HomeMy WebLinkAbout2013-1216 Study Session PACKET
CITY OF
ASHLAND
CITY COUNCIL STUDY SESSION
AGENDA
Monday, December 16, 2013
Siskiyou Room, 51 Winburn Way
5: 30 p.m. Study Session
1. Look Ahead review
2. Presentation of cost of service and rate design study for electric utility
3. Discussion of request to donate fire pumper to Guanajuato
4. Discussion of ordinance updates: City Council Rules (Chapter 2.04), Boards and
Commissions Rules and Procedures (Chapter 2.10), and Miscellaneous Chapters
(2.18 and 2.28) (continued from December 2 study session)
In compliance with the Americans with Disabilities Act if you need special assistance to participate in this
meeting, please contact the City Administrator's office at (541) 488-6002 (TTY phone number 1-800-735-
2900). Notification 72 hours prior to the meeting will enable the City to make reasonable arrangements to
ensure accessibility to the meeting (28 CFR 35.102-35.104 ADA Title 1).
COUNCIL MEETINGS ARE BROADCAST LIVE ON CHANNEL 9
VISIT THE CITY OF ASHLAND'S WEB SITE AT WW W.ASHLAND.OR.US
City of Ashland Council Meeting Look Ahead
*****THIS IS A DRAFT AND SUBJECT TO CHANGE*****
Departments
Responsible 116 117 1120 1121 213 214 2)8 2/17 2118 313 3/4 3117 3)18 3/31 411
us ~$tud Session in Siski -ou Room ® s
1 Discussion of Electric User Tax (request of Councilor Voisin) Admin/ Finance Ss
2 Discussion of Utility Subsidy Programs (request of Councilor Admin/ Finance SS
Marsh
1 - Re ular Council Meetin ~e 1
3 Proclamation re: Christmas Tree Recycle Da Diana Admin PROC
4 Mayor's State of the City speech Mayor SPCH
s Two trail easements Don/Barbara Parks CONS
s Approval of council liaisons for SDC working group (Mike/Mayor) PW Mayor CONS
Election of Council President for 2014 Barbara Recorder NEW
a Approval of Council Liaisons for 2014 (Diana/Mayor) Admin NEW
9 Approval of letter to Jackson County re: non-partisan commission Admin NEW
offices Dave
Review of Medford Water Commission's recommendation on PW
10 SDC's and approval of a letter of intent regarding SDCs (Mike) NEW
11 First Reading of an ordinance amending AMC 6.04, Business Legal ORD-1 ORD-2
Licenses Dave L.
029Stud'ISession Ca nceled(MLKIPJ"rlD_a , ® no
1/z1 Re ular Council~Meetin ``rr. rlZ
12 Second Reading of an ordinance amending AMC 6.04, Business Legal ORD-2
Licenses Dave L.
z/3 S.tud Session in Siski -ou Room v_3
Discussion of conservation easement on Imperatrice Property Admin
3 (request of Councilor Lemhouse ss
14 Discussion of potential ordinance to ban the carrying of loaded Admin SS
weapons (request of Councilor Voisin
214, Re° ularCouncil'Meetm 77,
15 I Discussion of possible ordinance related to seismic requirements CD NEW
in new construction Bill
16 Approval of new film & television production prolicy, ordinance, Admin ORD-1 ORD-2
and rate resolution Ann RES
v 7 . R Goal(Settin TSession z/a
17 Review, consolidation and update of current biennial goals Admin GOAL
2a Sid'ISessionCancelTd(P.r.esi8ensi[Qa, i IMIII
I*20
. 1;. Re ular C-ouncil(Meetin 21-8
ie Transportation Commission annual update to Council Mike PW PRES
19 Unified Land Use Ordinance (ULUO) update (Bill) CD PH OR -2
00
IRD
20 Second reading of film & television policy ordinance Ann Admin ORD-2
Page 1 of 2 12/1212013
City of Ashland Council Meeting Look Ahead
*****THIS IS A DRAFT AND SUBJECT TO CHANGE*****
Departments Responsible 1/6 117 1120 1121 213 214 218 2117 2118 313 314 3117 3118 3131 411
313 s.,EXBCI1i1Ve'$ESSIOn =»Y r• .;'='[~a3'.``v„ z 's'.-'~ s 17? t n"wax 4'^Xk4 ..ca 3/3
21 Pursuant to ORS 192.660(2)(i) - Performance Eval. EXEC
3/3 ~&tud Session in $iski ,o-u R.O.Om 3/3
22 AFN business plan Mark Electric/IT SS
3/4 Re ular C-ounciliMFetln I~ ® 3-
23 Unified Land Use Ordinance ULUO update Bill CD ORD-2
3/17 15-tud Session (1015A
ki ,ou Room 3/
361a Re ular Council Meetin i 1! ® 61.5
24 Tree Commission annual update to Council Bill CD PRES
25 Plastic bag ban recommendations Adam Admin NEW
3/31 ~$tud Session in Siski ou Room
Al Re ular Council Meetin 461
Commission Presentation Dates .2014
February 18-Transportation Commission
March 18 - Tree Commission
A dl 15 - Histonc Commission
May 20- FireWise Commission
June 3 - Band Board
Jul 15 - Forest Lands Commission
August 19 - Conservation Commission
September l6-Airport Commission
October 21 - Public Arts Commission
November 18 - Housing and Human Services Commission
December 16 - Planning Commission
Page 2 of 2 12112/2013
CITY OF
ASHLAND
Council Communication
December 16, 2013, Study Session
Discussion Regarding Request to Donate Fire Pumper to Guanajuato
FROM:
John Karns, Fire Chief, Ashland Fire & Rescue, karnsj@ashland.or.us
SUMMARY
The Fire Department is purchasing two new pumpers that will be delivered in April of 2014. That will
require that the department's two oldest pumpers be declared surplus and disposed of This is a request
that the oldest pumper, a 1991 unit, be donated to the City of Guanajuato, Mexico, with whom we have
a Sister-City relationship.
BACKGROUND AND POLICY IMPLICATIONS:
The City of Guanajuato operates a fire department utilizing primarily donated equipment and vehicles
with mostly volunteer personnel. The City of Ashland has donated fire equipment and vehicles in the
past. The Guanajuato Fire Department currently is in need of a pumper to be placed in front-line
service. A formal written request for our 1991 pumper has been received from the Mayor of
Guanajuato. This pumper would significantly improve fire safety for the residents of our sister city in
Mexico.
FISCAL IMPLICATIONS:
The vendor supplying the new pumpers, Hughes Fire Equipment, is offering trade in values of the
department's two oldest pumpers, a 1991 E-I and a 1993 Western States, of $10,000 and $25,000
respectively. A donation of the 1991 pumper would reduce the total trade-in value by $10,000.
STAFF RECOMMENDATION AND REQUESTED ACTION:
Authorize the donation of the 1991 E-1 pumper to Guanajuato.
SUGGESTED MOTION:
None. If the Council would like to support this request, Fire will bring this item to the next Council
business meeting.
ATTACHMENTS:
Letter from the Mayor of Guanajuato requesting the donation of the 1991 Fire Pumper
Page 1 of 1
~r,
its H. Ayuptamiento -
t0j ~k 1'C7t~Git+rno Ggntprorrtextittn
v
Ottghrr:15, 2013.
MR. JOHN KARNS
FIRr CNIrF
ASHLAND rIRr lv RESCUE
ASHLAND, OR. 97520
Mar Mr. Karns,
Through this letter, we would like to ask you if it is possible for you, to donate personal protective
equipment and a fire engine for combating fires, knowing of your good will and generous support of the
volunteer Firefighting Department of Guanajuato, Ashland's Sister City.
I think the vehicle that could be donated is a 1991 E-1 Cyclone Pumper.
With nothing el a to say at the momr'nt, and thanking you in advanced if you are able to grant my request, 1
take the oppa unity send yyo a warm greeting and emphasize my sincere respect.
Trulyyours,
ING. LUIS FfRfi=
PREISDENTE MUNICIPAL
O ,
GUANAJUA'fO, GTO. CIA
~ r G-s~~`yt> xf f3iFl j.
!'4W.{ v4 f Ie I `,jai 1;
~
CITY OF
ASHLAND
Council Communication
December 16, 2013, Study Session
Presentation on Cost of Service and Rate Design Study for Electric Utility
FROM:
Mark Holden, Director of IT and Electric Utility, mark.holdengashland.or.us
SUMMARY
This is a Study Session to receive and review the results of the Cost of Service and Rate Design Study
(COS) from the Electric Department. This communication provides background for the presentation.
A COS evaluates how a utility's costs are allocated across different customer classes to determine
whether these allocations are properly reflected in rates. The study recommends a series of rate
increases, beginning in FY 2015, and continuing over a period of four years. Staff is requesting
approval and guidance to proceed with rate design and, subject to future rate review and approval by
the Council, implementation of the recommendations presented in the COS.
BACKGROUND AND POLICY IMPLICATIONS:
In compliance with Council direction of November 20, 2012, a COS was performed. The COS focuses
on the long tern financial stability of the utility. A COS provides guidance to the Electric Department
for evaluating and managing charges and rates. The COS identifies the cost to serve each class of
customer and ensures these costs are recovered through equitable charge and rate structures. Taken
together with the pending Ten Year Capital Plan, the COS provides a master plan for the Electric
Department.
The City last performed a COS over twelve years ago. Industry best practices would recommend a
COS every five years. The City, through the RFP process, contracted with Utility Financial Solutions,
LLC, to perform the COS. The COS began in July, 2013.
Summary of Results
• Charge and rate adjustments are needed to reach and maintain long term financial stability
• The cost of service model is recommended as the basis for charge and rate decisions
o Unbundles cost structures
o Designed to equitably assign costs
• Cross-subsidies exist in the current rate structures. Some classes are above the identified cost of
service, some classes are below the identified cost of service.
• The Customer Charge is proposed to be the actual cost of service for each class of customer
(Ashland's currently calls this the Basic Charge). Conservation charges are unbundled from
usage rates and identified as a separate charge.
Page I of 3
I`,
CITY OF
ASHLAND
Discussion of Results
1. Rate Adjustments: Rate adjustments are necessary for the long tern reliability and long term
health of the electric system. Rate adjustments are needed to ensure no class of customer is
unfairly burdened with costs beyond those needed to support their usage. A detailed analysis of
the costs and cost drivers reveals the need to adjust rates to more fairly recover these costs. In
addition, the model provides the flexibility to deal with innovations in electric service (e.g. time
of use and demand response) without unfairly shifting costs to unrelated classes.
2. Cost of Service: Many municipal electric utilities, electric cooperatives, and Public Utility
Districts are currently operating with a cost of service model. Investor Owned Utilities (e.g.,
Pacific Corp, Portland General) operate under the cost of service model.
The cost of service model:
Identifies costs
Identifies rate classes
Distributes costs to appropriate rate class
Develops charges and rates
Builds a model of the Electric Utility based on cost of service
The cost of service model analyzes the Electric Department's costs, assigning these costs to the
class of customer benefiting the most from the cost. The cost of service model provides the
flexibility, accuracy and fairness necessary to implement (with the aid of technology)
conservation methods such as time of use and demand reduction.
3. Cross-subsidies: When examined on a cost basis, the current rate structure contains inequities
between classes. The cost of service model identifies costs, identifies the classes benefiting
from those costs, and assigns the cost to these rate classes. The current classes are not aligned
with the cost of service. However, the COS analysis shows the current rates are, on average,
within 9.9% of the desired goal. Over time, the rates can be brought in line with the cost of
service model without large swings in customer rates (please see below: Table 1: Proposed
Rate Changes).
4. Customer Charge: Customer charges (Ashland's current Basic Charge) are adjusted to cover
the actual cost to serve each class of customer. Adjustments are meant to eliminate subsidies
among classes of customers.
As conservation emerges as a higher priority for many utilities, a common industry trend is to
fund conservation through a fixed monthly customer charge. A fixed conservation charge
provides stable funding for conservation efforts and reduces the need to adjust electric rates as
the investment in conservation is adjusted up or down. The fixed rate decouples conservation
funding from the variability (most often weather related) of electric consumption.
Staff has completed the 2013 Cost of Service portion of the COS. Subject to Council guidance, a final
rate design and implementation schedule will be completed in April, 2014. First implementation of the
cost of service based rates would be July 1, 2014 (FY2015).
Page 2 of 3
IFFAM
CITY OF
ASHLAND
FISCAL IMPLICATIONS:
The COS provides the Electric Department with a methodology and road map to accomplish an
equitable rate structure while providing for the long term reliabilityand financial health of the electric
system.
A summary of rate adjustments recommended in the COS are:
Table 1: Proposed Rate Changes
Rate Adjustments by FY 2014 2015 2016 2017 2018
Increase 3.5 3.5 3.3 3.0
Recommended
(COS page 8
Notes to Table 1: The rate increase percentage is not a broad application of the single increase
percentage across all customer classes. Rather, the rate increase percentage represents the net effect of
the class-specific cost of service rates. Since some classes of customers are above and others below the
recommended cost of service rates, some customer classes will go up and some will go down.
STAFF RECOMMENDATION AND REQUESTED ACTION:
Staff recommends the COS as the basis for future charges and rates. Staff recommends the
development of interim, class specific charges and rates to gradually implement (phase in) the COS
recommendations.
Staff is seeking guidance from Council on these points:
• Does Council want staff to move forward and design charges and rates using the results of the
Cost of Service Study?
• Does Council want staff to plan for a phased implementation of the COS results (four-year
phase in)?
SUGGESTED MOTION:
N/A
ATTACHMENTS:
Executive Report, CITY OF ASHLAND, "Electric Cost of Service Study", October 2013
Page 3 of 3
PF&
,
E~xecutiue Re
CI ~ ~ SH ~ N
Electric Cost of Service ( u
October 2013
utt;
.«rm
Utility. FinaWSW '
Specia
lizing in Cost of S,emce;
Rate Design, and Financ al'Analysse
f t{v{c.
i j~xri;u` guq E n~~uc~~i ugiariz
This page intentionally left blank
Utility Financial Solutions, LLC
October 2013
Mr. Mark Holden
Director of IT and Electric Utility
City of Ashland Electric Department
90 N. Mountain Avenue
Ashland, OR 97520
Dear Mr. Holden;
We are pleased to present the executive summary draft report for an electric cost of service, financial
projection and rate design study for the City of Ashland Electric Department (Ashland). This report was
prepared to provide Ashland with a comprehensive examination of its existing rate structure by an
outside party.
The specific purposes of this rate study are:
• Determine electric utility's revenue requirements for fiscal year 2014
• Identify cross-subsidies that may exist between rate classes
• Recommend rate adjustments needed to meet targeted revenue requirements
• Identify the appropriate monthly customer charge for each customer class
This report includes results of the electric cost of service and unbundling study and recommendations on
future rate designs.
The specific recommendations included in this report are:
• Detailed rate recommendations will be made following consensus on the cost of service and
unbundling study and further discussions with utility management.
This report is intended for information and use by the utility and management for the purposes stated
above and is not intended to be used by anyone except the specified parties.
Sincerely,
Utility Financial Solutions, LLC
Mark Beauchamp
CPA, MBA, CMA
185 Sun Meadow Ct
Holland, MI 49424
U'uty Ft...., Solutio C •
TABLE OF CONTENTS
1. Introduction ............................................................................................................................................3
2. Cost of Service Summary ........................................................................................................................4
Utility Rate Process ...................................................................................................................................................4
Utility Revenue Requirements ..................................................................................................................................4
Development of Recommended Rate Track .............................................................................................................5
Recommended Rate Track ........................................................................................................................................8
Cost of Service Summary Results ..............................................................................................................................8
Cost of Service Results ..............................................................................................................................................9
Distribution Rates ...................................................................................................................................................10
3. Functionalization of Costs .....................................................................................................................11
Transmission ...........................................................................................................................................................11
Distribution .............................................................................................................................................................12
Distribution Customer Types ..................................................................................................................................12
Customer-Related Services .....................................................................................................................................12
Administrative Services ..........................................................................................................................................13
System Losses .........................................................................................................................................................13
4. Unbundling Process ..............................................................................................................................14
Distribution Breakdown ..........................................................................................................................................14
Customer-Related Cost Breakdown ........................................................................................................................15
Power Supply Cost Breakdown ...............................................................................................................................15
Combined Cost Summary .......................................................................................................................................16
5. Significant Assumptions ........................................................................................................................17
Forecasted Operating Expenses .............................................................................................................................17
Load Data ................................................................................................................................................................17
kWh Sales Forecast .................................................................................................................................................17
System Loss Factors ................................................................................................................................................17
Revenue Forecast ...................................................................................................................................................18
6. Recommendations and Additional Information ...................................................................................19
Accountant's Compilation Report ................................................................................................................22
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 1
Utility Financial Solutions, LLC •
LIST OF FIGURES
Figure 1- Breakdown of Distribution-Related Customer Costs (Without Conservation) ...........................15
LIST OF TABLES
Table 1- 2014 Projected Change ..................................................................................................................4
Table 2 - Financial Projection - Without Rate Adjustments .........................................................................5
Table 3 - Current Debt Coverage Ratio - Without Rate Adjustment ............................................................6
Table 4 - Minimum Cash Reserves - Without Rate Adjustments .................................................................7
Table 5 - Optimal Operating Income Targets Compared to Projected .........................................................7
Table 6 - Recommended Revenue Adjustments ...........................................................................................8
Table 7 - Cost of Service Summary ................................................................................................................9
Table 8-Average Revenue per kWh vs. Average Cost per kWh ...................................................................9
Table 9 - Distribution Rates by Customer Class ..........................................................................................10
Table 10- Breakdown of Ashland Cost Structure .......................................................................................14
Table 11- Power Supply Costs by Customer Class ......................................................................................15
Table 12-Total Costs by Customer Class ....................................................................................................16
Table 13- Monthly Customer Charge Comparison (Including Conservation) :...........................................16
Table 14- Projected Operating Expenses for 2014- 2018 ..........................................................................17
LIST OF APPENDICES
Appendix A- Billing and Load Data
Appendix B - Historical Load Data
Appendix C - Projected Load Data
Appendix D - Cost of Service Allocators
Appendix E - Cost of Service Expense Allocation
Appendix F - Cost of Service Plant Allocations
Appendix G - Unbundled Cost Breakdown
Appendix H - Rate Design
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 2
S Section 1
Utllity Financinl5otu[ions, LLC Introduction
1. Introduction
This report was prepared to provide the City of Ashland Electric Department (Ashland) with an electric
cost of service (COS) study and a comprehensive examination of its existing rate structure by an outside
party. The specific purposes of the rate study are identified below:
1) Determine electric utility's revenue requirements for fiscal year 2014. The Electric Division's
revenue requirements were projected for the period from 2014 - 2018 and included
adjustments for the following:
a. Projected power costs
b. Projected changes O&M costs
c. Capital improvement plan projected over next five years
2) Identify cross-subsidies that may exist between rate classes. Cross-subsidies exist when
certain customer classes subsidize the electric costs of other customers. The rate study
identifies if cross-subsidies exist and practical ways to reduce the subsidies. The cost of
service study was completed using 2014 projected revenues and expenses. The financial
projections are for the period from 2014- 2018.
3) Recommend rate adjustments needed to meet targeted revenue requirements. The primary
purpose of this rate study is to identify appropriate revenue requirements and the rate
adjustments needed to meet targeted revenue requirements. The report includes a long-
term rate track for Ashland to help ensure the financial stability of the utility in future years.
4) Unbundled electric rates. The cost of providing electricity to customers consists of a number
of components, including power generation, distribution, customer services, transmission,
and franchise fee to the general fund. Electric unbundling identifies the cost of each
component to assist the utility in preparing for electric rate restructuring and understanding
its cost structure.
5) Identify the appropriate monthly customer charge for each customer class. The monthly
customer charge consists of fixed costs to service customers that do not vary based on the
amount of electricity used.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 3
Section 2
UtiO[y Fiwndal Solutions, LLC • of Service Summary
2. Cost of Service Summary
Utility Rate Process
Ashland retained Utility Financial Solutions to review utility rates and cost of service and make
recommendations on the appropriate course of action. This report includes results of the electric cost of
service and unbundling study and recommendations on future rate designs.
Summary of Recommendations:
Listed below is a summary of the recommendations included in this report. Detailed recommendations
are included in the recommendation section of this report.
Table 1 details the results of the cost of service study, the percentage change column indicates the
adjustment to current class revenues to meet cost of service revenue requirements.
Table 1- 2014 Projected Change
2034 20,14
Projected Cost of
Customer Class Revenues Se .vice %Chanee
Government Si ngl a Pha s e $ 152,801 $ 170,233 11.4%
Municipal Single Phase 66,385 71,836 8.2%
Gover n ment Th ree Pha s e 396,580 446,869 12.7%
Municipal Three Phase 386,367 355,256 -8.1%
Government Prima ry 818,041 926,489 13.3%
Commercial Single Phase 1,993,133 2,236,289 12.2%
Commercial Three Phase 2,259,814 2,237,137 -1.0%
Telecom 56,092 55,591 -0.9%
Residential Single Phase 6,596,584 7,482,118 13.4%
Outdoor Lighting 18,536 18,791 1.4%
Seasonal Residential 46,057 55,041 19.5%
Total $ 12,795,908 $ 14,063,469 9.9%
Utility Revenue Requirements
Forecasted expenses were based on actual FY 2011; FY 2012; FY 2013 and budgeted FY2014 adjusted for
power supply costs and inflation. Table 2 provides a summary of the financial projection based on the
following assumptions:
• System Growth Rate of 0.5% 2015-2018
• Projected power supply costs
Ashland projected adjusted operating income without rate adjustment for 2014 is a deficit of $0.74M,
and projected to decrease each year from 2014 - 2018 to minus $1.925M in 2018.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 4
Section 2
Wlity Fliundnl Solutions, LLC Cost of Service Summary
Table 2 - Financial Projection - Without Rate Adjustments
Projected Adjusted e Fiscal Rate Projected Pr
ojected Operating jeeCh ImproeYear Adjustments Revenues Expenses Income Pl2014 0.00% $ 13,390,059 $ 14,129,398 $ (739,339) $ 1,241,935 $
825,000 (9.85)
2015 0.00% 13,468,893 14,451,051 (982,158) 128,900 620,000 (19.76)
2016 0.00% 13,548,417 14,833,190 (1,284,773) (1,218,244) 570,000 (32.10)
2017 0.00% 13,628,644 15,227,017 (1,598,373) (2,944,761) 660,000 (44.96)
2018 0.00% 13,709,584 15,634,579 1,924,995 5,005,529 695,000 58.55
Recommended Target in 2014 $ 528,223
Recommended Target in 2018 $ 554,587
Recommended Minimum Target in 2014 $ 2,150,511 1.4
Recommended Minimum Target in 2018 $ 2,297,803 1.4
1) Capital investments are based on the utility's five year capital plan.
2) Cash balances include current cash and investments.
3) A number of additional assumptions were used in developing the financial projections.
Please see summary of significant assumptions for further details, section 5.
Development of Recommended Rate Track
When evaluating rates to charge customers, three factors must be considered:
1) Debt Coverage Ratio
2) Minimum Cash Reserves
3) Optimal Net Income
Each of these factors is discussed below:
1) Debt Coverage Ratio - This section provides reference for future debt issuance and how to
evaluate from a cost of service perspective. Debt coverage ratios are mandated by covenants
established in the bond ordinance and must be maintained to ensure utilities maintain their
bond rating and have the capacity to issue additional revenue bonds. Typical bond coverage
ratios require that cash generated from operations exceed 1.2 times the debt payments.
Utilities should maintain a minimum coverage ratio of 1.20 but due to fluctuations in sales,
mainly the result of weather or the economy, a safety factor is recommended to help ensure
coverage ratios requirements are met or exceeded during low sales years. A target of 1.40 is
established for financial projection purposes. This becomes the minimum target and rates
must be established to meet the debt coverage target.
Table 3 contains the projected debt coverage ratios from 2014 - 2018. Debt coverage ratios
are insufficient 2014 through 2018 without adjustment to current rates.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 5
Section 2
• • Service ❑dRty Financial5oludorts, LLC Summary
Table 3 - Current Debt Coverage Ratio - Without Rate Adjustment
Des 'iption Projected FY,14 11Projected R. P,r.jected FY,16 P,rojeated FY,17 Projected gr18
Debt Coverage Ratio
Net Income $ (733,154) $ (977,984) $ (1,285,893) $ (1,599,866) $ (1,926,217)
Add Depreciation/Amortization Expense 494,263 506,663 530,463 555,063 582,163
Add Interest Expense (2,307) (2,036) 1,764 1,493 1221
Cash Available for Debt Service 236583 469285 $ 753665 1043310 1342832
Debt Pri nci pal and Interest $ 24,021 $ 23,750 $ 23,479 $ 23,207 $ 22,936
Projected Debt Covera a Ratio Covenants 9.85 19.76 32.10 44.96 58.55
Minimum Debt Coverage Ratio 1.4 1.4 1.4 1.4 1.4
2) Minimum Cash Reserve Target - To help ensure timely completion of capital improvements
and enable the utility to meet requirements for large unexpected expenditures, a minimum
cash reserve policy should be established. Minimum cash reserves attempts to quantify the
minimum amount of cash the utility should keep in reserve, actual cash reserves may vary
substantially above the minimum and is dependent on the life cycle of assets that are
currently in service. The methodology used in this report is based on certain assumptions
related to percent of operation and maintenance, rate base, capital improvements, and debt
service. The establishment of minimum cash reserves should consider a number of factors
including:
a. Working capital lag - Timing differences between when expenses are incurred and
revenues received from customers. Establishing a minimum cash reserve helps to
ensure cash exists to pay expenses in a timely manner.
b. Investment in assets - Catastrophic events may occur that require substantial
amounts of cash reserves to replace damaged assets. Some examples of catastrophic
events include ice storms, earthquakes, wind storms, floods, or tornadoes. Many of
these catastrophic events may allow the utility to recover the cost of damages from
FEMA; however FEMA reimbursements can take between 6 months to 2 years to
recover. The utility should ensure adequate cash reserves exist to replace the assets
in a timely fashion. The minimum reserve levels are often combined with emergency
funding from banks or bonding agencies.
c. Annual debt service - Debt service payments do not occur evenly throughout the
year and often occurs at periodic times typically every six months. The utility has to
ensure adequate cash reserves exist to fund the debt service payment when the
payment is due.
d. Capital improvement program - Some capital improvements are funded through
bond issuances and some through cash reserves. The establishment of a minimum
cash reserve level helps to ensure timely replacement or construction of assets.
