month). BPA and Port Angeles shall verify all transactions pursuant to this
Agreement as to product or type of service, hourly amounts, daily and monthly
totals, and related charges.
9.1 BPA's Right to Revise the Exhibit
BPA may unilaterally revise this exhibit:
(1) to implement changes that BPA determines are necessary to allow it
to meet its power and scheduling obligations under this Agreement, or
(2) to comply with requirements of WECC, NAESB, or NERC, or their
successors or assigns, or
(3) to update the table in section 4.3.6 to reflect which resources BPA
provides TCMS for.
BPA shall provide a draft of any material revisions of this exhibit to Port
Angeles, with a reasonable time for comment, prior to BPA providing written
notice of the revision. Revisions are effective 45 days after BPA provides
09PB- 13093, Port Angeles 8 of 9
Revision No. 1, Exhibit F, Transmission Scheduling Service
written notice of the revisions to Port Angeles unless, in BPA's sole judgment,
less notice is necessary to comply with an emergency change to the
requirements of WECC, NAESB, NERC, or their successors or assigns. In
this case, BPA shall specify the effective date of such revisions.
9.2 Port Angeles' Right to Cease Purchasing Transmission Scheduling
Service and the Associated Exhibit Revision
If Port Angeles is no longer purchasing:
CITY OF PORT ANGELES
(1) BPA's Diurnal Flattening Service; or
(2) BPA's Secondary Crediting Service; or
(3) power from BPA at a Tier 2 rate;
then Port Angeles, with six months' notice to BPA, may elect to cease
purchasing Transmission Scheduling Service from Power Services and the
Parties shall modify this exhibit to eliminate the terms and conditions of such
service.
10. SIGNATURES
The Parties have caused this revision to be executed as of the date both Parties have
signed this revision.
UNITED STATES OF AMERICA
Department of Energy
Bonneville Power Administration
By BY ?dli/ v��•���2/L�
Name Dan DiGuilio Name Shannon K. Greene
Title Mayor Title Account Executive
Date Date 0 62
(PSW-S PM CUST_SKG PORT ANGELES PSC_2009_PF_Reg,onal Dialogue Exh F_Rev# 1 PA_13093_20101006_Exh F_Rev# 1_Final doc) 10/06/2010
09PB- 13093, Port Angeles 9 of 9
Revision No. 1, Exhibit F, Transmission Scheduling Service
pO!RT
NGEL
W A S H I N G T O N U.S.A.
Utility Advisory Committee Memo
Date: October 12, 2010
To: Utility Advisory Committee
From: Larry Dunbar, Deputy Director of Power Systems
Subject: Bonneville Power Administration Network Integration Transmission Service
Agreement Exhibit A Revision
Summary: The Bonneville Power Administration offered the City a revision to Exhibit A of the
Transmission Services Agreement.
Recommendation: Forward a favorable recommendation to City Council to authorize the
City Manager to accept the revision to Exhibit A of the Network Integration Transmission
Service Agreement.
Background /Analysis: On September 27, 2006, City Council accepted a new Network
Integration Transmission Service Agreement with the Bonneville Power Administration. The new
Network Integration Transmission Service Agreement concludes on September 30, 2036.
In accordance with the Network Integration Transmission Service Agreement, BPA has revised
Exhibit A to incorporate the following updates:
Metering descriptions, points of receipt and delivery
The incorporation of the new BPA Power Sales Agreement as a network resource.
Staff recommends that the Utility Advisory Committee forwards a favorable recommendation to
City Council to authorize the City Manager to accept the revision to Exhibit A of the Network
Integration Transmission Service Agreement.
Attachment: Proposed revision to Exhibit A of the BPA Transmission Services Agreement
N: \UAC\Final\BPA Transmission Services Agreement Exhibit A Revision.doc
This Revision No. 1 to Table 1: 1) converts Exhibit A, Table 1 to the Transmission Provider's
updated template format, 2) adds the Transmission Customer's Regional Dialogue Power
Sales Contract to Section 2(b), and 3) updates Points of Receipt, Points of Delivery, and
metering descriptions. Exhibit A, Table 2 remains in effect unchanged.
1. TERM OF TRANSACTION
Service Agreement Start Date: at 0000 hours on October 1, 2006.
Service Agreement Termination Date: at 0000 hours on October 1, 2036.