The minimum recommended cash reserve for Ashland in 2014 is $2.15M and increases to
$23M million in 2018. For 2014, the projected cash reserve is $1.24M and decreases to
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 6
Section 2
Service Summary
' Ulility Finondal Solutions, LLC • •
minus $5M in 2018 without an adjustment to rates. Table 4 details the current minimum
cash reserve calculation.
Table 4 - Minimum Cash Reserves - Without Rate Adjustments
Description Allocation P,rojecCedrF,Y14 (PTojec[edTY15] FP(ojec(ed FYl6 Projected FYi1.7 Projected F.Y118
Operas on& Mai Mena nce Less Depreci ati on 12% $ 651,392 $ 642,937 $ 659,011 $ 675,486 $ 692,373
Purchase Power Expense 2.7% 192,309 201,921 207,991 214,270 220,764
Historical Rate Base 3% 629,028 647,628 664,728 684,528 705,378
Current Porti on of Debt Service Reser ve 50% 11,875 11,739 11,604 11,468 11,468
Five Year Ca ital lm rovements-Net oflb d 20% 674,000 674,000 674,000 674,000 674,000
Minimum Cash Reserve Levels $ 2,158,604 $ 2,178,226 $ 2,217,334 $ 2,259,752 $ 2,303,983
Projected Cash Reserves $ 78,169 $ 1087 239 (2,482,736) $ (4,258,160) $ (6,369,056)
Notes:
• Operation and maintenance expenses exclude depreciation expense, franchise fee
and purchase power/transmission expenses.
• Rate base is historical investment in plant and equipment
• Next five years capital is annualized budgeted capital improvements for next five
years and excludes any capital improvements funded through debt issuances
Cash reserves are consistently below the minimum targets throughout the projection period
without rate adjustments.
3) Optimal operating income targets - The optimal target for setting rates is the establishment
of a target operating income to help ensure the following:
a. Funding of depreciation expense
b. Adequate rate of return on investment to help ensure current customers are paying
their fair share of the use of the infrastructure and not deferring the charge to future
generations.
As improvements are made to the system, the optimal operating income target will increase
unless annual depreciation expense is greater than yearly capital improvements. The target
established for 2014 is $528k and increases in 2018 to $554k. For 2014 - 2018 Ashland is
projected to not meet targeted operating income without any rate adjustments.
Table 5 - Optimal Operating Income Targets Compared to Projected
Descri tian ProJectetl FY14 P,roJected F,Y.15 Projetted FY36 P,rolected F,Y.3.7 Projected F,Y78
Target Operating Income
Interest on Debt $ 2,307 $ 2,036 $ 1,764 $ 1,493 $ 1,221
System Equity 525,916 534,019 537,694 545,293 553,366
Target Operating Income $ 528,223 $ 536,055 $ 539,458 $ 546,786 $ 554,587
Projected Operating Income $ 739339 $ 982158 $ 1284773 $ 1,598 73 $ 1,924995
Rate of Return in 5.9% 5.9% 5.9% 5.9% 6.0%
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 7
Section 2
Service Summary
utility Financial Solutions, LLC • •
Recommended Rate Track
The study identifies increasing revenues in 2014, and further annual thereafter to maintain debt
coverage ratios and minimum cash targets. Table 6 is a summary of the financial results detailing the
recommended revenue adjustments required to meet target operating income.
Table 6- Recommended Revenue Adjustments
Projected Adjusted Capital Debt
Fiscal Rate Projected Projected Operating Projected Cash Improvements Coverage
Y,e.ar Adjustments Revenues Expenses Income Balances Plan Ratio
2014 5.3% $ 14,068,242 $ 14,129,398 $ (61,155) $ 1,920,118 $ 825,000 18.38
2015 3.5% 14,624,418 14,451,051 173,367 1,965,999 620,000 29.04
2016 3.5% 15,202,712 14,877,055 325,657 2,238,470 570,000 36.88
2017 3.3% 15,767,380 15,313,470 453,910 2,575,429 660,000 43.96
2018 3.0% 16,315,109 15,762,046 553,063 3,005,597 695,000 50.06
Recommended Target in 2014 $ 528,223
Recommended Target in 2018 $ 554,587
Recommended Minimum Target in 2014 $ 2,150,511 1.4
Recommended Minimum Target in 2018 $ 2,301,285 1.4
Cost of Service Summary Results
A cast of service study was completed to determine the cost of providing service to each class of
customers and to assist in design of electric rates for customers. A cost of service study consists of the
following general steps:
1) Determine utility revenue requirement for test year 2014
2) Classify utility expenses into common cost pools
3) Allocate costs to customer classes based on the classes' contribution to utility expenses
4) Compare revenues received from each class to the cost of service
The cost of service summary is included as Table 7 which compares the projected cost to serve each
class with the revenue received from each class. The % change" column is the revenue adjustment
necessary to meet projected cost of service requirements. The cost of service summary uses the current
rates including any adjustment factors.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 8
Section 2
Service Summary
Utility Financial Solulioaa, LLC • •
Table 7 - Cost of Service Summary
2011 2011
Projected host of
Customer Glass Revenues Service Ghanee
Government Single Phase $ 152,801 $ 170,233 11.4%
Municipal Single Phase 66,385 71,836 8.2%
Government Three Phase 396,580 446,869 12.7%
Municipal Three Phase 386,367 355,256 -8.1%
Government Primary 818,041 926,489 13.3%
Commercial Single Phase 1,993,133 2,236,289 12.2%
Commercial Three Phase 2,259,814 2,237,137 -1.0%
Telecom 56,092 55,591 -0.9%
Residential Single Phase 6,596,584 7,482,118 13.4%
Outdoor Lighting 18,536 18,791 1.4%
Seasonal Residential 46,057 55,041 19.5%°
Tota 1 $ 12,795 908 $ 14,063,469 9.9%
Cost of Service Results
Table 8 shows the average cost of service per kWh and compares the cost to the average revenue per
kWh for each customer class.
Table 8-Average Revenue per kWh vs. Average Cost per kWh
2011 2014
01 ted Cost of
Projec
Customer Glass Revenues/,kWh Service
Government Single Phase $ 0.088 $ 0.098
Municipal Single Phase 0.086 0.093
Government Three Phase 0.079 0.089
Municipal Three Phase 0.068 0.063
Government Primary 0.072 0.082
Commercial Single Phase 0.076 0.085
Commercial Three Phase 0.070 0.070
Telecom 0.089 0.088
Residential Single Phase 0.069 0.078
Outdoor Lighting 0.095 0.096
Seasonal Residential 0.070 0.083
Cost differences result from usage patterns of customers and how efficiently each class of customer use
facilities based on load data provided by Ashland and comparable data from similar utilities.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 9
Section 2
Service Utility Pirianctal5ol • •
utions, LLC •
Distribution Rates
Separation of distribution cost helps identify distribution charges for each customer class and the fixed
monthly customer charge. Distribution rates include separation of the following costs:
• Operation and maintenance of distribution & transmission system
• Franchise fee
• Customer service
• Customer accounting
• Meter reading
• Billing
• Meter operation & maintenance
• Administrative expenses
The distribution rates consist of two components:
• Monthly customer charge to recover the costs of meter reading, billing, customer service,
and a portion of maintenance and operations of the distribution system.
• Distribution rate based on billing parameter, (kW or kWh) to recover the cost to operate and
maintain the distribution system. Table 9 identifies the cost-based distribution rates for
customer classes.
• The monthly cost of service conservation charge has been broken out to enable monthly
billing. Historically conservation has been billed within energy charge however, it is intended
to capture this cost as a monthly customer charge to provide independent support for
conservation efforts within the city.
Table 9 - Distribution Rates by Customer Class
of of Service
lmonCseice Monthly
stoitiution Billing Conseaion
Customer harge Rates Basis Charge
Government Single Phase $ (19.47 $ 10.031 kW $ 6.50
Municipal Single Phase 41.67 12.282 kW 4.84
Government Three Phase 63.86 11.267 kW 33.65
Municipal Three Phase 63.86 11.279 kW 65.95
Government Primary 285.82 8.959 kW 1,483.71
Commercial Single Phase 41.67 10.141 kW 6.34
Commercial Three Phase 63.86 8.237 kW 21.54
Telecom 9.97 0.034 kWh 2.03
Residential Single Phase 11.50 0.029 kWh 234
Seasonal Residential 11.50 0.037 kWh 3.28
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 10
Section 3
-Utl6ty Finandnl Solutions, LLC Functionalization of Costs;,
3. Functionalization of Costs
Delivery of electricity consists of many components that bring electricity from the power supply facilities
to the communities and eventually into customer facilities. The facilities consist of four major
components: transmission, distribution, customer-related services, and administration. Following are
general descriptions of each of these facilities and the sub-breakdowns within each category.
Transmission
The transmission system is comprised of four types of subsystems that operate together:
1) Backbone and inter-tie transmission facilities are the network of high voltage facilities
through which a utility's major production sources are integrated.
2) Generation set-up facilities are the
substations through which power is Terminology of Cost of service
transformed from a utility's generation
voltages to its various transmission FUNCTIONALIZATION-Cost data arranged
voltages. by functional category (e.g. power supply,
3) Sub-transmission plant consists of lower transmission distribution.
voltage facilities to transfer electric energy CLASSIFICATION" Assignment of
from convenient points on a utility's functionalizedcosts"to'cost components,
backbone system to its distribution (e.g. demand, energy and customer
system. related).
4) Radial transmission facilities are those that ALLOCATION Allocating classif ied costs,to
each
are not networked with other transmission class of service based on each class's
lines but are used to serve specific loads contribution to that specific cost
component.
directly.
DEMAND COSTS - Costs that vary.with the
Operation of the transmission system also consists of maximum or peak usage Measured in
providing certain services that ensure a stable supply kilowatts (kW)
of power. These services are typically referred to as
ENERGY COSTS" Coststhat vary oov
yeran'
ancillary services. The Federal Energy Regulatory extended period of time. Measured in
Commission (FERC) has defined six ancillary service kilowatt-hours(kWh)
charges for the use of transmission facilities. For
Ashland, these charges will be passed-through CUSTOMER COSTS'=Costs that varywrth"
charges by the control area operator. Ancillary tfienumberofcustomersonthe`system,` '
e.g. metering costs.
services consist of the following:
DIRECT ASSIGNMENT-Costs id`eniified as
• Mandatory Ancillary Service Charges: belonging to a specific customer or group
Reactive Supply and Voltage Control of customers.
Regulation and Frequency Response
Service
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 11
Section 3
Functionalization of Costs,
utility Fl..6.1 Solutions, LLC
Energy Imbalance Charges
Operating Reserves Spinning
Operating Reserves Supplemental
Reactive Power Supply
Power losses from use of transmission system
Distribution
The distribution facilities connect the customer with the transmission grid to provide the customer with
access to the electrical power that has been generated and transmitted. The distribution plant includes
substations, primary and secondary conductors, poles, and line transformers that are jointly used and in
the public right-of-way.
Substations typically separate the distribution plant from the transmission system. The substation
power transformer "steps down" the voltage to a level that is more practical to install on and under city
streets.
Distribution circuits are divided into primary and secondary voltages with the primary voltages usually
ranging between 35 kV and 4 kV and the secondary below 4 kV.
Distribution Customer Types
Sub-transmission customers are served directly from the substation feeder and bypass both the
secondary and primary distribution lines. The charges for this type of customer should reflect the cost
of the substation and not include the cost of primary or secondary line charges.
Primary customers are typically referred to as customers who have purchased, owned, and maintained
their own transformers that convert the voltage to the secondary voltage level. The rates for these
customers should reflect the cost of substations and the cost of primary distribution lines and not
include the cost of secondary line extensions.
Secondary customers have the services provided by the utilities directly into their facilities. The utility
provides the customer with the transformer and the connection on the customers' facilities.
Customer-Related Services
Certain administrative-type services are necessary to ensure customers are provided service connections
and disconnections in a timely manner and the facilities are in place to read meters and bill for customer
usages. These services typically consist of the following components:
• Customer Services - The cost of providing personnel to assist customers with questions and
dispatch personnel to connect and disconnect meters.
• Billing and Collections -The cost of billing and collections personnel, postage, and supplies.
• Meter Reading - The cost of reading customers' meters.
• Meter Operation and Maintenance -The cost of installing and maintaining customer meters.
• Portion of Distribution system based on minimum sizing (Minimum System Analysis)
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 12
Section 3
• . . • of Costs
Fun
Utility Fiw cial Solutko , 6LC
Administrative Services
These costs are sometimes referred to as overhead costs and relate to functions that cannot be directly-
attributed to any service. These costs are spread to the other services through an allocator such as
labor, expenses, or total rate base. These costs may consist of, property insurance, and wages for
management of the utility.
System Losses
As energy moves through each component of the transmission and distribution system, some of the
power is lost and cannot be sold to customers. Losses vary based on time of day and season. Typically,
as system usage increases or ambient temperature increases, the percentages of losses that occur also
increase. These losses are recovered from distribution customers through an analysis of the peak losses
that occur in the system. The average system losses and unaccounted for energy for Ashland are
approximately 3.2%. (Typical municipal system losses are approximately 5.4%)
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 13
Section 4
Utility Finindal Solutions, LLC Unbundling Process
4. Unbundling Process
.The cost of power supply, distribution, and customer services are identified as part of the unbundling
process and are the first step in determining unbundled charges to customers. The total revenue
requirements of $14.05M are separated into four categories identified in Table 10.
Table 10 - Breakdown of Ashland Cost Structure
Ez ense T, a P.ercenta e
Power Supply 50.2%
Distribution 28.8%
Conservation 4.0%
Customer Service/Central Services 17.1%
Total 100.0%
Ashland is projected to expend 50.2% of its total costs toward power supply. Distribution-related costs
are 28.8%; customer/service/central services 17.1% and conservation costs are 4.0%. These
components are broken down into each of the subcomponents and are identified in the following
sections.
Distribution Breakdown
Distribution rates consist of a number of different components. Total distribution-related costs of $4M
FY 2014 are broken down into the main components including substations, transformers and
distribution lines. -Each of these components is allocated to customer groups based on certain factors
established in the study. These factors are based on the efficiency of each customer class and the time
of day or the season the electricity is used. Other factors are also considered, such as the length of line
extensions to reach certain customer classes.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 14
Section 4
uLiHtyFieenChdSolufim%LLC Unbundling Process
Customer-Related Cost Breakdown
Ashland total expenses for customer-related costs are $2.41VI for FY 2014. The cost is broken
down into the components identified in Figure 1.
Figure 1- Breakdown of Distribution-Related Customer Costs (Without Conservation)
Dlstrtbution
51%
Bugng
z%
TraWs er
a%
Substation
Mater Reading 4%
14%
Each of these costs is broken down by customer class and the breakdown is included in the detailed
analysis of this report.
Power Supply Cost Breakdown
Table 11 identifies the average cost of providing power supply to customers of Ashland.
Table 11- Power Supply Costs by Customer Class
Billing Billing
Customer Class Demand Basis Energy Basis
Government Single Phase $ 0.7274 kW $0.0319 kWh
Municipal Single Phase 0.7921 kW 0.0319 kWh
Government Three Phase 0.8042 kW 0.0318 kWh
Municipal Three Phase 0.8084 kW 0.0320 kWh
Government Primary 0.5003 kW 0.0320 kWh
Commercial Single Phase 0.6064 kW 0.0320 kWh
Commercial Three Phase 0.5859 kW 0.0319 kWh
Telecom 0.0027 kWh 0.0320 kWh
Residential Single Phase 0.0017 kWh 0.0319 kWh
Seasonal Residential 0.0024 kWh 0.0319 kWh
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 15
Section 4
"UtilityFi...M Solutions, LLC Unbundling Process
Combined Cost Summary
Table 12 identifies the cost of service rates for each customer class. Charging these rates would directly
match the cost of providing service to customers identified in this study.
Table 12 -Total Costs by Customer Class
Cost of Service
Monthly Monthly Total COS
Customer Conservation Customer MCF-arge COS Energy
Customer Glass Charge arge Charge
Government Single Phase $ u 19.47 $ 6.50 $ - .97 $ 10.76 $ 0.0319
Munici pal Si ngle Phase 41.67 4.84 46.51 13.07 0.0319
Government Three Phase 63.86 33.65 97.51 12.07 0.0318
Municipal Three Phase 63.86 65.95 129.82 12.09 0.0320
Government Pri mart' 285.82 1,483.71 1,769.52 9.46 0.0320
Commercia 151 ngle Phase 41.67 6.34 48.0 10.75 0.0320
Commercial Three Phase 63.86 21.54 8-.41 8.82 0.0319
Telecom 9.97 2.03 12.00 - 0.0691
Residential Single Phase 11.50 2.34 13.84 - 0.0625
Seasonal Residential 11.50 3.28 14.7 - 0.0717
Table 13 shows current monthly customer charge and cost of service charge for recovery of monthly
fixed charges.
Table 13 - Monthly Customer Charge Comparison (Including Conservation)
GOS Customer Current Basic
Gustamer Glass Charge Charge
Government Single Phase $ 25.97 $ 15.12
Municipal Single Phase 46.51 56.74
Government Three Phase 97.51 98.35
Municipal Three Phase 129.82 98.35
Government Primary 1,769.52 2,315.25
Commercial Single Phase 48.01 56.74
Commercial Three Phase 85.41 98.35
Telecom 12.00 15.12
Residential Single Phase 13.84 8.45
Seasonal Residential 14.77 8.45
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 16
Section 5
Utility Financial Solutions, LLC Significant Assumptions
5. Significant Assumptions
This section outlines the procedures used to develop the cost of service and unbundling study for
Ashland and the related significant assumptions.
Forecasted Operating Expenses
Forecasted expenses were based on actual FY 2011; FY 2012; FY 2013 and budgeted FY2014 adjusted for
power supply costs and inflation. The table below is a summary of the expenses used in the analysis; the
projected operating expenses include an adjustment for any franchise fees.
Table 14 - Projected Operating Expenses for 2014- 2018
Description P, rojectedsF,Y,,14 P,rojeRed FY.15. P,rojectedlF,Y16 Projected PYr17 Projected F.Yr18
Operating Expenses
Purchases
Purchased Power $ 5,869,213 $ 6,144,268 $ 6,360,239 $ 6,583,802 $ 6,815,223
Transmission 1,170,265 1,247,052 1,297,152 1,346,006 1,393,318
Total Purchase Power ransmsission Expense 7,039,477 $ 7,391,320 7,657,391 7,929,808 8,208,541
Other Operating Expenses
Conservation 557,000 391,000 400,775 410,794 421,064
11.18 Personal Services 2,301,948 2,359,497 2,418,484 2,478,946 2,540,920
11.18 Materials and Services 2,358,917 2,417,890 2,478,337 2,540,296 2,603,803
Depreciation Expense 494,263 506,663 530,463 555,063 582,163
Franchise Fee 1,377,792 1,384,681 1,391,604 1,398,562 1,405,555
Total Other Operating Expenses $ 7,089,920 $ 7,059,731 7,219,664 7,383,662 7,553 506
Total Operating Expenses $ 14,129,398 $ 14 451051 $ 14,877,055 $ 15 313 470 15 762,046
Power supply costs from 2014 - 2018 are based on Ashland's current charges adjusted for system
growth factors and inflation.
Load Data
Load data is one of the most critical components of a cost of service study. Information from the billing
statistics were used to determine the usage patterns of each customer class. A complete breakdown of
the load data used in the analysis is included in Appendix A.
kWh Sales Forecast
The 2014 kWh sales forecast is based on FY 2012 actual sales adjusted for 1% growth.
System Loss Factors
Losses occurring from the transmission and distribution of electricity can vary from year to year
depending upon weather and system loading.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 17
Section 5
.Utility Pinincial Solutions LLC Significant Assumptions'
Revenue Forecast
The revenue forecast was based on FY 2011- FY 2013 usages adjusted for growth rate assumptions.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 18
Section 6
Recommendations'
411fly1f..1S.1utions, LLC
6. Recommendations and Additional Information
1. The study indicates rate adjustments are needed to meet debt coverage, minimum cash and
operating income targets. To ensure the utility meets financial targets and remains financially
stable, the following rate track may be considered:
Projeced Adjusted Capital Oeb[
Fisol Rate Projected Projected Operating Projectetlcash Improvements Coverage
Year Adustme nts Revenues Fxpe nses Inwme Balances Plan Ratio
2014 5.30% $14,068,242 $ 14,129,398 $ 161,1551 $ 1,920,118 $ 825,000 18.38
2015 350% 14,624,418 14,451,051 173,367 1,965,999 620,000 29.04
2016 3.50% 15,202,712 14,877,055 325,657 2,238,470 570,000 36.88
2017 3.25% 15,767,380 15,313,470 453,910 2,575,429 660,000 43.96
2018 3.00% 16,315,109 15,762,046 553,063 3,005,597 695,000 50.06
Recommended Target in 2014 $ 528,223
Recommended Target in 2018 $ 554,58]
Recommended Minimum Target in 2014 $ 2,150,511 1A
Recommended Minimum Target in 2018 $ 2,301 285 IA
2. The cost of service study identified some customer classes are paying above cost of service and
some below cost of service. The Council should consider movements toward cost of service
using a bandwidth of plus or minus 2%. Using the 5.3% rate adjustment, this would result in no
customer class given a rate increase greater than 7.3% and the lowest increase would be 3.3%.
The table below are the cost of service charges compared with the projected current revenues
for each class:
zo•ia zoaa
Projected Cost of
Customer Class _ Revenues Service % unanee
Government Si ngle Phase $ 152,801 $ 170,233 11.4%
Munici pa l Si ngle Phase 66,385 71,836 8.2%
Government Three Phase 396,580 446,869 12.7%
Municipal Three Phase 386,367 355,256 -8.1%
Government Primary 818,041 926,489 13.3%
Commercial Single Phase 1,993,133 2,236,289 12.2%
Commercial Three Phase 2,259,814 2,237,137 -1.0%
Telecom 56,092 55,591 -0.9%
Residential Single Phase 6,596,584 7,482,118 13.4%
Outdoor Lighting 18,536 18,791 1.4%
Seasonal Residential 46,057 55,041 19.5%
Total $ 12,795,908 $ 14,063,469 9.9%
3. Historically conservation has been billed within energy charge however, it is intended to capture
this cost as a monthly customer charge to provide independent support for conservation efforts
within the city. It is recommended the conservation program be funded through the fixed
monthly customer charges. The table below details monthly charges the council may consider to
adequately fund the conservation program and are included in the comparison of monthly
customer charges listed in recommendation Number Four.
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 19
Section 6
. uRUry e.a., soIuuons, ccc
Recommendations
MCh,,z,
Customer Class Government Single Phase $ 6.50
Municipal Single Phase 4.84
Government Three Phase 33.65
Municipal Three Phase 65.95
Government Primary 1,483.71
Commercial Single Phase 6.34
Commercial Three Phase 21.54
Telecom 2.03
Residential Single Phase 2.34
Seasonal Residential 3.28
4. The Council may consider movements in the customer charges to move toward cost of service
based customer charges and to adequately fund the conservation program on a consistent basis:
The table below compares the total cost of service monthly customer charges including
conservation with the current basic charges. (The council may consider renaming the fixed
monthly charge from Basic Charge to Customer Charge)
COS COS Current
COS Basic Conservation Customer Basic
Customer Class Charge Charge Charge Charge
Government Single Phase $ 19.47 $ 6.50 $ 25.97 $ 15.12
Municipal Single Phase 41.67 4.84 46.51 56.74
Government Three Phase 63.86 33.65 97.51 98.35
Municipal Three Phase 63.86 65.95 129.82 98.35
Government Primary 285.82 1,483.71 1,769.52 2,315.25
Commercial Single Phase 41.67 6.34 48.01 56.74
Commercial Three Phase 63.86 21.54 85.41 98.35
Telecom 9.97 2.03 12.00 15.12
Residential Single Phase 11.50 2.34 13.84 8.45
Seasonal Residential 11.50 3.28 14.77 8.45
5. The City of Forrest Grove is considering the installation of an Automatic Meter Reading
Infrastructure to obtain hourly usage readings from customers and offer Time of Use rates at a
future date. Time of Use rates are developed to send customers an appropriate price signal that
reflect a utilities costs during certain times of the day. Time of Use rates are often established to
reflect time periods where the costs change significantly and often includes an on peak; off peak
and critical peak time periods and often the rates will vary by season. The Bonneville Power
Administration has implemented changes that over time may adversely impact customer's power
supply rates if usage is not maintained below certain levels during the High Load Hours. Prior to
implementation of Time of Use rates a history of approximately 6 months to 12 months of time
dependent (hourly) meter reads is recommended to help ensure the accuracy of the rates
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 20
Section 6
Recommendations
' Utllity Finandal Solutions, LLC
developed to help ensure the proper revenue requirements of the utility are consistently
realized.
Prior to offering Time of Use rates and development of an AMI system the City should consider
the direct and indirect benefits and develop a framework to assist in understanding, identifying,
and calculating AMI benefits. Following are a sample of items the City may consider prior to
implementation of an AMI system:
• Utility departments affected
• Benefits to operations, customers and potential reductions in power supply costs
• What amounts of measurable savings the City will receive including avoided future costs
and customer-related enhancements
• What indirect benefits might be realized
• What information the AMI system is required to provide to fully realize the benefits of an
AMI implementation
• What software and information systems are required to realize the identified benefits
City of Ashland Electric Department
Cost of Service & Electric Unbundling Study Page 21
Utility FinancialSolutions
185 Sun Meadow Ct.
Holland, MI 49424
Phone: 616-393-9722
Fax: 616-393-9721
Accountant's Compilation Report
City Council
City Administrator
City of Ashland Electric Department
The accompanying forecasted statements of revenues and expenses of the City of Ashland Electric
Department (Ashland) were compiled for the year ending June, 2014 in accordance with guidelines
established by the American Institute of Certified Public Accountants.
The purpose of this report is to assist management in forecasting revenue requirements and
determining the cost to service each customer class. This report should not be used for any other
purpose.
A compilation is limited to presenting, in the form of a forecast; information represented by
management and does not include evaluation of support for any assumptions used in projecting revenue
requirements. We have not audited the forecast and, accordingly, do not express an opinion or any
other form of assurance on the statements or assumptions accompanying this report.
Differences between forecasted and actual results will occur since some assumptions may not
materialize and events and circumstances may occur that were not anticipated. Some of these variations
may be material. Utility Financial Solutions has no responsibility to update this report after the date of
this report.
This report is intended for information and use by the City Council and management for the purposes
stated above. This report is not intended to be used by anyone except the specified parties.
UTILITY FINANCIAL SOLUTIONS
Mark Beauchamp, CPA, CMA, MBA
Holland, MI
October 2013
Appendix A - Billing and Load Data
This appendix provides details of load and billing data provided by Ashland. This data forms the basis for
Appendix B and Appendix C thus its accuracy is critical for determining appropriate allocator for
allocating costs to individual classes. The revenue reconciliation provides a reference to booked
numbers and those calculated using the rates from the load data time period.
ro
ro
a =."'s spa 'S"a "a e. 65 c°a ~ ! ^!^a;m55„ ^s"s ^8
g ~^R6^" 5 ~^a z
1' ~~~a,q~:"sm 3E $ 1 1~ ~"s.msvs ~s sa^ s a
°o"a a
•I ^~RA~°'3Mr° A~ 8 ~ .I ^aatl,Ra~B 58 65a 8
.I ~ampaasx:5 x.~ aP e ~ MI ^sa a:ae =58 a s
le:~~~ml~ •T oo . ~ I~ I:~ i .I :m m o
'35:$s~~5 x5 s5 s YI ^amn a 11 555 s
m °
:m oe m e
~sa:5P5~aP x5 a;. a ~ MI ^A ^BRe~G&^ ~8 655 a s
o
°~5a.p:'s~p 1 s ^ss5a.„say
aa a a
II ee5.a~.5:F$ 5 sa a ~ II 4.s5 $8 $55 s a
-~J.s:ama x5 a 1 s.°"se a g~ $a5 e 5
I' PI• 15 oo m ~ ii la^'„ I :m oe
.,I •Rm:~s xp a^ a s x.a~° a: ga o5o a ~
I ^$EaS~r$^° sm a ' gm°gm -„NS ~5 ~x5 e
i~ =Tai 1= .m oo ~ ° ~i I:_ ~ I :m aoe m
I °~op :W~.^ X~ 3a 8 B I ^aae '3n ~YB $8 ~&0 8 3
^I °a5s 5a^: ;5 5s a e ^sta: :s g xa: a a
5 as
it I I^ it ~g IN
EE
se 3g s 3~a 33 kE i~€ 3a fE~~
s
~ s s - 3 E x
EEa ~pp t~ p3p ap3p a
~ 30 ~ 3~ 3 3 Y 3S 34 ~
y A pC SpC y tltl ~ SN
`V E.s FFE EE _ s~ FF Ed ~ a~A FFF EE ~a aFE ~E `
n~ ems a€ WW ° a ~a~ ad wWw °x
Oc` f
°a
x=
sa
by
s~
eaxsxs: Rm "s $s :a~?c"aaa~R a$ a$$ R m
$tlmwm - h s3$a:^~a °:a: -a„~ pan z
'I
ooa ma o°o a gg
I jj^ 1`11111 e$ Aga es 3i°s e$ ~Ba 5~
~ IN ~I I P it "I"im °
.I m.^,aSmTe n3be 88 9' C,m .3 S^P r8 •j '~iR 8.
II ".~m,_' ,I I8"s ]TI 1a-$§ R;ia as $^a" ^aa flfiRn;
eee o ma° " o.
I Y-1,
"m3aRA„r rv.$ agG s -~eNr 0~ m"g 88e 68 ~„aka 8a9
:RRm °oo°o mmm$" a°a og°= ge8
~~~"-I o00 .a RI •I"w"I I o°° R~ ai"~" w o
XR, 86 ^aCA° -~s~^^
~s tae „6 I' ^s^ ^ a$ $^a mk I' n.a: $ s~.
II .10.3 ^ ^ II ~ ^ II ~ I
"~~~^a nsOe .8 °aso m~ m! as^'"s "a
~ a~x~ $ a ma° °o ~ sa°" o•N
.I "&80°2 X82 9B .1 -x3R~a6 382
I~~j -i o°n a ;I I~~R~ I gg gg II -d_i ~ oggo
a' 92oA2e~"7 n3 ~Be 88 aI mmmr^~ 83 38e m8 .I ~aP~ 8ga
o'
it ~N ^I ~ it ^I_PI it
EE
E€ EE 3 EE FFEE E E
3~ 333 33 , 33 333 33 6~ ««3 , e 3 3 3 «
E W g L C ~ E y g
b s 3 ~ 3 ~ ~
y~ _ S
ea 3 a2 2 a3 i i ;
3 3~a 3 o ~ 3 3O" ~ P « $
5 `s s, .32 s'~i a s'3 .`3$ ~3 tl
YF 38S iW 3-~ :c 3$L :W ~L° ~t
_`.F ~F a; s` o$ k&a Fi && mm i` "s ie" Lk 3' ? ` a=~
<9 F$a FFF E€ 3a zFF EEg aka FFF EE a FzF EE4 Ea s ` 3 Fob
o dad ad www o Fad ad Www °oa rs ° .as
e33 a nY3a3:a*3i xa &33.3 ! !!a_ _ _ LL
! 3~a3~aa~::•s Is
y am~^mmR m 3
3: s "G3."^. sas ^ia xx_ &a
I!"I~
11 a"sa33n sas 11 °cFmma3°¢ as "s_ es tl Ra3..9 2"s9
8Ma' C 3o~'T ea a.'n
s 3=~^ ooo 3. a aa!ff as =
aaa3s ,m3 °I m.a3°°-c3g la e~ RS "I Ra• sgg.
li " ~ a ~ ggg P ii $ oa m~ II I ooo_
.I 3:$ ~ las,al .I si^aaa i~~ s~ ssa'Ra .I s ggg
as s li ~e•s ?.'""i ~s ee ii ~I^ oea
ooo
Ias 1. 1
xya~3ss„m„y xP 13g.1 °I sssas's: ool'Rn I s a ooo
a ^"5^ ooo
,I ssmaaa'sa~M sa Iax.ml
°I saa3~a_se as 3sl 3s "I ^a:.$ gag
a3am«" ESE ^ 3 a m$ eo ooo
°a
~I I i" I II
&a!'~e^"as~a g3x,a. I ae~:° est "a:a"I gn II
oslas •I ""3.9s.gg
R •e~'a_^^ oao A a" aa~r:n m$ eee oea_
- - - - - - - - - - - -
II 3a~a^3s "asa sa a3N•ml II sa^"3°'^R-g $ sgl•x~ II - _ gill
«3m^^^ as ME •a .3s~"' as as m';; •a .a ooo
^i 8898:B.G 3r.•^. P S~3'm I ri»m°~o~ d
N .6 Rr I ."i 'aC a
R" !as&^m oaa R~ •Sx.::e .3 ^3 R ~~bm
^I $a xa:,^3:e m ass 3 ' .-M a 58 ss" ss • ^W
aoo
,I 336s9a°aaas ^ I^„.ml ^I n1mc®€3 3 81 os3 Rm al Sill
e o.
oao=
x88 G « M e :
•I asa3aa?3 sa aas ml •I an~asgla3'~ # as$.sc ^I .Q sgge
~e•• g33 aoo
° R 3F~' Rs ^'0
al $a~&33a:3~ g33,:s •I aaeass~exq 33 331.Ra JI a .c gill
88 °3r 63 °oa T'y
it ~l^•~ - it I~ it ~
I I I_
dd 333 33 »~»~t~ dd 333 33 ~r
E ~ g
E d 3 "s ~
s &i a _ = a3 i sY
'z3¢a $ar ~xa€3P g $al
E a y ~€2rWn a sl ^~2san a m~~n
M. M
=x "3 d~O <e Y3 pmmg X33 oox FY :3 898. € X8 2 o K%%°
73 E$R EFF iE 3a FFFE i ets stF ii 3s F€Fo i4 FFF =FF
o 8&~ a~ W•woa~ ao w•w sd E ww
i,
B c$ma B as^~ ^x 1° # 5 m^y z
I li .I„a'
i _I ' li laal If
$~$r as
T
il 1 xPmo $ i~gipl 1 " r❑ m° as
TI ~$~?R gg gg ::as ~gg a-~$.@ppa "o"s B a~a
a." ~g o6ce S" s a"A : 6°g aRa" R$ 9 e6°
it I ~I pl` i o it "In it "I
ss as sax" sa~Bx
c^ as a n n° a
ii I Ani n 6606 ii I` R ~i I^
' 8~s~ aa~ e~g° xx^Pa ~ d6s xx a_ ~~$~~8~ el $ has
a_ "x^^ R3 oa°°_ ^SABa 6cY .R: _Ra^ a : aae
RI ~ I ° sl I i ~ `I I Qpp p =I "I^ml
II ggga II 4.2P~' ~$m II x^ M"bb• I~ "$sa I og8
m ~Rq- : eee
I
a a~~ as^^ x^ $ -
~'@: of ^"s eB$ _In .I 's $e og§
o"
.I @@$ sa x^xn ssax~ gR .I xxx^ sa Jim
S8 ooa~
xx 88 xax° xa x^ xa 8 a
Bs ose$ ae~
as ^Ma xS'_°^ xa 8 xs^^8
s s
I ii 3 55 19 a ~ 9 E EEEQ iEv iiip I a 33 O 55
3.~ " 3~SS a :3 3 »»SSSSSS 3 a
_ ~ 9 w 9 p w
_ _ h a a
_ s
5
g" 8 cu ~y oc ~~3e 3 ~dE ~ i ~ d $se
ee 'r €$W5 a €Wx - .aa3a;a i €W#
~o s e gf'_x oe EP'_x° HOC 5x E En° ?E .fir'"zr :raa rr: oo E
=s EE 'i x:s3 ,°~x a`;. GE E Ys"
a QY~ F€F FE@ ~e Ez @ €E~ $a ~~~=9~~e :a EE a EPF
VG _Ed o~ WW - a3 z s5 axW~a~B axW""x. 5- - .W3
c 8 s`
<s
Appendix B - Historical Load Data
This Appendix is based on the data derived from Appendix A and functionalizes data into time period for
cost allocations.
Chy of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -n 2014
d Plate Wind] Histem,
Govemms. Si ¢Phas¢
Customer Type Ginernment5inde Phase
Customer Load Profile Type Government Single Phase
Distribution Billing Parameter kW
Total Winter Summv mter2 b.14
Customers 85 BE 115 85
Load Factor - Group 32°% 21% 28% 201
Group Losses:
Seemcary 2.09% 20% z.o% z.
Primary 1.0% 17796 1.0% 1.0
Substation 0.296 D2% 0.2% 0.2
Individual NCP 687 7D3 656 688
Group Comintern Factor 90% 90% sox -
NCPMeterfarGroup 618 630 590 619
System Cpu<Idence Factor 95% 90% 90% 9
BII ling StnNdR (Yea r End 6 2014)
Actual Demand 2,746 1,401 1,311 2,753
Energy at Meter 1,62,6% 631,807 215,177 2%072 527,640
Revenue' $ 147,857
Con Per kvm rear End 620141 $ 0.0900
Usage Profile - NCP
Average Monthly kWh per Customer 1,853 1,251 1,585 1,547
NCP M Primary for Group 643 630 643 602 632
NonCoinridence Peak at Input for Group 651 630 651 609 640
Ult;mrte Peak Usage Per Cmtomv 7,6 7.48 7.57 zn 7.50
Lee, Prpfle - m
Coincident Peak at Input Voltage 605 586 548 5%
Diversified CP per Customer-kW 7.11 6.81 6.49 698
System lenses
kWhatlnpm Voltage 1,696,113 652,352 222,174 276,789 544,798
Average Group tosses 3.3% 3.3% 3.3% 3.3% 3.3%
kWh M Input by tome Period
Df-Peak Erins, 84$056 326,176 111,087 138,395 272,399
On-Peak Enerry 848,056 326,176 111,087 138,395 273,399
SMulder-P A Energy
[Test kWh UU a 1,696.113 552,352 222,174 276,789 SH790
Municipal Sile Phan
Customer Type Municipal Single Nase
Customer Lead Profile Type MYRIUpal Single Phase
Distribution Bllling Parameter kW
7.1 Winter Summer mter.2 Inter-4
Customers up So 49 50
Load Factor - Group 70% 643, 75% s
Group wines:
Secondary 2.0% z.0% 2.0% 2.
Primary 1.0% 1.0% 1.0% 1.
Substation 0.2% 0,2% 0.2% 0.
individual NCP 150 100 102 135
Group Concident Factor 100% 107% 107% IOGN
NCP Meter I., Group 150 103, 102 135
System Confidence FMOr 95% 90% 9^ 93%
BIIIhq Statlnl¢ (Year End 62014)
Actual Demand 6N 193 203 538
Energy rt Meter 738,681 305,507 94,323 103,282 228,569
Revenue $ 65,049
Con Per kWh (Year End 62014) $ 0.0801
Usage faults - NO,
Average Monthly kWh per Customer 1,525 943 1,127 1,154
NCP at Primary for Group 153 153 101 104 137
Nonfnlodence Peak at Input for Group 155 155 Do 105 139
Estimate Peak Usage Par Customer 3.1 308 2,05 2.16 2.81
Usage Profile-v
Coincident Peak at Input Voltage 147 92 94 129
DiversffiM CP per Customer ANY 2.93 1.85 194 2.61
System tonnes
kvm at Input Voltage 762701 316,474 97,390 112836 236,002
Average Group Losses 33% 3.3% 33% 3.3% 3.3%
kM at Input by thirty Pardiss!
Off Peak Energy 381,351 158,237 48,695 56,418 118,001
Om Peak Energy 381,351 158,237 48,695 56,418 118,001
Shoulder-Peak Energy
melkWb Ua a 762,701 316,474 97390 112,815 236002
AppelMia B Prepared by:
Historical Load Data B-1 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Servlce and Unbundling Study -Ty 2014
Customer Load Profile Dow" Iffiland,
Govemmem,Thiro PNS¢
Cuammer Type Government Three Phase
Customer lead Profile Type Government Three Phase
Distribution Billing Parameter kW
Total Winter Summer Inter2 Inter4
Customers 42 43 43 43
Lead Factor - Group 3]% 29% 306 31%
Group Losses:
Secondary 20% 2.F96 1%6 2.
Primary L17% 1 m6 1.0% 1.
Substation 0.2% 0.2% (12% ON
Individual NCP 1,636 1,547 1,]1] 1,687
Group Coincident Factor 1006 106% 106% 1
NCP Meter for Group 1,636 1,547 1,]1] 1,687
System Coincidence Fission 95% 90% 906 93BI
Billl4lg Statistics (Year End 62014)
Jonual OemaM 8,542 3,093 3,433 6,]46
Energy M Meter 4,841,219 1,730,431 658,201 899,684 1,54,903
Revenue $ 382,765
Cost per kWh( Year End 62014) $ Bowl
Usage Profile-NP
Average MmWy kWn per Customer 10,348 7,654 lo,mi 9,080
NCprt Primary for Group 1,751 1,6GB I,5]2 1,751 1,720
Non Comiarre Peak at Input for Group 1,772 1,689 1,597 1,222 1,741
Estimate Peak Usage per Customer 413 4031 37.13 41.22 40.92
Usage Profile - P
Coinatlent Peak at Input VOll 1,604 1,437 1,5% 1,619
Dlversifetl Pper Cusinmer-kW 38.20 3342 37.03 38.10
system added,
kWh at Input Voltage 4,998,646 1,294,961 61 920,940 1,595,140
Average Group Lases 3.3% 3.3% 3.3% 3.3% 33
kWh at Input by Time Period
OX-Peak Energy 2,493,322 fall 339,802 464,470 ]9],570
On-peak Energy 2,493,322 09],480 339,802 464420 ]97,570
Shoultler-Peak Energy
malkWhU 4,998,644 1]91%1 679,604 91 1595,140
Munltl l."reeplae
Customer Type Municipal Three Phase
Customer Load Profile Type Muniaaal Three Phase
DIZVIbution Nor, Parameter Wr
Taal Winter summer late 2 Imes
Customers 21 22 21 21
two Fission - Group 61% 54% 70k 6
Group Losses:
Secondary 2.M 2,0% 2.0% 2.0%
Primary 10% 1.0% 1.066 1.0fit
Substation 01 02% ON o.
InNM 111 982 1,046 990 1,016
Group Cdnaidem rage I" 106% 106% 1
Ni Meter for Group 902 1,006 990 1,016
System Comadentt Factor 95% 90% 90% 9
III SaudisUe (year End 6206)
usual Demand 3.927 2,091 1,906 4,063
Energy, at Meter 5,425,293 1,]48,423 04,5]6 991 1,WM
Revenue $ 378,237
Cost per kWh (Year End 6 M14) $ 0.0697
Usage Profile - NP
Average Monthly kWh per Customer 20,815 19,641 23,625 21,905
NCP at Primary for Group 1,006 1,063 1,066 1,010 1,036
NDnldrcideme Peak at Input for Group 1,029 1,014 1,079 1,022 1,049
Estimate Peak Usage Per Customer S012 4fl27 50.21 48.68 49.94
Uup Profile -P
Coincident Peak at Input Vohage 963 972 920 975
Diversified CP Per Customer-kW 45,85 4519 4183 4645
System Loses
kWh at Input VOha, 5,601,]11 1,80,2]8 872,040 1,024499 1,8%,894
Average Group Lases 3.3% 3.3% 33% 33% 3.3%
kWh at Input by Thome PMOd
Off Peak Energy 2,800,855 902,639 436,020 512,250 949,94]
Opi Energy 2,800,855 902,639 436,020 512,250 949,947
Shoulder-Pe S Energy
aslkWh Ura a 5,601,]11 10952]8 872,040 1.024493 189abal
Appendix B Prepared by:
Historical Load Data B-2 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -TY 2014
Customer Land ProflN Mail Hl4ork
Gav¢mmen[Se[anda
Customer Type Government Secondary
Customer Wad Profile Type Government Secondary
Distribution Billing Parameter kW
Total Winter Summer Inter-2 Im.rA
Customers 2 2 2 2
Loaafactor-Group 35% 31% 2954 3
Group tosses:
Secondary 2.D% 2.0% 2.056 2.
Primary 1.0% LO% 1.0% 30
Substation 0.2% D.21g 0.2% 0,2%
Individual NO 2,148 2,469 2,772 2,209
Group Cn'mdnrt Factor 75% 75% 75% 75
NCP Meter for Group 1,611 1,851 2,002 1,656
system Cdnddena Factor 75% 75% 75% 75%
stiff, Statistics (Year End 62014)
Actual Demand 8,591 4,935 5,553 8,834
Energy at Meter 6,436,880 2,203,200 1,14o,o9D 1,149,600 1,9"'M
Revenue $ 451,202
Cost Per kWh (Year End 62014) $ 0.0701
Usage Profile - NO
Average Monthly kWh Per Customer 275,400 285,000 287,400 243,000
NCP9 Primary for Group 2,124 1,643 1,88 2,124 1,683
Non{oinddence Peak at lnputfor Group 2,150 1,663 1,911 2,150 1,710
Estimate Pek Usage per Customer 1,075.0 83160 95540 1,07S04 855.12
Usage Profile - CP
Coinadent Peak at Input VOOage 1,247 1,433 1,613 1,283
Oiversifel CP per CustomerkW 6B,70 71655 806.28 641.34
S,bon Losses
kWh at Input Voltage 6,6W,110 2,274,843 1,m,070 1,185,982 2,007,214
Average Group Losses 3.3% 3.3% 3.3% 3.3% 3.3
kWb at Input by Tlme Bell
OFF Peak Energy 3,323,055 1,137,421 588,535 593,491 1,003,607
On-Peak Energy 3,323,455 1,137,421 589,535 593,491 1,003,607
Sibenim r-Peak Energy
Total M Usage 6,646,110 2274843 1,177,80 1,100,982 2,007,214
GowrnmentG50
Cozwmer Type Government G50
Customer Lead Profile Type Government G50
Distribution Billing Parameter kWh
Total Winter Summer Inter -2 Iirl
oastome
wad Factor - Group ox D% D%
Group Losuz:
secondary, 3096 2.^ 2.0% 2.036
Primary L o% 1.056 1.0% IN
5u1hstMian 0.2% 0.2% 0.2% 0.2%
Individual NCP - - - -
Group Consul Factor 100% 1001' 10096 1
NCP Meter for Group - - - - -
SystemCdrcldence Factor 95% 90'M %Eg 9
Billing Statistics (Yea r End 62014)
Actual Demand - - -
Energy at Meter 4,449,600 1,358,400 5",000 823,200 1,704,000
Revenue $ 210,833
Cost per kWh (Year End 62014) $ 0.0474
Usage Profile -NO
Avenge Monthly kWh per Customer - - - -
NCPat Primary for Group - - - -
Nor{olnddencs Peak st Input for Group - - - - -
Estimate Peak Usage Per Customer
Usage Profile a
Cdnddent Peak at ltpW Voltage - - - -
DMrslfiedOn per customer AW - - - -
System Lauer
kWh at Input VOkage 4,594,291 1,402,572 582,340 849,969 1,759,410
Average Group Losses 3.3% 3.3% 3.3% 33% 33%
kWh at Input by Time Period
OffPeak Energy 2,297,145 701,286 291,170 424,985 Rl
On Peak Energy 2,297,145 701,286 291,170 424,984 879,705
Slwulder-Peak Energy
Total kwb UU a 4,594,291 1,402,572 582,340 849,969 1,759,410
Appendix 8 Prepared by:
Historical Wad Data B-3 Utility Financial Solutions, LLC
City of Ashland, Eleatic Department
Electric Cost of Service and Unbundling Study - TV 2014
Cysmmer Lead Profile asset Months
Commmam Sin lepbase
Customer Type Commercial Single Phase
Customer Load Profile Type Commercial Single Phase
Distribution Billing Parameter kW
TWI Winter Summer Inter-2 Inter-0
Customers 1,141 1,1]2 1,122 1,12]
Load LectorGroup 5ms sees 5673
Group lasses:
SewMarY 2.0% 30% 30% 2.
Primary 1.0% 10% 10% 1.