2. NETWORK RESOURCES
Pursuant to section 29.2 and 30.2 of Transmission Provider's Tariff, Transmission
Customer has designated the following Network Resources:
Designated
Start Capacity
Resource Name Date Stop Date (MW)
Morse Creek Hydro 10/15/1991 9/30/2011 0.465
Source (Contract
No.) or Resource
Name (if within
BPA Bal. Auth.)
BPA
(OOPB- 12054)
BPA
(09PB- 13093)
EXHIBIT A
SPECIFICATIONS FOR
NETWORK INTEGRATION TRANSMISSION SERVICE
TABLE 1, REVISION NO. 1
TRANSMISSION SERVICES REQUEST
Assign Ref: 1470701
(The Assign Ref represent the term of the NT Service Agreement)
(a) Generation Owned by the Transmission Customer
(b) Generation Purchased by the Transmission Customer
Start
Date Stop Date
10/1/2001 10/1/2011
10/1/2011 10/1/2028
Designated
Capacity
(MW)
Net
Requirements
Net
Requirements
1 Bonneville Power Administration Transmission Services
2 There is no associated Assign Ref for this Network Resource
3 Federal Columbia River Power System
06TX- 12443, The City of Port Angeles
Exhibit A, Table 1, Revision No 1
Specifications for Network Integration Transmission Service
Point of
Receipt Balancing Associated
Source Authority Assign Ref
Morse Creek
Hydro
Point of
Receipt
Source
BPAPOWER
FCRPS
BPAPOWER
FCRPS
BPAT N /A
Balancing Associated
Authority Assign Ref
BPAT N /A
BPAT N /A
Page 1 of 6
Resource Name
N/A
(c) Local Resource Behind the Meter (owned or purchased)
This resource does not qualify as Declared Customer Served Load as it is
defined in the NT -10 Rate Schedule or successor rate schedules.
Start Stop
Date Date
3. POINT(S) OF RECEIPT
Designated
Capacity
(MW)
(a) Federal Generation Point(s) of Receipt
Balancing Associated Assign
Authority Ref
Transmission Customer Point of Receipt: Federal Columbia River
Power System (FCRPS);
POR Number: 3453;
Balancing Authority: BPAT;
Location: FCRPS;
Voltage: 500 kV;
Metering: Scheduled quantity;
Delivering Party: BPAT;
Exceptions: None.
(b) Non Federal Generation Point(s) of Receipt
Not applicable.
4. POINT(S) OF DELIVERY
(a) Description of Network Point(s) of Delivery
(1) Transmission Customer Point of Delivery: Nippon 69 kV;
BPA POD Name: PORTANGELES;
BPA POD Number: 163;
Balancing Authority: BPAT;
06TX- 12443, The City of Port Angeles
Exhibit A, Table 1, Revision No. 1
Specifications for Network Integration Transmission Service
Page 2 of 6
Location: the point in the Transmission Provider's Port Angeles
Substation, where the 69 kV facilities of the Transmission Provider
and the City of Port Angeles are connected for service to the Nippon
Paper Mill;
Voltage: 69 kV;
Metering: in the Transmission Provider's Port Angeles Substation in
the 69 kV circuit over which such electric power flows;
(A) BPA Meter Point Name: Nippon In;
BPA Meter Point Number: 158;
Direction for Billing Purposes: Negative;
Manner of Service: Direct, the City of Port Angeles to the
Transmission Provider;
(B) BPA Meter Point Name: Nippon Out;
BPA Meter Point Number: 459;
Direction for Billing Purposes: Positive;
Manner of Service: Direct, the Transmission Provider to the
City of Port Angeles;
Metering Loss Adjustment: Not applicable;
Exceptions: None.