Substation 0.2% 02% 0.2% 0.2%
Ind ,dual NCP 5,672 6,79] 5,591 5,531
Group Coincident Fatter ]UM 85% 70% >
NCP Meter for Group 3,970 5,]2] 3,913 3,872
System Coincidence Factor 95% 906 90M 9
Billing StauII16(Year End 62014)
Actual Demand 22,68] 13,593 11,181 2;124
Energy at Meter 25,05,9]1 8,188,9]5 4,849,186 4,541,942 ],4]5,869
Revenue IS 1,924,266
Cast per M(Year End 62014) $ 00768
Usage Profile-Nd
Average Monthly kM per Customer 1,795 2,069 2,025 1,658
NCP at Primary for Group 5,892 4,049 5,892 3,991 3,949
Non-Coincidence Peak at Input for Group 5,965 4,099 5,965 4,041 3,998
Estimate Peak Usage per Customer 51 3.59 5.09 3.60 3,55
Units profile-m
Cdnadent Peak at Input Voltage 3,894 5,368 3,637 3,718
Diversifies CPper Customer-kW 341 450 324 3,30
system Lasses
kWh at input voltage 25,870,733 8,455,261 5,006,87D 4,689,635 ],]18,966
Average Group Losses 33% 33% 13% 33% 33%
gets at Input by Time Period
Off Peak Energy 12,935,366 4,22],631 2,503,435 2,344,818 3,859,483
On Peak Energy 12,935,366 4,222,631 2,503,435 3344,818 3,859,483
SMuldec-Peak Encrgy
otelkWhU 25,820,]33 0,455,261 5,006,8]0 4,689,635 7,718,966
COmmerelaijime¢ Phase
Csum-rType Commercial Thee PhasCustomer Load Profile Type Commercal Twee Phase
Distribution 111fo, Parameter kW
Total Winter Summer Inter-2 Inter4
Customers 381 350 398 393
Used Factor - Group 45% 43% 48M 4
Group Losses:
Secondary 2.06 2.M 2.0% 2.
Primary 1.M 1RM 1.G% 1.
Substation 02% 0,N 0,;r`6 On
individual NCP ],]49 7,092 8,545 8,178
Group Coincident Factor ]04 85% ]O% 70%
NCP Meter for Group 5,424 6,028 5,982 5,724
System Coincidence Festoon 95% 90% 90% 9
&3u, ne lrtta (Tort. 6294)
Actual Demand 30,937 14,184 17,030 32,7]0
Energyrt Meter 30,526,533 10,053,134 4,40,70 5,892,238 10,061,3]6
Revenue $ 2,189,412
Cost per kWh (Year End 62014) $ 0.0717
Usage Profile - NCP
Average Months, kWh per Customer 6,601 6,428 7,412 GIN
NCP9 Primary for Group 6,148 5,532 6,148 6,100 5,838
rl. Comaderce Peak As Input for Group 6,224 5,E01 6,224 6,176 5,910
Estimate Peak Usage Per Customer 17.8 14.71 1]]8 15.54 15.03
Usage Profile -a
Coincident Peak at Input Voltage 5,321 5,02 5,558 5,497
DlversHl H (P Per Customer AW 13.97 16.01 13.98 13.98
System trues
kWh at Input Voltage 31,519,185 10,3,030 4,646,108 6,083,840 10,409,199
Average Group Losses 3.3% 33% 33% 3.3% 3.3%
kWh at Input by Time Pea.
ON-Peak Energy 15,759,592 5,190019 2,323,054 3,041,920 5,204,599
On Peak Energy 15,759,592 5,190,019 332$054 3,041,920 5,204,593
Sbaulder-Peak Energy
Mai kind USa ¢ 31,519,185 11),380,08 4,646,106 6,083,806 10,409,199
Appe.ia B prepared by:
Historical Load Data B-4 Utility Firumial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -Ty 2014
customer Wad Profile Oerall Hinarla
Commercal Conrtruttipn
Customer Type Commercial Construction
Customer Load Profile Type Commercial Construction
Distribution&IWg Parameter kWh
Total Winter Summer mli,12 kdero
Conomers 13 22 is 16
load Factor Group SO% SDI Sort 5
Group losses:
Secondary 2.05k 2.0% 2.0% lD%
Primary 1.0% 1.0% 1.0% ]O's
Substation D.2% 0.2% 0.2% 0.2%
Individual NCP 15 5 10 8
Group CUmdem Fatter 76% ]O% ]OM ]
NCP Meter for Group 11 4 ] s
System Coincidence F.., 75% 75% 75% 75%
01111% Statistics (Year End 62014)
Actual Demand - - - -
Emr,atWier 44,86] 22,494 3,]01 ],135 11,49
Revenue $ 5,430
Cost per kWh (Year End 62014) $ 0.121D
usage Praia - POP
Average Monthly kWh per Customer 433 86 198 in
NCP at Primary for Group 11 11 4 ] 6
Ncnt nridenm Peak at Input for Group 11 11 4 ] 6
Estimate Peak these per Customer 09 0% 0.17 040 0,35
Usage Profile - Cle
Coinddent Peak at Input Voltage 0 3 5 4
Diversified CPper Customer-kW 0,65 0.13 0.30 0.27
System Losses
kWh at Input Voltage 46,326 23,225 3,904 ],36] 11,x30
Avenge Group Losses 33% 33% 33% 13% 3.3
kWh at Input by Time parsed
ON-Peak Energy 23,163 11,613 1,952 3,681 5,915
On-Peak Energy 23,163 11,613 1,952 3,684 5,915
5l
,mM PUYeakaEnergy
TobkWh 45,326 23,225 3,904 ],36] 11,830
TNero
Customer Type Telecom
Customer Load Profile Type Telecom
Distribution ailing Parameter kWh
foul Winter Summer Inter2 Inte-A
Customers 2 2 2 2
load FMor - Group 45% 45% 45% 45%
Group Losses:
Secondary 2.0% 2016 3014 2.
Primary 1.0% 1.0% 1.014 1.
Substation 03% 03% 0.2% 0.2%
Individual NCP 157 47 103 128
Group COiMdenl Factor 10]96 1W96 100% IDON
NCP Mttet for Group 157 47 103 128
System Continence, Factor lank lank 10036 1
Built, Statistics (Year End 621114)
Actual Demand - - - -
End,,0Meter 4]1,084 20,600 31,342 66,821 169,121
Revenue $ 44,37
Coat per kWh (Year End 62014) $ 0.039
Usage Profile-NOP
Average Mardis kWh per Customer 25,575 7,836 16,705 21,14o
NCP m Primary for Group la la 48 105 131
Non-Coindden a Peak at Input for Group 162 162 48 la 133
Estimate Peak Usage per Customer 8n.8 8083 24.16 53,24 66.26
Usage Profile-CP
Coincident Peak at Input Voltage 162 48 HIS 133
OiKndned CP Par Customer kW 00.03 24.16 53.24 66.26
System Losses
kWh at Input Voltage 47,229 211,253 32,361 68,994 1]4,620
Average Group losses 33% 3.3% 3.3% 3.3% 3.3%
kWh at input by Time Period
OH-Peak Energy 243,614 105,62] 15,181 3,47 8],310
On Peak Energy 243,614 105,62] 16,181 34,49] 8],310
Shoulder-Peak Energy
TOaeI kWh Use, 40],229 211,253 32,361 68,934 1]4,620
Appendix B Prepared by:
Historical Load Data B-5 Utility Financial Solarium, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -TY 2014
n.a0mar -.end Mistake
ResldenualSingle Phase
Customer Type Residential Single Phase
Customer load Profile Type Residential Single Phase
OisMdNOn&IHM Parameter kWh
Total Winter Summer inter -2 Inter-4
Customers 10,136 10,281 10,2]0 10,161
fwd Factor - Group 43% 5Y 52% 43%
Group Losses:
Seemel., 2.016 20% 2G% 2.
Primary LM 1.0% 1006 1.
Substation O. AZ A^ 0.
individual NCP 30,874 14,786 17,651 21,995
Group Coincident Factor 7Ol6 85% ]O% 70%
MCP Meter for Group 21,612 12,568 12,355 15,396
System Coincidence factor 85% 9]% 9TM BT.6
Mill, Statlstb (Your End 620,1)
Actual Demand - - - -
Energy at shelter 9o,N1,640 38,552,496 11,410,429 13,216,]22 2],691,993
Revenue $ 6,405,056
Cost per kWh (Year End 6201) $ 0.0705
Usage Profile-Non
Average MmWg kWh per Customer 951 5% 643 681
PICA at Primary, for Group 22,040 22,040 12,817 12,601 15,702
Non{dncideMe Peak M Input for Group 22,314 22,314 12,976 12,157 15,837
Estimate Peak Jane per Customer 23 2.20 1.26 134 1.56
Usage Profile -m
CoNddent Peak at Input Voltage 18,961 12,581 12,324 13,830
NeersBied CP per Customer AW 1.81 1.22 130 1.36
System Losses
kWh at Input Voltage 93,85],549 39,996,133 11,812,445 13,W6,499 28,592,4]2
Average Group Losses 3.3% 3.3% 3.3% 3.3% 33
kWh at Input it, Time Pblod
Of Peak Energy 46,928,1]5 19,993,06] 5,906,223 6,8]3,249 14,296,236
On-Peak Energy 46,928.15 19,903,051 5,986,223 6,823,249 14,296,236
SMul4rpeak Energy
Tp[alkWh UU a 9385]549 39,806,133 11,812,445 13,06499 28,5924]2
Good ugnnn
Customer Type Undoes 11'rim g
Customer Load Profile Type outdoor ughOry
Distribution BllllnB Parameter kWh
Taal Winter Summer Inter-2 Interd
Customers 59 58 59 61
Land F.-Group 45% 45% 45% 45%
Group losYS:
Secondary 2G% 10% 2,056 2.
Primary 10% I'M 1,0% in
Substation 0.2% 03% 0.2% ON
Individual NCP 55 37 43 49
Group C'rcident Factor 300% IDEM6 Dark; lung
NCP Meter for Group 55 31 43 49
System CtAmeeme canny 0% 0% 0%
6nrng5unsMes (Year End 62934)
Actual Demand - - - -
Energy atMeter 189,000 ]1,262 24,]8] 27,885 65,066
Revenue $ 18,536
Cost per kWh (Year EM 62014) $ 0.0381
Usap Profile Non
Average Monthly kWh Per Customer 301 214 238 269
NCP M Primary for Group 56 56 38 44 50
Nan-Coindhnce Peak at Input for Group 56 56 38 44 51
Estimate Peak usage Per Customer 10 0 95 0.66 0.76 ON
Usage P.M. - Op
Coincident Peak at Input Voltage - - - -
OlverslfledCPperCUrtomer -kW - - - -
System Lesser
kWh at Input Voltage 155,146 73,58D 25,593 2$902 67,181
Average Group losses 33% 33% 3.3% 33% 3.3%
kWh at I..UI by Tlmo Pedod
OR-Peak Energy 91,513 36,]90 12,196 14,396 33,591
On Peak Energy 97,513 36,19D 12,196 14,396 33,591
Sloulder-Peak Energy
otal kindUO a 195,146 ]3,580 25,593 28,]92 6],181
Appendix B Prepared by:
Historical Load Data B-6 Utility Firsmial Solutions, LLC
I
❑ty of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -Ty 2014
customer load %prile peran Historic
Seasonal Randandal
Customer Type Seasonal Residential
Customer Load Profile Type Seasaul Residential
DisWbudon flights Parmeter kWh
Tmal Winter Summer Inter-2 mtesi
Customers 51 51 51 51
Load factor - Group 4036 55% 55% 40%
Group Losses:
Secomlary 30% 3Pb 2.036 2.
Primary 10% LOM 10% 1.
Substation 0.2% (17)6 0.236 Is
Individual NCP 192 121 142 123
Group Coincident Factor 1N% 10]36 10716 1
NCP Meter for Group 192 121 142 123
5,,oem Coincidence factor 85% 9T6 W% 85%
Wilily Sta it (Yes, End 62014)
Actual DemaM - - - -
EnergyatMeler 641$45 223033 99,151 116,200 202,661
Revenue $ 45,381
Cost per kWh year End 62014) $ 0.0202
Usage P.M.-NQ
Average MonWy kWh per Customer 1,033 922 1,144 989
NCP at Primary for Group 193 1% 124 150 126
Non-Cosciderte Peak at Input for Group 198 198 125 152 129
Estimate Peak Usage Per Customer 3,9 3,89 2,45 2,99 3.49
Usage profile - OP
Coincident Peak at Input Voltage 169 121 148 152
Doomfied CP Ms Customer AW 330 230 2.89 2.%
System losses
kWh at Input Voltage 662,407 230,285 102,325 120,495 203,251
Avenge Group Losses 33% 3.3% 33% 3.3% 33
kWh at Input by Tine Period
Off Peak Energy 331,203 115,143 51,169 60,242 IUI
OnPeak Energy 331,203 115,143 51,1M 60,242 1W,6M
SMUltler~Peak Energy
TatalkWhU 662,407 230,285 302,325 120,495 207,251
Aapendia B Prepared by:
Historical Load Data B-7 Utility Financial Solutions, LLC
Appendix C - Projected Load Data
This Appendix details load data used as the basis for determining allocators for the study. The data
forms a projection of customer class usage patterns by season for the test year.
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study - TY 7014
Customer Wa Profile Detail Pr R
GoveFmn fgnglCP.hase Total-W4nIerSom e~r G0er-2-IdteTd~
Customer Type Government Single Phase
Customer Load Profile Type Government Single Phase
Distribution Billing Parameter W
Customer Gowth Historic-Test Year 1.1996
Energy Growth Historic -Test Year 2.1056
Customers 85 85 96 85 85
Load Factor - Group 32% 21% 28% 26%
Group Lasses:
Secondary 2.096 2.0% 2.M 2.096
Primary 1.0% 1.0% 1.0% 1.0%
Substation 0.2% 0z% 0.2% 0.2%
Inchidual NCP 701 715 669 703
Group Coincident Factor 90141 90% 90% 90%
NCP Meter for Group 631 644 602 632
System Coincidence Factor 95% 90% 90% 93%
Billing Statistics Test Year (Projected)
Actual Demand 2,804 1,430 1,339 2,811
Energy at Meter 1,677,161 645,063 219,668 273,722 538,708
Revenue $ 152,801
Cost per kWh $ 0.0911
Usage Profile - NCP
Avenge Monthly kWh per Customer 1,897 1,277 1,610 1,584
NCP at Primary for Group 656 643 656 614 645
Non-Coincidence Peak at Input for Group 665 651 665 622 653
Estimate Peak Usage per Customer 7.7 7.66 7.73 7.32 7.68
Usage Profile - CP
Coincident Peak at Input Voltage 619 590 560 607
Diversified CP per Customer-kW 7.28 6.95 6.59 7.14
System Losses
kWh at Input Voltage 1,731,698 666,039 226,811 282,622 556,226
Average Group Losses 3.3% 3.396 3.3% 3.3% 3.3%
kWh at Input by Time Period
Off-Peak Energy 865,849 333,019 113,405 141,311 278,113
On-Peak Energy 865,849 333,019 113,405 141,311 278,113
Shoulder-Peak Energy
Total kWh Usage 1,731,698 666,039 226,811 282,622 556226
Appendix C Prepared by:
Projected Load Data C-1 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study - W 2014
Customer bad Profile Detail Pr e d
Muniai a151ngle.Bhbse Total®WlnterSummer~Intaid-Intee4~
Customer Type Municipal Single Phase
Customer Load Profile Type Municipal Single Phase
Distribution Billing Parameter kW
Customer Grovvh Historic-Test Year CAM
Energy Growth Historic-Test Year 0.90%
Customers 50 50 50 49 50
Load Factor - Group 70% 61% 75% 58%
Group Lasses:
Secondary 2.0% 2.0% 2.096 2.0%
Primary 1M 10% 1.0% 1.0%
Substation 0.2% 0.2% 0.2% 0.21;
Individual NCP 151 IN 102 136
Group Coincident Factor 100% 10096 100% 100%
NCP Meter for Group 151 100 102 136
System Coincidence Factor 95% 90% 90% 93%
Billing Statisda Test Year (Projected)
Actual Demand 605 201 205 543
Energy at Meter 745,329 309,266 95,172 110,266 230,626
Revenue $ 66,385
Cost per kWh $ 0.0891
Usage Profile - NCP
Average Monthly kWh Per Customer 1,546 952 1,125 1,153
NCP at Primary for Group 154 154 102 104 138
Non{ incidence Peak at Input for Group 156 156 104 106 140
Estimate Peak Usage per Customer 3.1 3.13 2.07 2.16 2.80
Usage Profile-Cp
Coincident Peak at Input Voltage 148 93 95 130
Diversified CP per Customer-kW 2.97 1.87 1.94 2.61
System Losses
kWh at Input Voltage 769,565 319,322 98,267 113,851 238,126
Average Group Lasses 3.3% 3.3% 3.3% 3.396 3.39K
kWh at Input by Time Period
Off-peak Energy 384,783 159,661 49,133 56,926 119,063
On-Peak Energy 384,783 159,661 49,133 56,926 119,063
Shoulder-Peak Energy
Total kWh Usage 769,565 319,322 98,267 113,851 238,126
Appendix C Prepared by:
Projected Load Data C. 2 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study - T' 2014
Customer Load Profile Detail Pra eR
GovernmentRhreF.P.hase Tdtal~Wlnt~50mm¢i~lhte~2~lnter'c4_
Customer Type Gavernment Three Phase
Customer Load Profile Type Government Three Phase
Distribution Billing Parameter kW
Customer Growth H lstoric - Test Year 0.00%
Energy Grovth Historic - Test Year 0.90%
Customers 43 42 43 43 43
Load Factor - Group 37% 29% 35% 31%
Group Losses:
Secondary 2.0% 2.0% 2.D% 2.0%
Primary 1.0% 1.096 1.036 1.0%
Substation 03% 0.7% 0.2% DN
Individual NCP 1,650 1,560 1,732 1,702
Group Coincident Factor 1009S 100% 100% 100%
NCP Meter for Group 1,650 1,560 1,732 1,702
System Coincidence Factor 95% 90% 90% 93%
Billing Statistics Test Year (Projected)
Actual Demand 6,fi01 3,121 3,464 6,807
Energy at Meter 4,884,790 1,754,077 664,125 907,781 1,558,807
Revenue $ 396,580
Cost per kWh $ 0.0812
Usage Profile - NCP
Average Monthly kWh per Customer 10,441 7,722 10,556 9,063
NCP at Primary for Group 1,766 1,683 1,591 1,766 1,735
Non-Coincidence Peak at Input for Group 1,788 1,704 1,611 1,788 1,757
Estimate Peak Usage Per Customer 41.6 40.57 37.47 41.59 40.86
Usage Profile - CP
Coincident Peak at Input Voltage 1,619 1,450 1,609 1,634
Diversified Ca per Customer-kW 38.54 33.72 37.43 38.00
System Losses
kWh at Input Voltage 5,043,632 1,811,115 685,721 937,300 1,679,496
Average Group Losses 3.3% 3.3% 3.3% 3.3% 3.3%
kWh at Input by Time Period
OH-Peak Energy 2,521,816 905,558 342,860 468,650 804,748
On-Peak Energy 2,521,816 905,558 342,860 468,650 804,748
Shoulder-Peak Energy
Total kWh Usage 5,043,632 1,811,115 685,721 937,300 1,609,496
Appendix C Prepared by:
Projected Load Data C- 3 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -TY 2014
Customer Load Profile Detail Pro d
Munk( INhreePhase Tdtal inter Summer~Inte~:2O16teP9~
Customer Type Municipal Three Phase
Customer Load Profile Type Municipal Three Phase
Distribution Billing Parameter WV
Customer Growth Historic - Test Year 0.00%
Energy Groyrth Historic - Test Year 0190%
Customers 21 21 22 21 21
Load Factor-Group 61% 54% 70% 62%
Group Losses:
Secondary 2.0% 2.0% 2.0% 2.D%
Primary 1.0% 1.0% 1.0% 1.0%
Substation 02% 0.2% 01% 0.2%
Individual NCP 991 1,055 999 1,025
Group Coincident Factor 100% 100% 100% 100%
NCP Meter for Group 991 1,055 999 1,025
System Coincidence Factor 95% 90% 90% 93%
Billing Statistics Test Year (Projected)
Actual Dome nd 3,962 2,110 1,998 4,100
Energy at Meter 5,474,121 1,264,159 852,177 1,001,164 1,956,621
Revenue $ 386,367
Cost per kWh $ 0.0706
Usage Profile - NCP
Average Monthly kWh per Customer 21,002 19,368 23,837 22,103
NCP at Primary for Group 1,076 1,010 1,076 1,019 1,045
Non{ Incidence Peak at Input for Group 1,089 1,023 1,089 1,031 1,058
Estimate Peak Usage For Customer 50.4 48.70 49.51 49.11 50.39
Usage Profile - CP
Coincident Peak at Input Voltage 972 980 928 984
Diversified CP For Customer-kW 46.27 44.56 4420 46.86
System Losses
kWh at Input Voltage 5,652,126 1,821,525 879,888 1,033,720 1,916,994
Average Group Losses 3.336 3.3% 3.3% 3.3% 3.3%
kWh at Input by Three Period
Off-Peak Energy 2,826,063 910,763 439,944 516,860 958,497
On-Peak Energy 2,826,063 910,763 439,944 516,860 958,497
Shoulder-Peak Energy
Total kWh Usage 5,652,126 1,821,525 879,888 1033,720 1,916,994
Appendix C Prepared by:
Projected Load Data C- 4 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study - TY 2014
Customer We Profile Detail r cted
Government` emdcar Total-Wloler~Wffirerf rote :2~inter4Iiiiiii1l
Customer Type Government Secondary
Customer Load Profile Type Government Secondary
Distribution Billing Parameter kW
Customer Gromh Historic - Test Year 100.0094
Energy GroWth Historic -Test Year 70.65%
Customers 2 2 2 2 2
Load Factor-Group 29% 23% 25% 28%
Group Losses:
secondary 10% 2.0% 2.0% 2.M
Primary 1.0% 1.0% 1.0% I.o%
Substation 0.2% 0.2% 0.2% 0.2%
Individual NCP 4,334 4,979 5,603 4,452
Group Coincident Factor 75% 75% 75% 75%
MCP Marc, for Group 3,251 3,735 4,202 3,343
System Coincidence Factor 75% 75% 75% 75%
Billing Statistics Test Year (Projected)
Actual Demand 17,337 9,959 11,206 17,827
Energy at Meter 10,984,378 3,593,654 1,719,336 1,990,555 3,680,832
Revenue $ 818,041
Cost Per kWh $ 0.0745
Usage Profile - NCP
Avenge Monthly kWh per Customer 449,207 429,834 497,639 460104
NCP at Primary for Group 4,286 3,315 3,809 4,286 3,409
Non. incidence Peak at Input for Group 4,339 3,356 3,856 4,339 3,451
Estimate Pea k Usage per Customer 2,169.4 1,678.16 1,928.00 2,169.44 1,725.63
Usage Profile - CP
Coincident Peak at Input Voltage 2,517 2,892 3,254 2,588
Diversified CP Per Customer AW 1,258.62 1,446.00 1,627.08 1,294.22
System Losses
kWh at Input Voltage 11,341,561 3,710,512 1,D5,245 2,055,283 3,800$24
Average Group Lasses 3.3% 3.3$1 1316 3.3% 3.3%
kWh at Input by Time Period
OH-Peak Energy 5,670,782 1,855,256 887,622 1,027,642 1,900,262
On-Peak Energy 5,670,782 1,855,256 687,622 1,027,642 1,900262
Shoulder-Peak Energy
Total kWh Uea a 11341,564 3,710,512 1,775,245 2,055,283 3,800,524
Appendix C Prepared by:
Projected Load Data C-5 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study - TY 2014
Customer Load Profile Deal Pnsected
Commerda151ng1e'D.haze Total-WidleFl♦SGmm¢~Ibter-2~Ib[ei-0~
Customer Type Commercial Single Phase
Customer Load Profile Type Commercial Single Phase
Distribution Billing Parameter kW
Customer Growth Historic - Test Year 1.01%
Energy Growth Historic - Test Year 192%
Customers 1,141 1,141 1,172 1,122 1,127
Load Factor - Group So% 48% 56% 46%
Group Losses:
Secondary 2.0% 2.m 2.096 2.0%
Primary 1.0% 1.0% 1.0% 1.0%
Substation 0.2% 0.2% 01% 0.2%
Individual NCP 5,781 6,929 5,697 5,637
Group Coincident Factor 7096 85% 70% 70%
NCP Meter for Group 4,047 5,889 3,988 3,946
System Coincidence Factor 95% 90% 90% 93%
Billing Statistics Test Year (Projected)
Actual Demand 23,125 13,857 11,395 22,546
Energy at Meter 25,537,547 8,346,995 4,943,444 4,628,848 7,618,258
Revenue $ 1,993,133
Cost Per kWh $ 0.0780
Usage Profile - NCP
Average Monthly kWh per Customer 1,829 2,109 2,063 1,690
NCP at Primary for Group 6,006 4,127 6,006 4,067 4,024
Non incidence Peak at Input for Group 6,081 4,178 6,081 4,118 4,074
Estimate Peak Usage Far Customer 5.2 3.66 5.19 3.67 3.61
Usage Profile - cP
Coincident Peak at Input voltage 3,970 5,473 3,706 3,789
Diversified CP per Customer AW 3.48 4.67 3.30 3.36
System Losses
kWh at Input Voltage 26,367,968 8,618,420 5,1Og194 4,A9,368 7,865,986
Average Group Losses 33% 3.3% 3.3% 33%
kWh at Input by Time Period
OH-Peak Energy 13,183,984 4,309,210 2,552,097 2,389,684 3,932,993
On-Peak Energy 13,183,984 4,309,210 2,552,097 2,389,684 3,932,993
Shoulder-Peak Energy
Total kWh Usage 26,367,968 8,618,420 5,104,194 4,779,368 7,865,986
Appendix C Prepared by:
Projected Load Data C-6 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -7Y 2014
Customer Load Profile Detail Projected!
CommerNahThree Phase Total~WinterSumme-r ilnte~lnh?ice
Customer Type Commercad Three Phase
Customer Lead Profile Type Commercial Three Phase
Distribution Billing Parameter kW
Customer Growth Historic - Test Year 1.06%
Energy Growth Historic -Test Year 1.96%
Customers 381 381 350 398 393
Load Factor-Group 45% 43% 48% 42%
Group Lasses:
Secondary 2.0% 2A% 2.0% 2.0%
PH., 1.0% 1.096 1.0% in
Subsunion 02% 0.2% 03% ON
Individual NCP 7,902 7,239 8,709 8,336
Group Coincident Factor 70% 85% 709k 70%
NCP Meter for Group 5,531 6,153 6,097 5,835
System Coincidence Factor 95% 90% 90% 93%
Billing Statistics Test Year (Projected)
Actual Demand 31,607 14,477 17,419 33,342
Energyat Meter 31,124,932 10,250,159 4,592,771 6,005,898 10,276,105
Revenue $ 2,259,814
Cost per kWh $ 0.0726
Usage Profile- NCP
Average Monthly kWh per Customer 6,726 6,561 7,545 6,537
NCP at Primary for Group 6,275 5,641 6,275 6,217 5,951
Non,Goincidence Peak at Input for Group 6,353 5,711 6,353 6,295 6,025
Estimate Peak Usage Per Customer 18.2 14.99 18.15 15.82 15.33
Usage Profile - CP
Coincident Peak at Input Voltage 5,426 5,718 5,665 5,03
DNersifed CP per Customer-kW 14.24 16.34 14.23 14.26
System Losses
kWh at Input Voltage 32,137,043 10,583,470 4,742,117 6,201,196 10,610,260
Average Group Losses 3.3% 3.3% 3.3% 3.3% 3.3%
kWh at Input by Time Period
Off Peak Energy 16,068,521 5,291,735 2,371,059 3,100,598 5,305,130
On-Peak Energy 16,068,521 5,291,735 2,371,059 3,100,598 5,305,130
Shoulder-Peak Energy
Total kWh Usage 32,137043 10,583,470 4,742,117 8,201,196 10,610,260
Appendix C Prepared by:
Projected Load Data C-7 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study - TY 2014
omer Load Profile Detail P ed
Commercial Cbnstkoc9lon Tdtbl®Wluter~SGmmer~lncerv2~lnte~c4~
Customer Type Commercial Construction
Customer Load Profile Type Commercial Construction
Distribution Billing Pa rameter kWh
Customer Growth Historic - Test Year 0.00%
Energy Growth Historic - Test Year 0.90%
Customers 17 13 22 18 16
Load Factor-Group 50% 50% 50% 50%
Group Losses:
Secondary 2.0% 2.0% 2.0% 2.0%
Primary 1.01K 1.0% 1.0% IN
Substation 0.2% GM 0.2% on
Individual NCP 16 5 10 8
Group Coincident Factor 70% 70% 70% 70%
NCP Meterfor Group 11 4 7 6
System Coincidence Factor 75% 75% 75% 75%
Billing Statistics Test Year (Projected)
Actual Demand _ - - -
Energy at Meter 45,273 22,696 3,815 7,199 11,560
Revenue $ 5,519
Cost Per kWh $ 0.1219
Usage Profile - NCP
Average Monthly kWh per Customer 436 87 200 181
HOP at Pnmary for Group 11 11 4 7 6
Non{olncidence Peak at Input for Group 11 11 4 7 6
Estimate Peak Usage per Customer 019 0.87 0.17 OAO 036
Usage Profile - CP
Coincident Peak at Input Voltage 8 3 5 4
Diversified U Per Customer-kW 0.65 0.13 0.30 0.27
svstem w:sex
kWh at In put Voltage 46,743 23,434 3,939 7,433 11,936
Average Group Losses 3.3% 3.3% 3.31% 3.316 3.391
kWh at Input by 71me Period
OH-Peak Energy 23,371 11,717 1,970 3,717 5,968
On-Peak Energy 23,371 11,717 1,970 3,717 5,968
Shoulder-Peak Energy
Total IrMU a 46,743 23434 3,939 7,433 11,936
Appendix C Prepared by:
Projected Load Data C-8 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cast of Service and Unbundling Study -TY 2014
Customer wad Profile Detail Nolected
Telecom Total-WinterJ111111111111111111 SUmme~, InteT-2-Inter-0glillig
CUitomar Type Telerom
Customer Lead Profile Type Telecom
Distribution Billing Parameter kWh
C comer Gnomh Historic - Test Year 20.00%
Energy Growth Historic -Test Year 30.01"911
Customers 2 2 2 2 2
load Factor - Group 45% 45% 45% 45%
Group Losses:
Secondary 2.0% 2.0% 2.0% 2.0%
Primary 1.0% 1.0% Lm 1.0%
Substation On 0.2% 0.2% 0.2%
Individual NU 157 153 158 155
Group Coincident Factor 100% 100% 100% 10014
NCP Meter for Group 157 153 158 155
System Coincidence Factor 100% 100% 100% 100%
Billing Statical Test Year iProjectedl
Actual Demand - - - -
Energyat Meter 613,800 204,600 102,300 102,300 204,600
Revenue $ 56,092
Cost Per kWh $ 0.0914
Usage Profile - NCP
Avemge Monthly kWh per Customer 25,575 25,575 25,51"5 25,575
NCP at Primary for Group 161 160 156 161 158
Non-Coincidence Peak at Input for Group 163 162 158 163 160
Estimate Peak Usage Par Customer 81.5 WAS 78.87 81.50 80.17
Usage Profile -CP
Coincident Peak at Input Voltage 162 158 163 160
Diversified CP Per Customer-kW 80.83 78.87 81.50 80.17
System Losses
kWh at Input Voltage 633,759 211,253 105,627 105,627 211,253
Average Group Losses 3.3% 3.3% 3.3% 3.3% 3.3%
kWh at Input by Time Period
OH-Peak Energy 316,880 105,627 52,813 52,813 105,627
On-Peak Energy 316,880 105,627 52,813 52,813 105,627
Shoulder-Peak Energy
Total kWh Usage 633,759 211,253 105,627 105,627 211,253
Appendix C Prepared by:
Projected Load Data C- 9 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -TY 2014
Customer Load Profile D all Pr ect d
ReadentialSingle PRase Total~Winter2i♦SUmidei~lhterv2~IbteM~
Curtomer Type Residential Single Phase
Customer Load Profile Type Residential Single Phase
Distribution Billing Parameter kWh
CustomerGrowth Historic-Test Year 1.00%
Energy Growth Historic - Test Year 1.91%
Customers 10,212 10,136 10,281 10,270 10,161
Load Factor-Group 43% 52% 52% 43%
Group Lasses:
Secondary 2.054 2.0% 2.0% 2.0%
Primary 1.0% 1.0% 1.096 in
Substation 0.2% 0.2% 012% on
Individual NCP 31,463 15,067 17,987 22,415
Group Coincident Factor 7056 85% 70% 70%
NCP Meter for Group 22,024 12,807 12,591 15,690
System Coincidence Factor 85% 97% 97% 87%
81I0ng StatisHa Test Year (Projected)
Actual Demand - - - -
Energy at Meter 92,636,427 39,288,067 11,658,495 13,468,763 28,221,102
Revenue $ 6,596,584
Cost per kWh $ 0.0712
Usage Profile - NCP
Average Monthly kWh per Customer 969 567 656 694
HOP at Primary for Group 22,461 22,461 13,061 12,841 16,002
NomComcidence Peak at Input for Group 22,740 22,740 13,224 13,000 16,201
Estimate Peak Usage Per Customer 2.2 2.24 1.29 127 1.59
Usage Prattle - CP
Coincident Peak at Input Voltage 19,329 12,827 12,610 14,094
Diversified CP per Customer-kW 1.91 1.25 133 1.39
System Losses
kWh at Input Voltage 95,618,748 40,565,624 12,037,602 13,906,736 29,138,786
Avenge Group Los. 3.3% 3.396 3.3% 3.336 3.8%
kWh at Input by Time Period
OH-Peak Energy 47,824,374 20,282,812 6,018,801 6,953,368 14,569,393
On-Peak Energy 47,824,374 20,282,812 6,018,801 6,953,360 14,569,393
Shoulder-Peak Energy
Total kWh Usage 95,648,748 40,565,624 12,037,602 13,906,736 29,138,796
Appendix C Prepared by:
Projected Load Data C-10 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study -TV 2014
rtom r ad Profile Detail Pusladed
Dahl,Dghting Total~Mnt_er~ SUmme~r lntaI7 erS_A
Customer Type 'Outdoor Lighting
Customer Load Profile Type Outdoor Lighting
Distribution Billing Parameter kWh
Customer Growth Historic - Test Year 0.0096
Energy Growth HILI -Test Year 0.00%
Customers 59 59 58 59 61
Load Factor - Group 45% 45% 45% 45%
Group Losses:
Secondary - 2.0% 2.0% 20% 2A%
Primary 1.0% 1.0% 1.0°6 1.0%
Substation 0.2% 0.2% an 02%
Individual NCP 55 37 43 49
Group Coincdent Factor 100% Loam 100% 10014
NCP Meter for Group 55 37 43 49
System Coincidence Factor 0% 0% 0% 0%
Billing Statistic Test Year (Projected(
Actual Demand - - - -
Energy at Meter 189,000 71,262 24,787 21,885 65,066
Revenue $ 18,536
Cast per kWh $ 0.0981
Usage Profile - NCP
Average Monthly kWh per Customer 302 214 236 267
NCP at Primary for Group 56 56 38 44 50
Non-Coincidence Peak at Input for Group 56 56 38 44 51
Estimate Peak Usage per Customer 1.0 0.95 0.66 075 0.84
Usage Profile - OR
Coincident Peak at Input Voltage - - - -
DlversifiedCPperCustomer -kW - - - -
System Losses
kWh at Input Voltage 195,146 73,580 25,593 28,792 67,181
Avenge Group Losses 3.3% 3.3% 3.3% 3.3% 3.3%
kWh at Input by Time Period
Off-Peak Energy 97,573 36,790 12,796 14,396 33,591
On-Peak Energy 97,573 36,790 12,796 14,396 33,591
Shouider-Peak Energy
Total kWh Usage 195,146 73,580 25,593 28,792 67,181
Appendix C Prepared by:
Projected Load Data C-11 Utility Financial Solutions, LLC
City of Ashland, Electric Department
Electric Cost of Service and Unbundling Study - TY 2014
Customer Wad PProfile Detail Pr
Suicidal Barre ntial Total®Winter] Summer~Gte-2~intir_4~
Customer Type Seasonal Residential
Customer Load Profile Type Seasonal Residential
Distribution Billing Parameter kWh
Customer Growth Historic-Test Year 0.00%
Energy Growth Historic-Test Year 0.00%
Customers 51 51 51 51 51
Load Factor-Group 40% 55% 55% 40%
Group Losses:
Secondary 2.0% 2.0% 2.0% 2.0%
Primary 1.0% 1.0% 1.M 1.0%
Substation 0.2% 0.2% 0.2% 0.2%
Individual NCP 192 121 147 173
Group Coincident Factor 100% 100% 100% 100%
NW Meterfor Group 192 121 147 173
System Coincidence Factor 85% 97% 97% 85%
Billing StzNStirs Test Year (Projected!)
Actual Demand - - - -
Energy at Meter 641,545 223,033 99,151 116,700 202,661
Revenue $ 46,057
Cost per kWh $ 0.0718
Usage Profile . NCR
Average Monthly kWh per Customer 1,093 972 1,144 993
NCP at Primary for Group 196 196 124 150 176
Non{Oincidence Peak at Input for Group 198 198 125 152 179
Estimate Peak Usage per Customer 3.9 3.89 245 2.98 3.50
Usage Profile - CP
Coincident Peak at Input Voltage 169 121 148 152
Diversified CP Per Customer -kW 3.30 2.38 2.89 2.98
System Losses
kWh at Input Voltage 662,407 230,286 102,375 120,495 209,251
Average Group Losses 3.3% 3.3% 3.3% 3.3% 3.3%
kWh at Input by Time Period
Of.Peak Energy 331,203 115,143 51,188 60,247 104,626
On-Peak Energy 331,203 115,143 51,188 60,247 104,626
Shoulder-Peak Energy
Total kWh Usage 662,407 230,286 302,375 120,495 209,251
Appendix C Prepared by:
Projected Load Data C-12 Utility Financial Solutions, LLC
Appendix D - Cost of Service Allocators
This Appendix details the allocation of forecasted test year expenses to the customer classes based on
Appendix C
J
v
c
d O_
m b N vl M n n Ol N u1 Q Vl m W O vl N W O T O ti b O 41 W Vl N M n tO n
m Ill rv rl b O o n p 'I m V1 m m m Yl m M p n ti 1D ti n Ol O m m O p 0
q N m m Q n IO IO Ip Q a N O] a0 n o vl .4 n o In p Q .i N n W al m p R d p
"i W b m b mm I.ni mm vO1imng omngomm a o°ti 10nmo`n°r°i n 0p0 vQi N
d p N N T e1 T N T H T~ m n N N VI O N rl Q O N
E a N vl N M vl vl N M vl tV O o
Q b O O Q b p N fy
E y m .y .y .I I m m d
o c` c
r c.
a m on n 18 mrvlnn m1p rmim ~m~m~ m~m~n ~~m mg W IWila rv g IQn
d a .y o m Q n n..I W ml~im.y N oldmN olommQ mm and ~rvln rv m Vl
y d ti ID M lM1 M M T m 'I ry O m Ol N Ol N Ol N Ol N n m g m Ill t0 (II m W n ~ n N
L N fi n Ol O V1 W m O VI W M ap n lO Q O N rl m rti Ol
d 6 m m VI M Ol m Vl M Ol M Ip n W m OI t0 10 I!I IO M O
E d fl Q N N fVl Q N N (I'1 N W V1 Q 1~ W Q Q h N N H
E m
o i
N
N V1NN
ry pf n N Q O] n Ol lD n W IO N N N lp N N N Q N IA M Q Q b Vl W W N
m Vl W N WVl M al ON W M O N I IQO N N tNp IQO N Ibll VI N N IM1 10 m Vi W M Ol W Q
d Q N N M N~ p1 'I ~ lp W VI n n p Vl n n p ~ O Vl Vl p M Ol O O a N N O
E N I!) VI W N O T W N O Q r n Vl O Ol ei Ol W b W N n W
m W O n
m m n O W ul n m m rv m Q
E aE W W W O W
~ fl N 'I 'I N N ~j M e'I N M M fl fl M O
O
N N H N
y Ol N O W pW N O W O O n m Q O n M V O n VJ Vl W O Q Ol n N N N O
i N O Onl p1 01 Ol OI 'I Ol O N M n Cl QW Q n CO W Q I I/1 W n Ol fi I I VJ I 01 M VI
r N trf N rl Q b 0 m IO W O m W N N Oi T b Q N b Q M O
a W M VI M VI VI N n m 'i l0 Vl p T n b N
M T Q Vl OI Ol Q Yl OI VJ W W O Ol n W O W Q 'I N
6 L Vl rl N ei '-I ei .ti vl
V 6
C
N Vl N t/l
m W Ol O Of Q V n N O W O O W W O O W N Vl O ID m y n O Q W Ol
Q W N Vl O m O N IO O m W M b vl Q. b, Q m. N O m n W O Ol W m
c d n Ip Q b t0 ID Q W Ol Vl vl W b n vl W IO n VQQJ N n m pp Ql O N n W n N v m
d ry .y .y .I .i .ti b tvl tvl IO Ol-I m m m V N M V O W b m IO n b 001 I~ 0 "T cs
E 0
c
Ew
>
O L
r
N N H H
d O ID W M VI O VI rl V1 m Q V1 ei m VJ m I I VJ m N n e4 b lD N b b 01 N b Vl
m VI OI 01 O O O Q VI W t0 m N.. N ID lD N VJ Vl l0 b N N b Ol
C IO N Vl VI M t0 Ol O. W O Vl T N W N N w M Q dl Q O
ti VJ al 01 IO Ol W 01 VJ al O1 W c6 M W O1 Y1 O O Vl m
d IO Ill Q VI rl Vl Q VI N IO fi OI H M O m H M Q N In N
d 'i rl rl rl n m e4 N m N N n
6 L
u 6
C
N V1 N V1
Vl V1 Ol W p n p O m fl M 'i Ol In '1 Ol In H W Ol '1 N V) m w N W N VJ W I
W l0 0 lp O O M M W O O fl O fl 01 m N N VJ l0 N O ti m N
C d Ip Ip N VI lp W Q M W M W O Q M fl O Q M 0 l0 O W ID N O t0 n n Q W
d N N 'I fl N W N M WM rl ID VJ N VJ VI Ol m W n y g
E M m m I m lp N W VI Q m m I
Q W W
c 6 M 'I N M fl N n lp N N Yl VJ N N VI VJ
a i m
eY O C
O V' b
N an v~ ~n ~n
W m In n
m m n n
M 0 N N
N v E N q E N q E N q E N Y E `7 Y
00 c E `v `v c E a+ `v c E a+ `v E a+ w c E `v v
c v
v e ~
a 5 5
p O ~ ~ - d d ~ d
a v c
s n ~ y
O d v a a i n v .d, a V `w
w 2 cv a a v E > mq q mm~ ~ °w
~ y c v v a v a a ov ~ ~ ~ ~ ~ m ~ ~ Io A rv « « « « " ~ v
E E E E www c cww c»j»~~EE °>t In .
w e u u o o v
L I«n Eou n`w . E .ry qq ~ooooQ ~aa w a i66 x33333 ~m n mw Nm\
O c - v a a y n-
V d oE?"yy">>> j d >,G .G «'°'°.a. v v v v c v $
Q L° c 0 0 o f o o Y, Y, Yi o v t c c c c o 0 0 o o wIc w w o o d LL
I« u o E u z o~ >In a r W o `0 `0 0 0 0 0 0 r r r r r r z z a
L v s
u W Q 0 x n
C O
a N
Q u
T J
~ J
d
C
p pp p p p q O
b 8 0 ° O O g o 2' d 3
q d O N N O Y1 V1 V1 Il1 N N N INII W lMM1 O] n t~0 m m O
a
E d
E ° m
O L C
r ll
H T
tp 0 0 0 0 0 0 0 0 a° a° a° a° a° w
O m
q b Om Om M N m M m Ol 01 T O M n m N n
b 6 ~O .y
E d
E m
o c
N
N
^ g g ° g ° g S S 3° D° dE d°.
o
m o a a ° a 0 0
o o -l rn m
c ^ r~ ,ti n ~ N n o+ m m .n rv n m m
d q P N N O1 O1 O~ M n m t0 t0
E
E E
o °
w
d N 0 0 0 0 0 000 b n 00000000 0 0 o m m m N
VI VI fl N VI VI N N N N N N n M N O O
r b p a N N N m N m m m
n q 'I
L
C
J
N
O O O O O O O
0 0 0 0 0^8 0 0 0 0 0 0 w m m o 0 w
d N O ul ul .-i vl vl of vl n b O b t0
E N V O O O O N N m N
E d
b b
O C
cv r
N
O p O O O p O O
d 0 0 0 0 0 0 0 0 i0 ~p ~p N v m rv m
G ryj Aj I m I ~yj m m m M IT V m N m ❑
cr~ - d p O G O O O 0 O O O
q A rl
nL
b a
c m
J c
N t
Yf 00008 800
b W O O O O N 'i O O N N N n n N m
C
3 8 N m
b q v1 n .y .i ey 2. .y .y N .y .4 O
E L m ~
E ° a
W d C
C O
N O y
Q N N
N ~n
d
E
0
> u
D
J
V
pp o O O
« .
C ~ O O w
d C
~ w w
c n
m C ~ m c c c
n ] m
D C :m Y Y Y ~ a n a E
m 3 v ~o a a
L' u a a m v m d `b' `b' a v v v
w W vbi .a c 'SP .Z 'a c v co ° i a a a c
3 L V 'V V = C C N
m d v 3 i u w o o o u u u d c x
m w ¢ 3 m u a c E `w ? c O v o
r Np Eo v v m o vJi o o N E 3 c y b rv d a> bo u
Q U o> u Z u z u z u u 3 u_ u- y c b 0 O
46° o r u N u N f u 2 'm 8Z u z n z n r u r u r u r u a n w n
V m V V
01 _ mid O
V W Q > Q O Vdl
U
C p
d H
n ~
O O
Q U
T J
L J
~ N
C
tp O
01 01 N N N n n n n n n M Vf
A d M m P P P O] O] W m m 01 W rl a O
V R N M V1 V1 OJ O] O] O O O n M N
d L ti ti ti N N N N ei ~
6
E d
E
o ~`c c
LL?
Y_
d O1 01 lO l0 L0 m M T l0 b, M VI
q H n n J1 VI N N 01 Cl tO P ~
Ol Ol .Ni .Ni .Mi .Mi .Mi l0 t0 l0 ~ Ol
~ i fl
E d
E m
o c
U y~
a° a° a a° a° a° a a°
m m
m m 't ti ti w w w w ut M m rv
~ Q P n n n m m m rv o
d Z, e e v; ~ vi ~ ~ e e ~ e ~ 0
E d
c E
>
d 6
v a ~o w ~o a a a ~ ~ ~
r d m m ri rv rv m m m ni rri ni m o
n ~
L
V 6
C
d w w P P P w w w .n. .n. .n. o
c~ w ~ e e oo ro ro m m
d q N N N N N N N N M M M N O
E L
E
d d
> d
o c`
d d° d° d° d° d° d' d° 3° 2: dF d° A e~° m
m m m n n n rv N rv m ro m m '
c M M Q P Q Q Q P M M m o P
0 0 0 0 0 0 0 0 0 0 0 0 0
d
n 10
L
u n
c
d w ro n n n m m m co co co co
m m m m v+
m m m m m m
o
d m o 0 0 0 0 0 0 0 o c o
0 0
E L
E a
d
.y o
O u,
}N
T
9
N
00
C_
c v
a c
E ~
Y a
N C
a~
a a d
E `d `w P y N rv
Oy ~ E m c > ~ c ~ c c ~ `w
W Z w v w m' w m to
W VI VI w E ~ C ~ `C C Q d P `C ~ N d rv w ~ t U`
m 0 O y M 0 y 0 y 3 3 0 v O y P= 0 y O y `V o f o
in d a >a a a a a o$ m
L O m X01° c mo ~o ~o mo E V
Q V W 0 o d 0 `d 0 ~ F d 0 w 0 `w F d 0 w 00 o ~ r em u' -O
w w II n n n n
w w w Z n Q
wO V o n n w u w II n n
V
d 9 0
U w Q K dw
v
a p
W
6 v~
a o
a u
T
N
~ C
m O_
m
q N m m m o m n o b rv m v°
m a` o
e e e e rv e b o io Iq b OR
m n G .ti m m ri m
d 6 •i .i .i .4 .i .4 .4 N .4 rl .-I .-I ~
E d ~ C
E °i m
O t C
~ LL?
4
a ~ a° a° a° a a° a' a° x a'
N N O1 m m of V1 C1 T O C1 O~ Lq m m m
L O O O O N O O O O O m O
d 6
E v
E m
o c
u H
a' ae a° a° ac a' a' a: ae a' X X
m m m m o M m o m m m w m O
E~ 0 0 0 0 0 0 0 0 0 0 io a b m
c E~
i `
d b V1 N N b Vl
IQ b b b Iq ID IR N M ~
m b o ro
r d o 0 0 0 0 0 0 0
6 N
L
V 6
C
C~
C
C d M m m fry M M M O M M O ID N kq
E N ti N ti ti ti ti fl o e4 N M N M N
E n
d y
O L
F
d a d° d° d° d° rv o X 2° d° V
m M °i °1 °1 N C1 M O Of O1 l° b O b
C
d 0 O O O N O O O O O O O O O
6 q
V 6
cC_
C
d N N N N vl N N O N N b b b 1~
C M m m 0 o 0 m o 0 0 0 O N vl N O 'I O
E o 0 0 ni 0 0 0 .i
a
E
d
d m
M O C
YN l7 m
F m
m
> 3
~ z m
in a
m c
C ° m
E
c v
d C « ~ a m
y m m ° .a m a
m~ 'v v ~ m t 3 - v v
w° v 3 3 u'^+ vai m .a ca t~
o c `v ° 3 ° a z 3 n
m
u 0 w m Y E N w m w 3
uz v v _ a
W Z o u v°i vai u 2° b m a v
ti w u` ° m y m `w a °m `a v °
c o mE 4E E E E a E O0 E ° m° o
O m " ~'a v `v y _ m c c n v u
Q Vv u' au' 3 y U du mU vU : a =u °z m z u LL 0 0
V Joel 11 U II II II z a
x W
- N
c 0
C O
W y.