(2) Transmission Customer Point of Delivery: Port Angeles 69 kV;
BPA POD Name: PORTANGELES;
BPA POD Number: 542;
Balancing Authority: BPAT;
Location: the points the Transmission Provider's Port Angeles
Substation, where the 69 kV facilities of the Transmission Provider
and the City of Port Angeles are connected;
Voltage: 69 kV;
06TX- 12443, The City of Port Angeles
Exhibit A, Table 1, Revision No. 1
Specifications for Network Integration Transmission Service
Page 3 of 6
Metering:
(A) in the Transmission Provider's Port Angeles Substation in the
69 kV circuit over which such electric power flows;
(i) BPA Meter Point Name: Port Angeles #2 Out;
BPA Meter Point Number: 152;
Direction for Billing Purposes: Positive;
(ii) BPA Meter Point Name: Port Angeles #1 Out;
BPA Meter Point Number: 251;
Direction for Billing Purposes: Positive;
Manner of Service: Direct, the Transmission Provider
to the City of Port Angeles;
(B) in the City of Port Angeles' Morse Creek Hydro Substation in
the 69 kV circuit over which such electric power flows;
(i) BPA Meter Point Name: Morse Creek In;
BPA Meter Point Number: 1564;
Direction for Billing Purposes: Negative;
06TX- 12443, The City of Port Angeles
Exhibit A, Table 1, Revision No. 1
Specifications for Network Integration Transmission Service
Manner of Service: Direct, the Transmission Provider
to the City of Port Angeles;
Manner of Service: Wheeled to System, Public Utility
District No. 1 of Clallam County to the Transmission
Provider to the City of Port Angeles;
(ii) BPA Meter Point Name: Morse Creek Stn Sry Out;
BPA Meter Point Number: 1565;
Direction for Billing Purposes: Not used;
Manner of Service: Wheeled to System, the City of
Port Angeles to the Transmission Provider to Public
Utility District No. 1 of Clallam County;
Page 4 of 6
Metering Loss Adjustment: the Transmission Provider shall adjust
for losses between the Port Angeles 69 kV Point of Delivery and the
Morse Creek In Point of Metering (POM). Such adjustments shall be
specified in writing between the Transmission Provider and the City
of Port Angeles;
Exceptions:
(i) revenue meters at metering point (B) are owned by the City of
Port Angeles;
(ii) the Morse Creek Stn Sry Out POM is part of Public Utility
District No. 1 of Clallam County's load and should not be added
to the City of Port Angeles' power bill. This is due to a separate
arrangement between the PUD and the City of Port Angeles.
(b) Description of Transfer Points of Delivery
Not applicable. See section 4(a).
5. NETWORK LOAD
The Application provides the Transmission Customer's initial annual load and
resource information. Annual load and resource information updates shall be
submitted to the Transmission Provider at the address specified in Exhibit B
(Notices), by September 30th of each year, unless otherwise agreed to by the
Transmission Provider and the Transmission Customer.
6. DESIGNATION OF PARTY(IES) SUBJECT TO RECIPROCAL SERVICE
OBLIGATION
Transmission Customer and its affiliates (if they own or control transmission
facilities).
7. NAMES OF ANY INTERVENING SYSTEMS PROVIDING TRANSMISSION
SERVICE
None.
8. SERVICE AGREEMENT CHARGES
Service under this Agreement shall be subject to some combination of the charges
detailed below. (The appropriate charges for transactions will be determined in
accordance with the tennis and conditions of the Tariff).
06TX- 12443, The City of Port Angeles
Exhibit A, Table 1, Revision No. 1
Specifications for Network Integration Transmission Service
Page 5 of 6
8.1 Transmission charge:
2010 Transmission and Ancillary Service Rate Schedules or successor
rate schedules.
8.2 System Impact and/or Facilities Study Charge:
System Impact and/or Facilities Study Charges are not required for
service under this Agreement.
8.3 Direct Assignment Facilities Charges:
Facilities Charges are not required at this time for the service under this
Agreement.
8.4 Ancillary Service Charges:
Described in Exhibit A, Table 2 (Ancillary Service Charges) of this
Agreement.
9. OTHER PROVISIONS SPECIFIC TO THIS SERVICE AGREEMENT
None.
10. SIGNATURES
The Parties have caused this Exhibit to be executed as of the date both Parties have
signed this Exhibit.
THE CITY OF PORT ANGELES
By: By:
06TX- 12443, The City of Port Angeles
Exhibit A, Table 1, Revision No. 1
Specifications for Network Integration Transmission Service
UNITED STATES OF AMERICA
Department of Energy
Bonneville Power Administration
Name: Name: Melanie M. Jackson
(Prcnt Type) (Print Type)
Title: Title: Transmission Account Executive
Date: Date:
W \TMVIC\ CT\ Port Angeles Revisions 12443 ExA T1 R1 doc)
Page 6 of 6
W A S H I N G T O N poRT
U.S.A.
Utility Advisory Committee Memo
NGEL
Date: October 12, 2010
To: Utility Advisory Committee
From: Larry Dunbar, Deputy Director of Power Systems
Subject: Advanced Metering Infrastructure System Project Update
Summary: Several activities continue to be underway in support of the Advanced Metering
Infrastructure System project.
Recommendation: For information only, no action requested.
Background/Analysis: A commercial and industrial grant application was submitted to the
Bonneville Power Administration (BPA) on September 30, 2010 for a Demand Response (DR)
project that would be integrated into the AMI System and electric utility Supervisory Control and
Data Acquisition System. BPA has indicated that it will announce the successful applicants by the
end of this month.