O N
n O
Q U
> J
a
v
c
q o
o
v ~
a o
q
V
C
q
C
rl pJ O1 N N n M W n lO M OJ n b n l0 N N fl m .4 O 'I N m m m
N .Mi b N N O,i~ N .ai 4 N O N In+l V N O ti l1pO vQl W~ N
~ lO , N O g p ti 4 6 gN 6 ,4 O Ol m Ol ~ N rl M W h
C ~ V N N O N l0 O l0 m O~ O N Ol O O 'I N rv
O d `y `y l0 N N N '1 N 1D
A 9
b a
K
H N N t/1
m O1 N ~ ~ ~ , , , ~ ~ , m O t0 l0 .i O a0 l0 N m O M N .-1 N n N 10 O N CO n
CI N N Ol m D\ m T N m m O) T W lO W W m O N N
N n n m N n n m N N N n 00 N W R
t ro i0 fq IF M lOO r~ IF tvl N M vl W n .ti Q h Vf Ol l0 W lp
m N M m M m Ol n N N lD n N N 40 OJ
ei '1
O
O
a
5
p v~ .n ~n v~
v rv a m n o p p rv m m rv m m m p N to n N m rv n p n
m p N N m m.+Om OI om mp Nom m to mloOrv m Srv
c rv n m m to o N m m m m m m n lb m n n o p n a N m
O N Ol N N O lO N M M pl N W m pf m N n lD m m W W rl t0 n V1 n
d fl N rl r1 rl 'I Ol m ti N Q m C N l0 lp 0 O~ m N t0 N m m l0 w
q q V1 N O Ol L Q O Ili N l0 N O Ol N l0 O N t0 OI m l°
C a l0 O b lD ~ O lp lO .Oi Ol O ti mi N m N N Ol N V tvi
d
p ~ p p p N H w
N lm0 l0 N l0 l0 Ol N N ti N N N ti N N N N N N O O O O O m m m
H e'I N e-I 'I O l0 m m lp lD m m l0 n N 10 t0 N 10 m m m m O n N
. y. Q.
E viOi o uNi rvr L6 o o 0 vrvi o m r o o O o o O 1 m N
O 'i rl rl 'i 1O N e-I r•1 N N .4 N N l0
d
f
V~ NNN
n 'i W m N R O1 n O m m ~ O ti m m p Ol m m. N Ol o N N m lD N
c ,y ti n e n lop mmmm m.~ orlon .i N m
q O ilj h Ol m m ~ 01 m m ~ p m p al lp m rl N rv N m l0 p
- vl .ti rl tll N ~ 'I tl'i V1 l0 tvf l+l n ~ N ttl h ~ vl tll O1 .i
.i p N N p
o p
u
t/l N N Vl
M m p p
O M n n
D T m N N
In `w E`"R `w E^,~4w E74 w` ENv E^lY
Op c E `v `v c E `v w c E u w E `w `v c E a+ `v
Y
C 'O -y
d G
E ~ o >
N C n n - c q
d 7 E - - - `v
a a ~ w
uu m n m m nor
u a ~ m a v ° 3
d Z c v v ~bo ~o ~o v a
w m a - a a a s v ~o bo ~o Ta m m m m rv v
v c c c p v m a a o- v
0 'S 'o E E E E w` w w w w w v w s s= s >
rv N U E~ U v v vN vU v0 o ao ¢ ~s~e ~ess~eY x 33333 »>yw o §
N p E m E m m9 m
Q V C c o ° o f v« v g q q q q w `v w `w w
u N o o o b ov'~ c c c c o 0 0 0 o w w w w°
c, o Euz> >->_>aa¢aoooooooozz
U w ¢ o
0
m
V
O
a
d
U_
x N
v
c p
a
0 0
a u
~ J
W
~ C
m O
a .y
v ~
d o
ut
m
V
C
A
C
LL
pp pp pp Z_
O . w O
O S 0 0 0 0 0 ~~lf W ti t
A .-I rl rl O .-I rl rl V 'O V V V N VI I V m
- T o 0 0 0 0 0 0 0 0
c ~
o y
n a
u.
I g o g o o g o X X X X 2° X
c o 0 0 o m m o o O a
o o O
0 0 0 0 0 0 0 0 0
rv
0
0
a
5
O
v o 0 0 0 0 ~ 2; ~ ~ a 2° a^ a; ~
m N O O S O S S O O ti N T T N LL
E m ,y ,y p ,y T m ut e
VI ~O I N N N N VI h m
H V Vl N V vl V R m O
N O
C t L'i
y 6
~ N m 0.8880880
O h p p
0 0 14 o 6 0 o m T m VI a vl VI O
E ea a8<<c 0 0 0 0 0 0 0 0 0
O m u
a
v
h
N p
pN O O g S o$ g o d' d° d°. 3° 2° x 9 9 d° e
q C M ON ON rl N p N N ON O O O O O O O O O Ct
~ O N O O O O O O O O O
V
b j
O ~
{9 lOj
H
O
'O U
~ n n n
> o
m o '0 0
c 0
c ~ `0 0 0
a c
Y a n n n
~ C ~ m C C C
d a e0 L Y Y s u Y Y Y w
CI C °1 °o a a n E
m 3 v m n n v
~ m n c ~ °1 ~ E
~ A m 3 s °1 °1 a c c c ~
y .2 m m c ~ ~ 'v c° m a v ~ v a a
w a 'v o m 'Z 3 a o a a c c
~n u - ~ u o T c
m 3 3 h 1", v°1i a me 'Acc u o 0 0
`a `w
m H ¢ E A E w E m U o E w Y c y
" o T E 3" o c rv `w o> c
N o - Q o. m o Y E o o
6 C o auz uz uz uN u3 u_ u
o F U u U P m `O z n z n z n f n 1- n F n F n ¢ n w u
a o u
V W Q 3 Q
O
m
V
O
Q
N
V_
0
X_ N
9
C p
a H
Qn u°
a ~
v
c
a o
a
a p
a o
m
V
C
C
LL?
Y
N O m M m m M M V O V m V
- O O O O O O O O O O O O O
C
O y
m a
N ~
m o 0 0 0 0 0 0 0 0 0 0 0 0
`o
0
a
5
O
m M m o O o N rv N m m m I~ Vl
C w w CO m M O O O O w
d< < 16
vml vml N m vl N O V V vMl OJ
R q
d
a
z
N 'i 'i fi 'i W O] 10 Iq N
o m m m m m m m m m m o
a
E d 0 0 0 0 0 0 0 0 0 0 0 0
0
d
u
a: x a ae x ae ae ae a a ae a a ^
~ rv N m m m rv rv rv m m m m e '
d o 0 O o o O o 0 o O o O o 'i o
0 0 0 0 0 0 0 0 0 0 0 0 0
`w
E „
0 c
u
v
Y
m
C
Y
C 'O
d C
E ~
Y a
~ c
a ~
c a a rv
V p m w m m d m ~ W 00 m d tm0 O
a 2 ` `
W VI N W E 3 C `C d O d O `C ~i N d N d L U
O y o v 3 3 O y o n a- 0 6 0 6 N- 3 `o E
Q {.1 c0 it d0 tO wr W O ~O wr c0 d0 EU
G u o w n n w n w n n n w n n w n w n w n w Z ii
d
V W Q
O
N
U
O
Q
a
x N
v
c p
a 0
a o
a u
> J
a
a
v c
`m o
n-.
a ~
a o
m
c
m
m m m m m m o m m m m m m
0 0 0 0 0 0 0 0 0 0 0 0 o c
c c
o d
A a
h
m m m m m
-E .o m m m m 0 o m m m
m m m m g m o o rv o rv
L a 0 0 0 0 0 0 0 0 0 0 0 0 0
m
o`
0
a
5
O
v d° 0 3° d° 2° 2° d° 3°
m o 0 0 o m O 0 0
0
o o m N o ~o
c e a a a m a N 0 e e N n a
N N N N N N N O N N V lp N ~O
d l0 lO l0 t0 N lD t0 1p l0 V1 N V1 V1
R q
y 6
W
C
O) OI 01 O1 m N N O 01 01 O N N
e a v v o a a o
0 a a m a
E o 0 0
0 0 0 0 0 0 0 0 0 0 0 0
0
v
v
f
q C N N N N al N N O N N O r1 O fl O
- ~ O O O O O O O O O O O O O O
d
E „
o c
m
a
> 3
~ z
m
VI a c_
m c
c ° m
M ~ d ~ m y
c v m ~ 3 LL
v c
a j .v 3 ~ 3 z v
y .0 3 u ~ a m m ~ v
o c v co 3 u `v ~ 3 da t~
~ m E m n ~ v E v w ~w
r+ E j o y v v = v d a°
a 2 gu LmN ~ ~ u f a'^ m ~ d
W 41 d ~ m♦ 00 O ~ d
x ~ µn U ;n ♦ an _ C q h ~ ~ N
d C d y d d d d L C y a
m« w E 4 E L E p E E my E N E d °o i
o v m v o o 0 0 0 w~ o m
t O E_0 " „ d N d N « d V r. C N O W d j
a du' au' vu' vU u' vu' va =u' xz mz LL a
11 0 3 u N N m z 3 m
~ a o
V W Q
N
O
m
V
O
Q
N
U_
O Z
X N
U
C p
v
~ N
4 O
Q V
Appendix E - Cost of Service Expense Allocation
This Appendix details the allocation of forecasted test year expenses to the customer classes based on
the allocators derived in Appendix D.
z
= as"e mQ mxx ~a F? OHS ^g ma s e~
E u $rmn.rv. .°.^^mv ~v rv. n m.. mn ~na a wm „ ° „ n..
Em S. Simnnm6`~^~ m~.Pi"v o~~OO B.
Et ~o~mmP~rvmmmne¢ 68 mm n o -sem
b`
u
« ~.^.mm„nn„m„mxoa n$
m3~amS~xe n.^ Sffi$e ° ..~E m8
Ed ryNtlrm.. fr~~m~rR dAA m n..
f
- mR~6e$mme~m^mm e~ X~•8~88 $8°m°gm6 n ^meo°m'
~ F n rv m
~o
- n~~n6n$Svv N~ Comm $$rem~ n$m
i a
E
n mN On,Qr.. °rv mmmrv m m u m
E°. H.. ..°nm mm ..m m n m mm.m.
b~
3 @ w
S Ex E 338 E
man r~ 3 d3
- 6~~py3ry~gm3ry6 E ~a fm~o~ _
w~W,.~ ~ i m i3HEi 3I333 3 wW Ogg
~ go mA66 88~
m~~°eSm~mmBa^°a ~o ¢•;~^qo 6°.$~m ago
m86$^.'m^9ra~m mm m S° ..m~ ~ n.. m nv..
8 n
e _
H C 9 9
~ n
r ~ ° $ M
m E o
~o a g x
Y ? @' a v o
d 9 ~ E + p 4
0 C o V g » Q 9 ~
w 2 Ey'"y 5 C
F
dx E `^v E»~4•'3 c ° ul E 8e° $ of
p 4 .4 .4 u~i g 9 d "
q u _ o o v o g g E i+~ F Q~ Q Y c` a o m " 2 a't v
o n~~~EEEE~b bz d e': °cE °c E
o j6o o E'VrEd3 r ase„'°imb
Z w » o` o o` - C 8 n E o" o` u' E u 9 v m a 9 r E E 9 g b
uw o` adadadadadoo r eoN „Ef ifd~Y - °a °ao o'dW
a
2
a° 3
i
v~N$ $Sm ~gx~ $9$ e nm °'rv mm m~ ^ta~°¢"" o
'm mix 8 Sq o° ~m 8~.~~ e86.P.^.."
E 2w - n a n m m m
a°a
E
8 - m ry m„"N
Ec' a Con .n+R m m m
v
m _ - _ a n " ~ n
E
$p~ " 8 m.. mn ..nm 3°rmWaB°m
E cm m m " a
b c°
U"q
@ - E E E
Y m ~ $
a ; d s
'm' ziizmi.5 m i z~ i3 i3 z3 ji xF~ m?m
"
e
g f _ -
o ~ o
n ] E E ~ E
O q Q „
E g
w 2 S ~ E E E E E E
q p S 3 A ^ F ' C ° E a w C E$
i t 0 s u E ' r C c m
o s_ J s "Jlu E Er v ~_`o ~ : Vcm o ~ ~F e° o a ggdy dm c3 n
a
w`EEEE"moo
S E y- 8 C C A E a E p E v E: C E E E d v a d ~,y "e E _
25
uw a3 o3ri8=E~ t3 ooNN O`u'ao3E o`dso u'~odod~5 v~oIhg93E
a
Z
a 16
`u `o
<s
a
'gx ~
E m m ~
E t x
u E ~ m
~ i
m m
L p
E
u~ p P
Ei
u~
$ ~
~i m r
E
u ~ ~
E ~
~ ~
U"q
a w
a
Y
Z
3 0
x
8 o N
v
0
a
N
~L 9
E a
Y
'8 ~
v °c
C V
W z c
~ $ E
C o
y V C a a
G E
t. v g 3 a y $
u w a r ~
'a
t
a°~
III
r
sa m~m~ ~ mn m m _ ~ ~ o mn
m& a $ne ^^,n ¢~r$~
aF r r ee nee
o' m
nmm m m m nm A~^8~m asAAm
E r~am~mm.a~amr & sr _ NP S~Rm'"m ns ^mp
$ me a m mm m m mn
z
^
e
~S o%1 e°mSm- rNSS m~ Fs~s ;.ie°m. Ssm a mx^nm
E n m S^ ti v m e n m m n m m m n a m m n
5 E .~n n
g ~
a - EK E E E E E
m3r n3 a, add w
9 2 ~wwwr"rr~rrr i id z3~EZ 3f333 3 W,~w"°~3
ommRm z a a8^^ 60$Ats~ SSA
3 m8~~^~'m^$ry4~m ^°.'aN S° ~A °W~m mn N nen
g n
N b n g
y F F F
Q
° » e u o
p c - u c^^ V ^ y
w z o_ E« ry 4 x ^ = s~~ ~ a ~ ffi
y EVypEc ~ _o N C tf - c
?
7,22,9 a°o o°>» o _ oy¢ `o v qs
9 _ „3=='"3
7 7
u 2' s a» v c $ ^
2E E E o x F E I Ew 6` : aY' s 4 c o m V E e C? 9
° 'e E E E E E
u c c E E E v v E Y Y E u' Y G c d a F L
Z,W ~ wo"o 9 „g9o « ~ ~^~X _ 9 eE E~VOw
V u 0°yyyyanauanan H OGO i NEf H Uv3f UJE F F 66600n
S
a
t
_ o
3
d
i
5
HIM m „3 Am n n e
e9 m _ m rv "
Q= n rv.. o
E ^ r"l Sl S$~ v n v$ n" ~n ..rv rv „"$'"n°v
~ m - _ rv n ti " ^
°03 'ti°ya~ - m^ m,"`°J 8;, ox e~S i=e^o^$me
E ~ v n ni'e~.'o m v n „ tirv rvm .r'.: Ica vmn v ^nm „
S _ r
a>' E E E
N 3 f
S c c I f q Im f m Em °~x 8E~$ w
e °
" iizizi.5 z3 z3 Y.~E$ i22zzz f°
mo oe 8 Ha y2
8
e
N d
N o b e S c
s
C B 3 ul E
i = E
O c aQ ¢ ~ c c
_ O c
w x E E E u e E
°3 v e ~ ~ V EY.v Co$
3 - e ~~y E `YU c `o o .v°.cm' e F a ~ EFZ a?°°'9
seW°EE~Ee~Ez~o"~E„go cwFozo
C o' i F E z u p E S„ 9 n G 2 3 E:_ E 3 r E: v' E C E V z o u v u d u '8 V%
luw o8: a=f: Z~ ~0 6odFo' v3.`- " `r`:~S
~ o`o ~ "3 5, E5 o 9 f
0
a
w 2
a° 3
r=
= x
E ~
u.L e w r
E
f. w
E ~ ~ n ry
g
a
W
s
0
a
e
s
)N
F
m
E u
Y ~
p c
~ 2
- O a' E
~ ~ r c L a $
`o ~ _ yY~ o
V w p p
Q
9
Y ~
a°3
Appendix F - Cost of Service Plant Allocations
This Appendix details the allocation of forecasted test year plant to the customer classes based on the
allocators derived in Appendix D.
N
a a
v
a ~
'V N M d b m Ot n N O M o m m t0 O `
W t N Vl M of y a N N O W Vl M O t0 m VI
d rl 'i ~ N 40 a 1!1 M n 4!1 n O n V
E a .-I w w ~
E m c
C LL
N ?
Y
~ d b Vf w N N N O W o0 tO d 01 Vl
y d VI d rl d at M N N n N M vl n
E o an d m ao m .-I m rv vi
~ q Ol ~ O a N ~ •-1 O N Nw N e -i
e 'i
y C .i
O G
l7
d N VI O M d O b M N m Vl m N m N M
a mn
rvM MO .yo 000 Inn OOn
r Nn utN ut vim nom rvmm
H d N N O .i d O d N d O vl N M .-I
~ m ei 'I M N
6 ~
t
V d
C
m n m n an d m~ m n m o d o O,l
a ~m min Tln m~ Inn .io md~o
y nln vln mo NN lom mm dlon m
~ M d Ol rl 00 Ol ~ W O T m O d tV N
C 6 d N M
w a
0
~ r
m% d b VI N Of d N tD M n M 01 N N
_ W N QI T N V1 N O lU O Ol l0 d l m ,I N
N q M M m N t0 M V1 n D] M al Ifl Ot0 N O N
d L d fl rl lp fl V1 ti b N n M d M
•V 6
C y
C
N
O M 'i 'i n fl lO N n 01 N r1 n O d n
W O I M O M N e4 O1 n m O b Vf O N
y d l0 d o O b d N b 01
t0 L6 rl
CO r4 M n N Vf
E t rI .y n T l0M n T d rl
~ y M rl
d ~
1 m LL
O C
~ N
V V V
N a. H H
O u u u
x x x o x m x
_o v v
22 2 1°. 2r 2.E ~t v w~ a v
H ~
a °uu ua uu^' ua u 22 vt .2
z z z ~n z 3 z 3 z 3 z u'
W O n V1 N n VI o] N M N N n Vl d M
~ tD O b OJ fl b d rl N W d d M O N W
g N M d v •"I M O "'I Vl Ill e-I n M M
QI
O Z N O d q m N N Oy lDg n n m d N d
N ry Ol '4 M t0 01 N M VI N N m m~ N
N p~ rl N N d IO d N Vl n W CO M t!1
7 d ~
g ~
m
c
Y
c a
~ c
~ a
c
Q i d
O c w
u ~ ~ u
u c
u~ c u v ~ 0 0
y 2 m E ~ `a
W d d d ~ Y ~ E,i' y
~ O ~n p LL y ~ ~ C 0
~ I~ c ~ v c a ~ ~ o
m~ o m m E ~ u o w u> G
in ~ a~ o. N y ob E c v c
Q u m UM v i a `w a s c v w° a `w -a `w o o a
O u c a s c 'c° o r m o m m o z m o c o a n o `m v u
u o f E y E a E F E E Z
N a w y u» v~ c v y w a
a+ c w ul c mou ou c ~u oou cou Zhu v x v
u
U W LL O O J N VI d J Val1 J '0 N
c p
~ V
a N
a o
a u
a c
0
v
a ~
a O N m m m Q O n fl n n n m n O t° q 0
~ o mmm~°m~n .ienm m mmQ rv n'^
'u q m m .n Q m m m .n Q N m N n a ~
a d n Q T Ifl Q N e'1 N VI m m n Q 1~ 2 'V
m N N l° l° m m O l0°
E m m Q ~
E m .-i w c
o c
{J N 4L}
Y
~ rl '1 N rl O M I N O rl Q tO rl O rl n
a n M N lz m N N 'i M N m tD m M N M
E m mm QIn min Q m mn Q n
E ~ ^ rim rie .ni m rvmvmi
a ,c m M
'o n
rv m0 n.+nn mne m
m mmn mom O m mmQ .i
m as Qc m rvom rv
a n N 1!1 N N m N O
q N ~ .i N ti
6 q
S ~
C n
J
m mv~m vi~. N.~ of M 800 O
C a m rv m m n a n Q .i O O
a VI n Q n V1 MN m M V1 r1 m Q N M
q N M M Ol ~ N Vl ~ O
N N N
a y
'o
~ H
V1 O N t° M n m M N m Q M VI
a ,y mmo.+ m nm I M mCnm Q
m o m m Nm Q m l° oI° o
t n7 v .ti ni a °i
~ a M M ~n
'c a
J
~ c
H
m o~o~rv~n ~o~nQ m .n ~oQO m
a m m n m m m o m Q N n m
a Nq 'i N M M Q f1 N N m m V1 M m m
c y m m m N
a LL
~ m
O C
V' in
C
O
V a
i c
m m m m m m m m m U n
Z Z Z Z Z Z Z Z Z 3 w
a t0 m Q m O vl N m .i t° Q O N v1 m n
O N O Vl lD N M m N tD n m N O n
O Z a I M m b Q m m m Q n O rl N m
n n O m v1 N O N O d nc .y O 'i m
N q m rv mrv m .y .i .-i ~o O m om m
a m t° N fl M M Vl m m
F Y a n m od
N
m m ~
C O o
C ~
d C G C
E ~ q q
Y a a a
c c q
a ° v
a v J° m
o c _
m
c o E E a o
2 q 6
a d
¢ > N
9 .v! o 'J Q
a q E J o
o w
_m Y 00 v v « a a Q
M c o 071 q.2 3 m
r 0 c cv q._ d. w E a o m
a u c 1` j C Q .°c o c J m uep d 'a.'
O 6 ~o7f JLL oa « Jw c q u_
t'i Ti N as 15 u w E :r c m Z
c 2 o n° E _M « o n " a
U W LL O l:J N O I- VI 10 - 9 u 2 H 3 m w H U N
c O
a „
a N
a o
u
~ C
O
'O 'ate
a ~
`m o
n N
a -
A
d V
C
W W N 01 N m O d' O O n Ol pt r N ~O 'p ~
m .io m.+ mm '+r mN Nr NOJN r E
p aN vv omm rvm n N oN.i ii
q a N N N r'I H N N M N fl rl T
W
m M 1 1 l o M O W Wt W, W
p 00 '1 V t° M 01 ei W N M l0 01 N V ~ CO
p C r1 'i N V N N N N tD r O pl N M
'p L, fi N N N N N N N
J OO
0 r
ry N m N N m 0O r N '1 N O rl M N 01 W
~p N V O rl 0O N W mw N Ol N m W I
C L M m r c of N N M lD W N M 'O O N N
6 r h O m p N pl V N r'I e'1 lp 'i r ti N
9 y T N M M V M Ol b r m e-I N M M v'I
~ tD N V N M N V C N N M
K G
N
E irv vri rvw n °m wm ma vo0im°v .mi
p M a N ~p n m N O oo ~0 0 0 ~p v .y
'a
m c am ma o.-i mN ,tea a N NNm .i
p N rv .r w rv m om mm .+v '+r N N
r'! N rv n r o
4s
com my NN n a nw ma NCO ~o N
.O1-ie NLq ma mm a° aM-i vtOi w
~ 'C r'1 e'I r '1 lD O] ~p r r M NO m m N N rv
o a
ufL
m
V
y w Y H LL
O 3 V U U
x x x o x a x x a
o s ~r v v v aU v v
EO 00 00 N y N .
zz z~ z3 z3 z3 zuJ
CO O r N N r N M N m N N r N V M
ei m NO M O rl ~ M O .N-I ~ N 111 emi ~ m ' m
e-I M O V N M fl N a l0 r r m O] N O
N q m rl rl M ~O m N M O N N N M O V N
a ~p .-I N N R lp V lp N r W OJ M N rl
a ti
~ m z
J
V
N
m
C
C L
d C
E ~ v
~ c E
G ~ a w
O C N a
y
u ~ a `a
m E
d 2 _m E J a
W d d j ~ u O J
N U
O m O LL 'p j C C
C O 0 m Loo O" m ° O N U T ~
m va'i .N n a E ri ~ y N E o v u
U = O O c~ J `a a `w ~ ar W~ N d c O ~
a u c d w cc E o c E° c E° c E c E c E a Q
. d a o E a~ E o a E° v' E U F E0 _0 E -v' v c
a» a a c a~ a a~ a0
d p d, 'n ~ n O U ❑ V C ~ U o O V c ~ U Z p V v ~
U W u O Q ~ t%1 'n 6 O U ~ Va1 ~ ~
V_
LL Z
x N
U
~ O
n 0
n O
Q V
c
n o
a
a
o
O_ N
Ul -
~ R
LL V
C
R M M 41 .Ni Ot N c0 O O1 N m b 0N N W R
A d O M O d d d N Ot m n O m
CR t M N d N V1 .Mi N ~M N b LL
R a0 O m t+l
ip D_ N M M _
W
N K ~
W n O M M N N b N '1 ll1 M N n rl
p pp 111 lp N n m m N M M d M N l0
C W M M % n M Ol N O
00~ e~i e1 ~ N
Q J
R N O 01 N v1 10 c0 111 N N .i O 01 O O
R o co co m~Mmnd rv rv d NO rv
G ,C Ih VI O Ol O N M Ot M N W m n W lO w
6 yj Vj p 1p n n N n y O M N l IO0
9 N m fi n N n O Ini1 ON N V O
R C d d N
S
N
Ot n V1 n W N N N N N l0 V1 ~ d n N
£ M rl 111 N n N d V1 M n O 1- O1
R n fl Vl fl Vl V1 N 111 O N n
N M d "'I N M n
m m m
a
r
E L M M Ol l0 N N l0 ~ 10 ei Ot N d o rl N
.V O N m vl m b m Ol Ol vt vl d
m .i .i d n d N M
`R ~ of ai o
c c
v c°~
n Ol N.' d N N l d N MIS g m mm Nr balmoNm o o
N
o m n b M n rv M to m ro m
0o m ~ m ~ .i .ti fi ri vi of ro ni
`w y o d N b b m m
E R o o
u ~
r
d
LL
C
O
N y
O d C
m m m m m m m m m
zzzzzzzzz 31„
b mdrooNNm.-+b c} o NN W n
a O d N O N ID N M M N l0 n W N O n
1'•1 W N d M Ol b d 4 N O Ol d lD n O rl N 11
0 zNn nOOl g N N n NO '1 M6
N R W N m N m 'i rl 'i ~ d Ol O O1 m
b m lp rl ei M O M V1 W O1
F y n W c0
N
> a ~
3 r
V
pp R R
C O O
- r r
C ~
d C c L
E " R
Y ~ n a
R ~ 0 10
a ~ d
N D a w
O c _
u m i2 c
u c o E E w
a Z R R d _ E
W 61 4 O S d R C 4
c o c s E o w n
o m- d l7~ C c q w R
- ~ a c v
t0 c cam«o o.~w'o
16E no m u
N R 0 6 O
V - O L m a _
C V o ° W ~LL a`„vti 0'w m
-6 E
V W I L O 9 N O r N r V r 3 d l u r a
W
V_
LL Z
X N
D
L p
d y
d N
a o
u
Appendix G - Unbundled Cost Breakdown
This Appendix details the unbundled costs derived from allocation of expenses and plant to
functionalized unbundling allocator and sub-allocators.
0
v~
do
z
_2 as ~o g"' eo °o m~
E m3 0o do 0o dd n do -.~ddrtiv
° N o
n o m e e ry y P
ea nno S
rv E o 0 0 0 0 0 0 0 0 o m m N v rv °m r
u c
0o mo 0o n o0mnmm.+v~m
~i 3 0 0 00 0o m
F ma e m a..
E' o m o e o m o n o o n m m v e m
E i 3 o'.d d 6 6 0 od 'o N .n:o
o `
m r
ma mo r rm n°.n ~ m~°.~^
' S oo na mn m
0 00 0 0 o n dd .+wd d~ U,'
A3 ~Q
f
a
n °m o e m a m m a m ~ o m
- mo °moo wo n ao mnn.+~rm~v
00 00
oo do mdom..oo
v of 3
N
pp O
C
y ~ c O
E ~ J
Y a
C ~ - q
p C V U
m J
Nr p V - ~.V NU E'o ~U
t p ° s v . . . c v a v ~
s
E E s E u ° E t s E E E t o n c° u c.N o
e - `
3
0
m`
0
V
V' a
x w
6 v
c c
v o
na
n c
J
>j
a
v
a` N
m„m
u i " m ^ 8
O m w
E Y•3 nrvcm„ mm ti
m o m m m a k a
E L y °N, n; m
`w E ~ o m a s o
a a ti ~
d
A 3 m m N
fa mNm o0
E a.3 mrvo mm S
E d
i u
m m m m ° °°o
C N m m N
m~ b rv OO rv V V U
ni3
f
e
o
n m e m
_ 0 0
n n o m m
a E ' 3
o Yn
N
C l'1
d C ~ A q
Y y J o 0
d C =
~ = m m
d 9
~ q J
d
. N
C O
c p u a„ E o °
U 7
E on z u
19
U W J n J
3
O
W
0
O
U
l7 a
9 ~
d J
na
n C
Q J
J
a'
^9' c
A o
L N
^'o om o,mi o M$~~mm
e $
v` 3 0 6 0 0 0 0 0 0 0 0 o m o 0 0 0 0
c mg; v o m $ar
3 ° o 0
d o o m o0 0o m m
O m ne °m u`~i $o °rv
S °o o °a o °0 0
u 3 0 0 0 o a o 0 0 0 0 o m o 0 0« o o
c F Y
~ °oo o mm~
u 3 d o 0 0 o a o 0 o d o n n
r J° ti rv e °a
o om o0 oM :.°.m a ma°n
~ 0 0 0 0 0 0
u m m W q ,my m m O ~n N N r
eo ~o $m ro`o„°
E w l
0 0 0 o d o o d rv o rv m m c m m
E
e c E e
m
E
n m c
~ = a
v v u o
p m me u
= m 3 ~ = = = u
Z
E E
u
w m` - - o E
q o - - - 2
S ° U
s 0 n n ° y c I v
3 c S °c G- S « 3 5 00- u E
w ° 'E E o w o w E o w E o w a ac ` o w 'o S E E 'm ~ ii
3
0
m`
0
U' v
x v
o a
~ c
nn'
n c
a ~
J
a
~ o
n 'a
a ~
d o
l
timon°n
93 00000 mm m
„ m Y
c ~ o o n m m
c °o °o
O O Y
o no no °
e.3 odddo rr n
m n Y
~3 ogg$o
g `o m r
a o 0 0 0
E O r ~
V a
E° 3 d r d m N N a
E w.
o €
O C j L°
r a 5
a-v
Q q J
Y a
N z ~
W
C O
R r V c ~ C
_ ° rJ n' 'E o 2
d '„mOO e~Pn ~ 3
u w ~ o J
3
0
a
v
0
u
c~ a
°c v
nn'
any
Appendix H - Rate Design
This Appendix details the rates for the test year for major customer classes (incomplete until after draft
finalized and rate discussions with utility).
CITY OF
ASHLAND
Council Communication
December 16, 2013, Study Session
Discussion of Ordinance Updates: City Council Rules (Chapter 2.04), Boards and
Commissions Rules and Procedures (Chapter 2.10),
and Miscellaneous Chapters (2.18 and 2.28)
FROM:
David H. Lohman, City Attorney, lohmand@ashland.or.us
SUMMARY
This item is for the Council to consider ordinance amendments to effect changes previously discussed
in concept to City code chapters on Council meeting procedures and on Boards and Commissions. The
proposed amendments in those chapters also include some suggested modifications the Council has not
previously discussed but which are intended to clarify procedural questions that have arisen in the
recent past. Finally, a few updates in the descriptions of the functions of City departments are
proposed.
BACKGROUND AND POLICY IMPLICATIONS:
At several meetings over the past year, Council has discussed various conceptual changes to the
procedural rules for Council meetings and to the policies and operating procedures for advisory bodies.
Attached Exhibits A and B show ordinance amendments that would effect those previously-discussed
conceptual changes. In addition, in Exhibit A, the City Attorney has proposed some clarifications and
additions to the Rules of City Council in AMC 2.04. While most of these proposed changes to the
Rules of City Council have not been discussed with the Council recently, they are intended to address
actual procedural questions and problems the Council has wrestled with in the eighteen months or so.
Revisions of these rules should streamline meetings by reducing procedural ambiguities and aligning
expectations about the conduct of meetings.
One significant proposed change is in the rules for study sessions. Study sessions are creatures of local
law. Nothing in state public meetings law precludes the Council from taking any actions in study
sessions that would be permissible in other public meetings. Under the proposal, shown in Section
2.04.020C of Exhibit A, the ambiguous term "deliberate towards a decision" is replaced with more
concrete terms describing actions that can and cannot occur in study sessions. One new type of action
that could occur under the proposed amendment is making a clear decision by means of a vote on
instructions to staff, on concepts to be presented in written form to Council at subsequent meetings,
and on procedural matters.
Another significant proposed change is the recommended codification of motion practice. Robert's.
Rules of Order has been the source of rules for the conduct of Council meetings, except for a few
provisions already set forth in AMC 2.04. For the most part, motion practice has been left to Robert's
Pagel of 2
r,
CITY OF
-ASHLAND
Rules. The motion practice outlined in Robert's Rules was designed for large assemblies that meet
only periodically. Because they try to address every eventuality Robert's Rules can be cumbersome.
The amendments on Council Deliberations in proposed AMC 2.04.040D(5) of Exhibit A are an
attempt to distill the essential parliamentary tools for handling Council business into a readily
accessible, abridged motion practice framework. The abridgement results in a few deviations from
Robert's Rules that may require some mental adjustment. But the reduced complexity should produce
greater clarity. Some parliamentary procedures not covered in the proposed ordinance still would be
governed by Robert's Rules. The expectation is that they would be invoked only rarely.
Exhibit B displays proposed amendments to parts of AMC 2.10, Uniform Policies and Operating
Procedures for Advisory Commissions and Boards. For the most part, these amendments have been
tentatively endorsed in concept in previous study sessions. The middle part of revised Section
2.10.020, however, addresses for the first time the possibility of allowing an alternate when a member
who represents another entity is not able to attend a meeting. Also, the last part of Section 2.10.040 in
Exhibit B has not been discussed previously. It attempts to clarify how advisory bodies should handle
scheduled meetings when a quorum is lacking.
Exhibit C merely updates a few code provisions on the Conservation Commission and on City
department functions to reflect real world changes that have occurred already.
More housekeeping updates to code provisions will be presented for Council consideration in the
coming months.
NOTE: To provide better legislative context for considering these amendments, they are shown in
Microsoft "Track Changes" format rather than traditional ordinance amendment format. The
traditional format will be used when the agreed-upon amendments are brought before a regular
meeting for formal adoption. Exhibit A displays all of Chapter 2.04, with amendments indicated.
Exhibits B and C display only the portions of Chapters 2.10, 2.18, and 2.28 proposed for amendment.
FISCAL IMPLICATIONS:
N/A
STAFF RECOMMENDATION AND REQUESTED ACTION:
N/A. Staff seeks confirmation that the proposed ordinance amendments reflect Council's intent.
SUGGESTED MOTION:
N/A
ATTACHMENTS:
• Exhibit A: Proposed Amendments to Provisions of Rules of City Council (Chapter 2.04);
• Exhibit B: Proposed Amendments to Provisions of Uniform Policies and Operating
Procedures of Advisory Commissions and Boards (Chapter 2.10)
• Exhibit C: Proposed Amendments to Provisions on Conservation Commission Staff
Liaison and Miscellaneous Department Functions
Page 2 of 2
PI
1,711
EXHIBIT A f
I
PROPOSED AMENDMENTS TO PROVISIONS OF:
I
RULES OF CITY COUNCIL
Section 2.04.010 Authority 6
A. Oregon Revised Statutes, the Municipal Charter of the City, 14iele `r>~.~.,~.--.o.;~a,e°- 3, j
and the Ashland Municipal Code as well as the Otegan Revised-&taiut~govems many
the meeting requirements and actions of the Council • -
B. These operating policies and procedures are established and adopted under the
authority granted in the Ashland City Charter, Article VIII, Section 3. j ,
1
C ~2o°'ber`ts" Rules of Order Newly-Revts%dr}liall be the author ti y for decldme aany
guesdons.on meetin~r`eyuirerrients a'"`nd actluns'not covered by 'the riles "in t`p~%1C 2 04 0~ (
Oregon S[a[utesj orv n nt'[1
iao2ox .a
D. b''ailure<to strictlv5fdllo'w'the riles m'AMC•'2:04+orRobert=s~Rules'fNewlv,Revised
x ..3 - ~-w saa.
shall'nobbe.cause to void or othenvlsedlsturb a declswn or ac[ion'of [he Council. ta.~ ~t [~7,ym s,m eeman part of cu,rem AMG2 W o2- mikes C 1i'o~ --1-Roy,
I 1 ( thf
l CI•he'rulis on meeting7procedures in AMCa2T04'020C2 04 040C r2'04'OSOE and ! ~x be i a weaj ILm'msr btdTinNRobert:sdRulei:Newly Revised may be"suspended temgotantyupon
-a motion. t;
th'atYis seconded ar;~°`idtpassedabv a two-tfiii Ts vot~io'Ifavov ..A mottb'°Sn ioaus°ond4ihese j
rules!is"1notPdebatablc oar a'mendable] Charter Provisions may be suspended or repealed / mx~tt[13]m P .a~ smc]Mty
only by a vote of the people ' 'b~ '°~'~"'a ' 8pfO`~1P°
esubl shed bYO"then Im ch
M171 hm ro hsuspmded M. Iu,dre-
.a"n. - - --.ma- sw J,an ame7 xoben sxW s
b''Ille'IIy~A[[o_amey'CrIS..dcsenzte8`s'astoarliuinentanan~-for_theCouncil"Council
meme°mbers' reg~ uest NOR i'nfortnaiion.on=.meenne""~r auirem ent s'or:nosslbleTCounci1 ractions
m°nvib fer?ed. tto heTCrty k(t me' tlirough thelpre`sldme officer for~inlerpretation !
pfteulaki`n°eTintoaccoun aanv.obin°io' of•`the`"'.City.A"°ttlornev3lhe?Tresi'dineofficeumust=rule "
onMo bout•meetinquiremen"ts o-" possib'I'e~Council dactions: A Tulin f4- e
presiding-"rg 'o'fficer may =.be ?challenged by."a+`uoin"t of ordei gas 'iset forth 'iMmG
2 04 040IN3WIN
! wtuneni [w]~ 'est "!m E4 »,m so,rc
clenfcm' ,oro I'"GL W.020L
Section 2.04.020 Meetings 'i
A. Regular Meetings. 1
The regular sessions of the Council are on the first and third Tuesday of each month unless ~I
otherwise arranged, beginning at 7:00 p.m. Meetings are required to end no later than 10:30
p.m.
B. Special Meetings.
A special meeting may be called either by the Mayor or two members of the Council. Notice
of the time and place of such special meeting and the subjects to be acted upon shall be
delivered to all members of the Council at least 36 hours in advance of the time of the
.
Page 1 of 18 '
EXHIBIT A -
meeting, except in the case of an emergency, and the Council may consider and act only
upon such matters as contained in the notice.
C. Study Sessions.
The Mayef of litive members of the Conrad may call a study session at any time virith 36 hou
nalliee for the purpose ofirilmigning members of the Glaffff~affiii
Study sessions are held s8 that Get-thail -HR aeffilletivItith ffiffilfand other expials an itaffle; 41"alpF
~ewafds a deeision but can give staff diFeetian to pFepaFe iffittaiiials for a regular Council
The Mayor or two Councilors may-cal I a study session 'at-an y time with 36-hour notice. The,
purpose of study sessions is for Council members to receive background information and f
'recommendations from staff or invitees with expertise on City business and to give Council, ° -
'on an opportunity to ask questions, discuss options, and express their individual views 4
on matters. Council members may also vote in study sessions concerning instructions to be
given to staff, concepts to be presented to Council at subsequent meetings in the form of _
specific written proposals for adoption, and non-substantive matters on which Council action
by resolution or ordinance is not necessary. Otherwise, no votes may be taken at study,
sessions absent a suspension of these rules. No particular cases involving guasijudicial
'decisions maybe discussed at study sessions , comment ttsl:
•-The tann',at." is used instead of 'official
t action' 'final death or'final actloni avoid
D. Executive Sessions. ! definidonalcueshore.
All meetings of the City Council shall be held in open sessions, except meetings that The tertn'deliberete towards a deasion' is
eliminated to reduce ambiguity. Instead,
may be closed for those purposes specified in the Oregon Public Meetings law (ORS concrete actions; that are allowed or disallowed!
192.610 to 192.690). These purposes include, but are not limited to, the employment and are specified.
*The proposed limits on study sessions are
dismissal of public employees, the performance evaluation of the City Administrator and arguably still more restrictive man me limits on
City Attorney, labor negotiations, real property transaction negotiations, and consulting executive sessions: Oregon's Attorney General
has said a governing body In executive session
with legal counsel on pending or threatened litigation. -Any Councilors who de-net may informally decide or reach a consensus.
feels that an item should not be in executive session "___.r. This is proper so long as the body goes Into
public session to act tormally on the matter.'
kession may state a point of order which shall be doled upon in the executive session as .only votes an limited types of masers would be
votes on
set forth in AMC 2.04.0401)(5)(c)(1). any allowed at matters are study permissible ven trough under the state
open maedngs law at any duly noticed meeting
2 Notice of executive sessions shall be given as required by State law, and such notice Win a Q10um.
1 •A vote on a matter still barred by this provision
must state the specific provision of law authorizing the session. The Mayor and City could he taken at a study season, upon
roes.
Council
Councilors will act in accordance with State law regarding confidentiality of information t tempussionat s studona orme
• reser ed tudysessions s would would continue to
dISWSSed in executive sessions. ad e reeerfaminfor e Council members, staff, and
speafic invitees.
3. At the commencement of each executive session, the presiding officer must state on CommentpBII The current version does not
note clear now to motive differing views on
the record that executive session information is confidential and may not be reported. 9 ,.mether the sent should be adaesnea to e.e.mive
s' does not so sj fT Me proceedings may be reported if no such statement is made. oration In os,ondmg 1. . 61 ofor&, order the
prop.srd reviswn, the presiding officer and
Councilors now take into account legal analysis by
E. Notice of Meetings. the city Attume,, and policy mnsideratiom.
Advance notice of at least 36 hours shall be provided for all meetings. Notice shall be sent to
a newspaper with general local circulation and posted prominently on the City's Web site. In
i
Page 2 of 18 _
~ i
i
EXHIBIT A
the case of an emergency or when a state of emergency has been declared, public notice
appropriate to the circumstances shall be provided and reasons justifying the lack of 36-hour
notice shall be included in the minutes of such meeting.
HJOTE: TI IF STRIKETHROUGHS OF SUBSECTIONS P. G. I. J. AND K B@LOW DO
NOT INDICATE DELETION. REVISED VERSION OFTHESE SUBSECTIONS HAVE
BEEN RELOCATED TO AMC 2.04.010 WHICH IS A13OUT THE CONDUCT OF
MEETINGS AND IS THEREFORE PROBABLY A MORE APPROPRIATE PLACE FOR -
THEM. , j
IA i,i,.d T. er.: ii1i1 c,.,.r,... rl..... ,....1.., May of and not less .1.....1._.,., f
r
_ f _ r.. simple MajeFity ..f .L.. quefle
'n ...r...... frog t•• third..Note of the r.. ne I as provided in the r:.. r1.°_.°_ there
--fed an affi~ati%,e vete of at least four Couneilam to &Eafeise any sash speeia
tt.. rl, :L_ r_..__a,.__ _tteadainee may d:___. .he ru_f of n_r.__ to flotify .L_`
e .
........L ...,........these known to be na oid°1.. detained, that thei 1
feqHiFed to enable the Ceene 1 to pmeeed YAth business. Should any then fail s8en te appe
i f
i
!he members present sha I!ooffl Commen[[tl]: maKdwnn+cz.a.moa,..,m
m
mrrew;siom.
,
and request Lie Mayor to eall a speeial
:.......:_....f.L.. r...._..:I .._d.._ to _ iif. the deel.._...:.._ of The speeial meetinj
eommentusl:move wA tc2.W.010B,wnh
mr revision.
Rolls"_, o..l°° °fn_d°' shall be the °...1.....:.. O._ .L,. ....yeniment of the n....neil d.._:..._ F
sessions, when not in eenfliet with the Gity Chas4ef nfld thpsp Ped- -
J., _ra._ r.....,: 1
_ The n ,...__:1 ..:n L.. Comment [197: Replaced by 20C.010C e1M D.
1
i
I
Page 3 of 18
i
1.
I
EXHIBIT A j
.uy
the Mayof ar my meHibef ealk for a roll call %,me, then each membe most N'
'noel. vote ...Le efe. e_a .Le.. '.va Comment [110]: MovW W AMC
lA -_H -ma;i4'-7a eon be made a9ly anee and at the session at : matter was adopted~ of at the next tegular meeting af the CaNneil, pfavided that He -Hti, 4
, _
fl_a _a. ,._,..L.._.__ _ _~t L~-___-f't•_~e ~ _I_~ Comment [Ill]: M1fovxd to AMC
2M.Ot0O("!)(a), wish ron-sub5lanliw clarificetio~u'.
I^~ a . ..f M1.e A.Ie. f Of presidi g eMee.. I. a .L°. °°°L n _.L.... Lee J'° '
L...,..nu~
__,Le_ . ,.....e e.... eeogi,i:cv
L raoaio,w,.
""'vmoG_rtshall
I°YY°..°...y 'z' v ~cc
should ~ evi'e the Mayor to a. No m
,peak aFe ..en epee until every member eLeee to speak shell have . ..:...a
. Le of '
f6o:~:oL. .e ae a Tle belF shell a eeh... 9-1 niel'HH an the ns.._ e, e
-ffi-eep~ / Commentl1121:Movdio AMC2.01.010D(2)
jgeumeil _ /CMm M[I33]:Twsublalivelobe
enforceable
Eeer .
q MR.,
_ _ _ __e,- _ / Comment [1141: This o unnecessar
fthe r~_?m Comm nt[1151: Amodifiedversionofthis
t w 1, pare b has Wen moved b AMC
4.e. Cit is a...: e...,1 a e n 0.` the /`e....1 Questions of
parliamentary rules may be refe~d to the City dkt
[136]: Thisprmisbn isryoposed to be
4he final i =n2
- - - m AMC 61.010 and modified slightly.
Section 2.04.030 Agendas
The City Administrator is responsible for the preparation of the Council agenda.
A. Topics will be added to a Council agenda based on timeliness of the topic and with
consideration of the number of items already scheduled for the Council. Matters to be
considered by the Council shall be placed on an agenda to be prepared by the City
Administrator from the following:
1. All items considered by the Council during study sessions, which require °f`°o..,~,g-a-.,e.-
f em "„~.,e the Get.„e.^e -ei ..a Council vote.
2. All items which are required by law or policy to be presented to the Council.
3. All other items that the City Administrator, City Attorney or Mayor present to the
Council for action.
4. Items placed on the agenda'in accordance with paragraphs B and C ofthis Section.
5. Requests of City Boards, Commissions, and Committees.
k
Page 4 of I8
}
EXHIBIT A
i
r
B. A Councilor may request that an item prior to initial Council discussion, that does not
involve staff time, policy research, or drafting of an ordinance, be placed on the Council's
agenda. The Councilor shall notify the City Administrator no later than noon of the
Wednesday prior to the Council meeting. The City Administrator shall determine the order l
of business of the item. The City Administrator may request that the matter be deferred until
a later meeting if the agenda of a particular meeting is already lengthy. Council members i
will endeavor to have subjects and any materials they wish considered submitted prior to
finalization of the Council packet.
C. A Councilor who desires major policy research and discussion or drafting of an ordinance
should first raise the issue at a regular meeting under Other Business from Council members
-
or at a study session prior to more than two hours of any staff time being spent on the issue.
The Councilor may also request that the discussion of this item be formally placed on the
agenda in accordance with paragraph B of this Section. The Council should consider items
in light of City priorities, including adopted City Council Goals, and workload. The Council
must agree to proceed with an issue or ordinance before staff time is spent preparing the
matter for Council action. The Councilor may present information or a position paper or ask "
for a department report or committee recommendation. Councilors who agree that staff time
can be spent on a particular item are not bound to support the issue when it comes before the
Council for a vote.
D. During a meeting. Arty A topic may be added to ert-the agenda by a majority vote of the
Councilors present. Generally these items should be limited to items of timeliness or f
emergencies. Advance notice of executive sessions, however, must be given as required by
State law.
E. Postponing Agenda Items Before Consideration.
1. If a Councilor will be absent from an upcoming regular meeting, the Councilor may
request during a regular meeting that consideration of an agenda item be postponed to a
future regular meeting. The request will be honored if the majority of the Council votes
in favor of postponement and the matter is not time-sensitive.
2. If the request to postpone is made outside a regular Council meeting the Councilor
requesting the postponement shall submit a request to the Mayor or City Administrator in
writing or by email as early as possible. The request to postpone will be honored unless
the majority of the Council at the public meeting votes not to postpone the item or if the
matter is time-sensitive. °
3. If time expires before the City Council can consider an item on the agenda including an l
advertised item, the unaddressed item shall automatically be continued to the next i
regularly scheduled meeting of the Council; re-advertisement shall not be required for
such continued items. A note shall be placed on the Agenda referencing this continuance
rule: `Items on the Agenda not considered due to time constraints are automatically
continued to the next regularly scheduled Council meeting. AMC 20.40.030.E.°
F. Council Packets.
Written materials, from Councilors, staff and citizens, which are related to agenda items to be
included in the Council packet, must be submitted to the City Administrator's office no later
I
Page 5 of 18
i
I
EXHIBIT A
than 12:00 noon six days in advance of the Council meeting for which it is intended.
Materials submitted must include author's name and address.
G. Study Session Agenda Preparation.
The City Administrator prepares the agenda for the study sessions from:
1. Items requested by the Mayor and members of the Council to be listed on the agenda.
2. Items deemed appropriate by the City Administrator.
3. Business from the Council pertaining to committee reports and other business.
4. Items requested by City Commissions, Committees or Boards.
Items appearing on the Council study session agenda shall be assigned a time limit and the
Mayor shall hold discussion to within the time frame, unless the consensus of the Council is
to extend the time limit until an issue or item is discussed and resolved.