Staff anticipates that it will present information at next month's meeting on the potential impacts
of a New Large Single Load (NLSL) which was included in the Retail Tiered Rate Methodology
Study. A NLSL would have retail rate impacts if the Electric Utility is required to purchase more
expense Tier 2 power supply. As part of the presentation staff will provide recommendations to
address this policy issue for the Electric Utility.
Parker LePla is scheduled to present the Communications Plan to the Utility Advisory Committee
at their November 9, 2010 meeting. The Communications Plan will include a campaign theme,
key messages, and a schedule for various educational and advertising materials for the AMI
System and Demand Response (DR) project.
AMI System proposals are continuing to be evaluated and vendors were interviewed last month.
The evaluation process is taking longer than anticipated due to the complexity of the project, and
an additional presentation from each vendor on their DR proposals is scheduled this month,
references are being checked, and a revision to their proposals will be requested. Staff now
anticipates that it may be requesting the Utility Advisory Committee's recommendation to City
Council on the AMI System Agreement at their November 9, 2010 meeting.
An executive summary of the Utility Advisory Committee involvement in the overall project is
available on the following page.
N \UAC \Final\AMI System Project RFP Update doc
AMI System Project Update
October 12, 2010
Page 2
Milestones
Advertisement
1 Proposal Deadline
1 UAC Consideration
City Council
Consideration
Milestones
UAC Consideration
City Council
Consideration
UAC Consideration
City Council
Consideration
2 Revised dates.
1
AMI
System
5/10/2010 2/18/2010 6/10/2010
8/6/2010
11/9/2010
11/16/2010
AMI
System
12/11/2011
12/18/2011
'Dates are uncertain at this time.
Request for Proposals Summary
BPA DR Projects
Commercial
Residential Industrial
1 4/19/2010 1 9/30/2010 1
1 7/13/2010 1 11/9/2010 1
7/20/2010 11/16/2010
Scope of Work Summary
BPA DR Projects
Commercial
Residential Industrial
Phase I Construction
3/8/2011
3/15/2011
Phase II Construction
12/11/2011
12/18/2011
Communications
Plan
5/10/2010
7/2/2010
8/10/2010
8/17/2010
Communications
Plan
Consultant
11/9/2010
11/16/2010
Retail TRM
Study
1/25/2010
1 3/5/2010 1
1 4/13/2010 1
4/20/2010
Retail TRM
Study
Report
8/10/2010
8/17/2010
NLSL
11/9/2010
11/16/20101
FOR' NCELES
W A S H I N G T O N U.S.A.
Utility Advisory Committee Memo
October 12, 2010
Date:
To: Utility Advisory Committee
From: Larry Dunbar, Deputy Director of Power Systems
Subject: Metropolitan Area Network Services Agreement Core Switching Equipment and
Customer Premises Equipment Inspection Report
Summary: Capacity Provisioning, Inc. replaced the core switching equipment and customer
premises equipment within the fiber optic network. The work has been inspected and accepted as
complete.
Recommendation: For information only, no action requested.
Background/Analysis: Capacity Provisioning, Inc. replaced the core switching equipment
and customer premises equipment within the fiber optic network. The replacements are a
requirement of the Metropolitan Area Network Services Agreement that City Council accepted on
March 16, 2010. The work has been inspected and accepted as complete.
The core switching equipment that has been in service since 2002 was replaced with new
equipment in accordance with the Agreement and Capacity Provisioning, Inc.'s proposal. The
customer premises equipment has also been in service since 2002 and was replaced as required by
the Agreement. The new equipment provides enhanced services and replaces equipment that has a
normal life expectancy of about seven years. On September 23, 2010, Columbia
Telecommunications Corporation inspected the work to ensure compliance with the Agreement.
The City's share of the cost was $13,008.00.
By the end of this year Capacity Provisioning, Inc. will prepare the plans and specifications for the
redundant fiber optic facilities and local area network improvements that are required by the
Agreement. Although the City has enjoyed very high reliability from the fiber optic network, the
redundant fiber optic facilities will ensure continuing services in the event of a single point of
failure. Construction is scheduled to be complete by April 15, 2011. The City's share of this
future expense in 2011 is $133,233.00. Staff anticipates that it will report on the status of this
project to the Utility Advisory Committee in May of 2011.
N. \UAC \Final\MAN Services Inspection Report doc