Section 2.04.040 Conduct of Meetings
A. Ouorum.
[A'ider dfintAmc`Iei1 IIUSecIion 4`ofihe Citw_Chart er tourCoonctlors.`or the=K19Lor. and
names' s.tha'thr°ee'4Coun'ilois consti0 -a -,-6 im If the Council
constitute. a quorum. the iiembers'ipresentfmav=adioum or a~' zjonKVU-,-t mb'iOin
altendan ee.mav direcl`the-Chref of Pohce to notify the absent membcn; except 1}iose known
to be unavoidaFilvde[ainedthet their~`pr`esence is=iequired to enable thc'Couhcil"to`oroceed
iilh;business'. Comment [IV]sThµ reroc~6°e~d'fraomA
2 OJ 6.r.d modifN sl ghay.
B. Emergency Meeting Procedures and Ouomm. -
The City Administrator is responsible for implementation of the Emergency Management
Plan. When the City Administrator determines that a state of emergency exists, the s
administrator will make a declaration to that effect and request the Mayor to call a special
meeting of the Council in order to ratify the declaration of emergency. The special meeting
of the Council will occur as soon as possible after the declaration of a state of emergency. A
quomm of the Council may not be possible due to emergency circumstances and is not
required for the special meeting. Notice of the special meeting can be made in the most
expedient manner determined by the Mayor and need not be 36 hours in advance, but notice
of the emergency special meeting must be with at least 24-hour advance notice if feasible
and, in case, minutes of the meeting must meet the requirements of ORS 192.640(3) and
192.650.
C. IAtt ne dance"bv=+ Electroniccommume`aiion
Except in th'eW'event'of^asuspenshon of•nile's~pursuanilto AMC-=2.04.OIOBv+nhembeis of the
@it'ySGouncilIn-MYanoffaltend1-6ruvole¢atTpubbc.inectings by vmeahswofa"feleohonc..or% lhen °r
ee°lectron c c°` commumcation The Pules-,Ww7meetin~pmcedures and'iCouncil wns'ahall i
otherwise rematm°hn'teffecpd6f%'vit6s[andmg"f'siiy'h'such suspension of rules to" allow for '
attndance`6electronic'communicati6n. I eommeni`[na] v~ovo_. smom
rg~g
is clenN turdl S,vfraq ats for `
r P
GD. Council Deliberation. s ^ ^~=e.M.co <i.m<nrn.
1. Presiding Officer. The Mayor, or in die Mayor's absence, the Chair of the Council, shall
preside-be the presiding officer at the meetings of the City Council. In the absence of these j
Page 6 of 18 '
EXHIBIT A
f
officers at any meeting, the Councilors present shall appoint a Chair Pro-Tern and proceed
with the meeting. The Chair, e eept the Mfi ff may vate on al m ^.1..,_ The
presiding officer may not vote on appeals from decisions made while acting as presiding
officer. The Chair may vote on all other motions, but the Mayor may vote only as Provided
in City Charter Article 4. Section 3
2.. Councilor Remarks... It is the duly of the presiding officer to ensure that each Council
member has the onnortunity to sneak. Councilors should ask the presiding officer to be
recognized. No member shall speak more than once until every member choosing to sneak
shall have spoken or waived the right to do so. No member shall sneak 6vi6' on''a motion mi ![hc,tlooi withoutaca've of:--ihe Presiding -'officer. Time limits may be set on topics
by the colnn+ene (u9l .ova co~dl~.Vw"`"~`s a. ~ms't
Presiding officer or by a consensus of the Council. I alli nss „oe ne<M'Irr<vr 1 a a I nne`;~'.
tut co vl U, s g,>
3. Subiect Matter. Council members, as well as members of the public speaking on Council
agenda items, shall confine their remarks to the question under deliberation, speak only for
themselves, and make no negative personal remarks or comments about the motives or
personal traits of others.
4. Decorum. the
presiding officer shall be r+esponslble for enstinhgkordei and tlecomm Is
maintained Gwed>;.no ka a " _ ti"^~ia"7i.',at+,l,l a i;.td4cr'""'vv'w',tl, a 'a
a• ..............a .ti^~...a'"~?m,.,._ ..o~s."~r,:'~'G„aTPYCF's.ars3,5'i• g~r&" r;~..$~(?8S_ ,1 ~
a. ~W'~s~-rA «nbtke i c-'m rlu-s- k~'ti~
•~~vB yr Anv Person s fature4o~abide
6y the prewngkofficers nsWCUOns con s[nutes,dlsmpr0ngofya la~`vful rise-mbly~as
provided m ORSSI66 025(l)(c) and may Elie cause for+the ores &'6fficer or.a malorlty of
lfie Councilors4to daect~agCltv`BOfficlal to.zremove [he person from'Sacc ouncd4mccunet !
Dlsruphve46ef~la fmclndR'6figagmgyi vlent or~,d(stracung `actlont making loud or
ism live noise orru~singryloud or d profane-language "~ma6lne negative nersoFal
re marks.or.commcnts abodr.[he motives or Personal trans o(olherssand refusing-`to,obey an i
older of~tfie pivdmg office 'Sign's'arenot per'nitted and will tietconsldered dis'rpptive.L Comment lt~oTy'lnevrvosea ~nanBa ere
direction or order of the Presiding officer may be challen ed by a Dint of order as set forth a am nr n in nu~ryb1a>_age
€ P a"-P r mn~ nrilAI a sc wci
in AMC 2.04.0401)(5)(c)(1).
xm~ ai vc y~ycvWe_i..
be s naveaa opponwily to rhallrngea
AMa . t'li o~-fimeiia*t aft a .-1 a mcr earns m m mot w..~lm
5. Motions and Permissible Intervening Actions xn-"'-p1
1 eommenl gz1.) M'ovW to K_I.
a. Councilor Actions During Debate No motion or intervening action shall be received
or recognized by the oresidine officer when a oucstion is under debate, except for the
following secondary motions and intervening actions:
(1) Point of order, request for information, or obiection to consideration ofa
matter
(2) Withdrawal of a motion
(3) Motion to lay the matter on the table I
(3) Motion to divide a motion under debate r
(4) Motion to refer E
(5) Motion to call for the previous question
Page 7 of 18
i
EXHIBIT A
i
(G) Motion to postpone to a certain time
(7) Motion to amend
b. Priorities. The disposition of on any action listed in AMC 2.04.040D(5)(a) must occur ,
before consideration of any other action lower on the list 9 "
c. Permissible Intervening Actions While a Speaker Has the Floor
(H Point of Order. Any member may interrupt a sneaker who has the floor to
raise a point of order if meeting, procedure rules appear to have been broken The
speaker must immediately cease sneaking, and the issue identified in the point of
order must be resolved before business continues. No second is required, and no
debate is allowed on the point of order. The presiding officer may seek -
clarification on the point of order from its maker or from the speaker who had the
floor when it was made. Before proceeding further, the presiding officer must
sustain or overrule the point of order or submit it to Council decision by maiority
vole with no debate A member who disagrees with the presiding officer's ruling
ona point of order may move immediately following the ruling to overturn it,..
The motion to overturn a ruling on a point of order may not be debated, and the -
presiding officer may not vote on it. Approval of the motion requires a majority
of affirmative votes the motion fails in the event of a tie vote
(22) Request for Information. Any member may interrupt a speaker who has the
floor to seek permission to make a request for information from the speaker or
from staff or invitees with expertise on the subject under discussion The request
must be addressed to the presiding officer and may not be addressed directly to
the speaker. The information sought must concern either the subiect under
discussion or meeting procedure rules. The presiding officer may ask the
requestor for a statement of the nature of the information sought A request for
information must not contain statements of fact unless lhev are necessary to ake
m
the request intelligible and must not contain arguments Upon inquiry from the
presiding officer, the person who had the floor when the request for information
was made shall decide whether to decline the proposed interruption to allow the
requested information to be provided j ,
(33) Obiection to Consideration of a Mailer. A member who contends a matter
about to be discussed is irrelevant or for anv other reason not advisable to
consider. maw object to consideration of the matter. The objection may be made
before or after another member has been assigned the floor, but only if debate has
not yet begun and none of the motions in AMC 2 04 040D(5)(a) has been made -
An objection to consideration of a matter does not require a second and is not
debatable or amendable. Immediately after the objection is made, a vote on
sustaining the objection must be taken The obiection fails unless at least two-
thirds of the Councilors present vote to sustain it
d. Main Motion. A main motion is a oronosed action that brines business before the
Council when no other motion is pending. The actions listed in AMC 2.04,0401)(5)(a)
Page 8 of 18
i
I
EXHIBIT A
may be undertaken while the main motion is pending and, if passed, may affect the
Council's consideration of the main motion. A main motion requires a second, is
amendable and debatable. and passes upon a majority vote in favor.
e Withdrawal 1l motion may be withdrawn by=the mos,er zt anv iime before an' -
amendment is made to it or, if no amendment is made. before a vole is taken on it) /Comment ~!zzI wposs.,fd',.,mrav.
v ion a ! r i
pt ~G:uWly d smut `Yd, nb
wa wn!a~ m ! tp am '
f Motion to Lay a Matter on the fable. A motion to lay a matter on the table is a ..6 WI,
proposal to suspend consideration of a main motion and all Pending related motions until Tmn that rii6m my t a r+ "4;
moarc lyO111, U tofihe mcnM wh co ded/
later in the same meeting in order to deal with another matter that has come up ! n ats~t : i ~edza> na;~i
unexpectedly and which must be dealt with before the pending motion can be Properly vmro 'n-;°^s ^•!i o'6vmuuo n :evo':
i amend th mod fed moo w no a the
addressed. A motion to lay a matter on the table requires a second, is not amendable or a+.-
debatable, and Passes upon a maiority vote. Before the meeting adioums, a subsequent
non-amendable, non-debatable motion may take the matter from the table if seconded and
-
pissed by a majority vote in favor. IAbsenl aas rt ucces" motion to take the matter from.
the table`tbe tabled motion dies. The matter may be addressed anew in a subsequent i eomment[!z3I m w b!iiyx b t m „ ke
mfo seP N bl do t pa ipo
meeting. wry~
menenndafinn ty es;3"~f.udW f,'$'
P. Division of a Motion. Any member may move to split a motion under consideration
into two or more independent motions that are taken uo in sequence. Each new motion is
deliberated. Possibly subiecled to secondary motions, and voted upon before taking no
the next part. The mover may designate in the motion the order in which the Parts are
considered. The motion requires a second, is amendable, is not debatable. and passes
upon a majority vote in favor.
h. Referral. A motion to refer a matter to a subcommittee or another body for further
study and and Possible recommendations to the Council The motion reouires a second,
is debatable and amendable, and passes upon a maiority vote in favor. Any proposed
amendments to a main motion on the referred matter that are pending at the time are also C
referred.
i
i. Previous Ouestion. A motion to call the previous question precludes all amendments
and debate on the pending motion until it is decided. It is not debatable or amendable and
requires a second and a two-thirds vote in favor.
j Postpone to a Certain Time. A motion to Postpone a matter to a narticular future j
meetine requires a second, is debatable and amendable, and passes upon a maiority vote j
in favor.
k. Amendment. Any main motion and any amendment to a main motion may be
amended to add or omit words. A proposed amendment must be germane, must be
seconded, and is debatable if the motion to be amended is itself debatable. The '
amendment Passes upon a maiority vote in favor. Other amendments may also be !
proposed. Provided that they do not alter or nullify the amendments already Passed or
attempt to amend a motion to amend a motion to amend.
Page 9 of 18
BXIIIBITA -
_
6 Restatement of Motion. h3eforea vote is takenonto motion. rt'mu iist be restated- the ,
presidin' e omcer oithe Cily Recorderj j comment pza7 ma,'i,6~e co,m ~ .M1 t`r k";';
7. Voting. i
a. When a question or motion is nut to a vote by the chair, each member present shall j
vote for or against the motion unless the Council excuses that member from so doing. If _.-'............t:.:
thereafter the Mayor or any member calls for a roll call vote, then each Wnexcuscd! corn nipss mee°Reni.er:a a<gwniy' .
member must vote. The Mayor can only vote in the case of a tie, and then is required to ea co i rrcri0m.m_,d`~a ~o~yr
cdl in t (having be db
vote. c Omar id IIii Conn i
i n m . c wdi nK be n'"""eta
d l FlI`ci f t Ys f~
b. A simple maiori[y of the quorum present delemtines the action on ordinance, or 4
resolution and on most motions. On questions required by City Charter. City Ordinances.
or applicable provisions of Robert's Rules of Order Newly Revised to be decided by a
o+. -
two-thirds vote of the Council. approval requires ern at7iritiv
nae vole~oRaCleast foul j
Councilors Comment pxe7 m n s ei r
Cw
iM1 RI [hr t q"g~Wn flll
In
C "7
i th ds ofthou prese tha the dd al
8 Reconsideration W~iiiember who voted m fav'ieYofdamf(CounctlaUioriu nay move for w"'"°m optic err(- i ~i r'i"i. a +
reconsi8eraMM b RTM oumment`of.lhc~meetin' g alY'~~hic'h' the.acuon was approved POD of cOYAe b`s° so=
the n~ e`Y rt°reeula mee[inRUMSss the iiem already h t0nja"'~'ooroved oTr yetoROylithe'fvlavo'r
pursuant.to.Cit°v C,liarteil•Artrcle'4: Section!Y,%,iie moC,on4°mustibe,s°"'e onded s'~.debalalile if
the Maio' HTUM er rewnsuie dr tion'is'fdebatable inot amendable, and'aoavses upon a m~7onty F
vote i°n'Wfavoi': Anv membe'r' may secdrid oti-on for rcwnsidcratiom *FA'r motion Ito
reconsider aCbuncd°aclion`tmsv`be inadeo Iv'one"e'A'veloed'i[emmav""'riot bye the subject f
as°motion"foirceonside'raion /r~t~ommerit [tom-Z~ red:~o~~ai;,,ncwoa
IjThecuR mn rovlted dereble
ll f n`a_Eo t Y ago
Section 2.04.050 Order of Business
At the first meeting in January, after the roll call, the presentation of the Mayor' s Stale of the
City address shall be first in order.
The Mayor or presiding officer may change the order of business on the agenda. The required
order of business has been established by ordinance is as follows:
A. Roll Call.
13. Approval of minutes of the previous meeting. If there are no corrections or objections to the
minutes, they shall be considered approved; otherwise, to be approved by vote. The minutes
as approved shall be signed by the Mayor and City Recorder. s
C. Special presentations, proclamations and awards. This item on the agenda is used to V
acknowledge special recognition and awards given to the City or for the Mayor to announce - -
proclamations, which serve to encourage and educate the community. Proclamations shall be
made and placed on the agenda at the discretion of the Mayor. Requests for recognition
under this agenda item should be submitted in writing to the Mayor.
D. Consent agenda. Routine business items may be listed by the City Administrator under this
item, which shall be acted upon in its entirety, except that the Mayor or any member of the
Page 10 of 18
EXHIBIT A
Council may request that any item be moved to the regular agenda under the appropriate
section of business.
E. Public hearings shall conclude at 9:00 p.m. and be continued to a future date to be set by the
Council, unless the Council by a two-thirds vote of those present, extends the hearing(s) for
one-half hour until 9:30 p.m. at which time the Council shall set a date for continuance and
shall proceed with the balance of the agenda. Not more than two land-use appeal hearings
shall be scheduled for any regular meeting of the Council. The City Administrator may, in
the administrator's discretion, schedule additional legislative hearings depending on the f
anticipated length of the Council meeting. t
r-
Persons wishing to speak at a Public hearing we to submit a "speaker request form" prior to
the commencement of the hearing and deliver the form to the City Recorder. The Mayor or '1
presiding officer is to inform the audience of this requirement to submit the form prior to the
commencement of the hearing. No testimony will be accepted on public hearings that have -
been closed.
P. Public forum. Public forum is an opportunity for the public to comment on items which are
not included on the agenda. The agenda for public forom is 15 minutes, unless a majority of
the Council votes to extend the time. Persons wishing to speak are to submit a,"speaker
request form" prior to the commencement of the forum and deliver the form to the City S
Recorder. The Mayor or presiding officer is to inform the audience on requirements for,
submission of the form. j
Members of the public may speak about any topic during the public fotvm, unless the topic is
indeed on the agenda for the same meeting. if a.r-~..R,-'-°-Members of the public who wishes
to speak on an agenda item or public hearing item they-may do so at the time set aside for
those topics after submitting a timely "speaker request form." -(See Section E. above
regarding hearing testimonvl. Of a member of the'uablic o?.a Council me`ombenhas reauestted
limeso sneak on s consent aeenda item, the "p"residme officerlsM1alLmaAc tiine''for a brief
presentatid-"tibvthe requester prior to the Counci L's"voe odOte con5eriiaeenda. eommenE h287v : a<a1
k eel= aw1 6e bet Ib g
r da t end Pl
II He
e;wPublic forum is not to be used to provide or gather additional testimony or information on a f item ao~,na""" sir
quasi-judicial matter. Public testimony will not be accepted on a public hearing where the
record has been closed if the matter is still pending.
The MayeFpresiding officer will set time limits for people who ask to speak during public
forum or on agenda items. In general the time limits should be set to enable all people who
wish to speak to eemplete-Nxifi 2 regent testimony. Time limits shall not be so short as to not
allow speakers to address their topic. ,
When possible and feasible, preference will be given to individuals who reside within the
Ashland city limits. Persons who do not reside in the City may be placed at the end of the
list of those wishing to speak at public forum.
G. Unfinished business.
Page I I of 18
EXHIBIT A j
H. New business. '
1. Ordinances, resolutions and contracts.
a. Every ordinance is to be enacted in accordance with Article X of the City Charter.
Copies of the ordinance shall be e-mailed to Council members and the Mayor at least
fourteen days prior to the meeting. Council members may review the ordinance and
forward suggestions for changes to the City Attorney for consideration. Minor changes
may be incorporated, substantive changes will be considered at the time of first reading. i
Any substantive changes to the ordinance must be verbally noted at first reading.
Council members must submit comments to the City Attorney no later than 12:00 noon
on the Wednesday prior to Council meeting.
Titles of lengthy ordinances will be published in the local paper at least seven days in !
advance of the Council meeting thus allowing the ordinance to be read by title only at the
Council meeting.
b. Resolutions may be placed on the consent agenda and voted upon. Resolutions do not
require a roll-call vote. "
c. The voting on all ordinances may be by roll-call vote and recorded in the minutes
showing those numbers voting for and those voting against.
J. Other business from Council members.
Section 2.04.060 Identification of Fiscal Impact of Policy Decisions
A. When the City Council adopts a program or policy, it shall indicate how it expects that i
program or policy will be funded; e.g., which existing taxes or fees the Council expects to I
increase and by how much, or which current City programs or department expenditures the
Council expects to reduce to fund the new program or policy. However, if the Council
cannot reasonably identify a potential funding source, it shall so indicate.
j
B. As used in this Section die term "program or policy with significant revenue implications"
includes an ordinance or a resolution in which implementation may entail expenditures in
any budget year in excess of one and one-half percent (1.5%) of the City' s annual General
Fund budget, and which may require an increase to existing taxes or fees or an imposition of I
new taxes or fees. "
C. The provisions of this Section shall not apply to extraordinary expenditures in situations of,
or necessitated by, public emergencies.
Section 2.04.070 Rights of Citizens
Citizens may speak on any item not on the agenda during public forum. Any citizen has the right
to present an item to the City Council during public forum. On behalf of the City, any Councilor
may request tlte-itenxhat any matter discussed durine public foram be placed on a future Council
agenda.
Page 12 of 18
i
EXHIBIT A
Section 2.04.080 Conduct with City Employees
The City Council will work with City staff in a spirit of teamwork and mutual cooperation.
A. Councilors may make inquiries of staff to increase their understanding of an issue or action.
Councilors should limit requests for information from staff to questions that may be '
answered with minimal research. Requests that require significant staff time or resources
(two hours or more) should be directed to the City Administrator and must be approved by
the Mayor, City Administrator, City Attorney or by a majority vote of the City Council.
B. Written information given by the Mayor, Councilors, City Administrator, City Attorney, or
City Staff, including materials requested by individual Councilors and the Mayor, generally
will be distributed to all Councilors with a notation indicating who has requested that the
information be provided. -
i
C. Individual Councilors should respect the separation between policy-making and
administration. They shall not pressure or direct City employees in a way that could
contravene the will of the Council as a whole or limits the options of the council. They must
not interfere with work performance, undermine the authority of supervisors, or prevent the ;
full council from having access to relevant information. Notwithstanding this paragraph, ! -
nothing shall hamper the Council's ability to evaluate the performance of the City
Administrator or the City Attorney.
D. The Mayor and council members should strive not to criticize any person in a public meeting
or in public electronic mail messages. 't'he same expectation applies to City staff in the
exercise of their official duties. Discussions and disagreements should focus on the content -
of the topic at hand. Nothing should limit a Councilor or staff person' s right to report
wrongdoing.
E. Councilors with a concern about the performance of a particular staff person should express
that concern to the Mayor, City Administrator, City Attorney.
Section 2.04.090 Commissions and Boards
A. Establishing Commissions and Boards.
Commissions and boards originate from different sources, including Oregon State Statute, City
Charter and Municipal Code; others are established by direction of the Mayor or the City
Council. Advisory Commissions and Boards which are permanent [Regular] shall be codified in
AMC Chapter 2, including but not limited to Forest Lands Commission, Planning Commission,
Transportation Commission, Planning Hearings Board, Public Recreation Commission, Public
Arts Commission, Conservation Commission, Ashland Airport Commission, Housing
Commission, Historic Commission,'frce Commission, and the Municipal Audit Commission. -
AMC 2.10 contains code common to all Appointed Commissions and Boards.
B. Ad-hoc Committees and Task Forces.
I
Page 13 of 18
i
EXHIBIT A
I
The Mayor shall have the authority, with the consent of the Council, to form ad-hoc committees
or task forces to deal with specific tasks within specific time frames. Such ad hoc committees or
task forces shall abide by uniform rules and procedures set forth in AMC 2.10 and such other
rules as prescribed by the order establishing such ad hoc entities. Committees or task forces
shall make recommendations by way of a formal report to the City Council. The Mayor or City
Administrator may refer matters to the appropriate ad hoc committee or task force. The Mayor
with the consent of the Council shall appoint the membership of such committees or task forces.
Members of Regular Boards and Commissions may be appointed to ad hoc committees and task
forces. The City Administrator shall by order establish the ad hoc body's scope of die work and
rules of procedure, if necessary. The Council has the authority to follow the recommendations,
change the recommendations, take no action, remand the matter back to the ad hoc body or take
any other action it sees fit. The Council by majority vote may remove a member of an ad hoc
committee or task force at any time, with or without cause. The City Council by majority vote
may amend or dissolve an ad hoc committee or task force. _
C. Regular Commission and Board Membership Appointments.
Except for the Municipal Audit Commission (AMC 2.11), all committees and boards not
required by state law to be appointed by the City Council shall be appointed by the Mayor with - -
the consent of the Council. 'the Mayor may request assistance or recommendations from
Councilors in making appointments. In the Mayors absence, any necessary appointment may be
made by the presiding officer with the consent of the Council. When necessary, the Mayor shall
stagger the initial expiration of terms of appointees, such as in the case of a new commission or
board. The Mayor shall not appoint, nor shall the Council consent to the appointment of a
person to more than two (2) regular board or commission positions at a time. This rule shall not -
apply to the Planning Hearing Board. Because broad citizen participation is encouraged, the
Mayor and Council shall give due consideration to appointment of new qualified members
before re-appointing a person to more than three (3) full terms on any single regular board or
commission.
D. Mayor Membership on Ashland Budget Committee.
For the purpose of local budget law, the Mayor is a member of the governing body of the City of
Ashland. and shall be a voting member of the budget committee.
E. Student Membership on Regular Commission s. and Boards.
The Mayor with the consent of the City Council may add to the membership of any city
commission or board up to two positions for student liaisons. The student liaisons shall be non-
voting ex officio members of their respective commissions or boards. Once the liaison positions
have been added, the liaison from the high school shall be a high school student chosen by the i
Ashland High School Leadership class and the liaison from the university shall be a university
student chosen by the Associated Students of Southern Oregon University Student Senate.
Student Liaisons need not be appointed to every advisory commission or board.
F. Regular Membership Removal Process.
The City Council, with or without cause, may by majority vote of the City Council at a regular
meeting, remove any regular commission or board member prior to the expiration of the term of
i
Page 14 of 18 -
r
i
EXHIBIT A'
the appointment. Written notice of removal to the affected member shall be provided. Removal
shall be handled with respect and courtesy. If a member resigns or is removed, the Mayor shall
appoint a replacement for the remainder of the term in accordance with paragraph C. above.
Notwithstanding the above procedure, removal of a Planning Commissioner shall be governed
by the procedures in ORS 227.030. Hearings under ORS 227.030 are hereby delegated by the
governing body to the City Administrator or Hearings Officer in accordance with the AMC.
2.30, the Uniform Administrative Appeals Ordinance.
G. Changing or Dissolving a Regular Commission, Committee or Board.
After the commission, committee or board has been formed and codified, any change or
dissolution requires an ordinance amending the Municipal Code.
Section 2.04.100 Council Liaisons to City Advisory Boards and Commissions.
A. Role and Responsibilities of Council Liaisons.
1. The primary role of a Council liaison is to facilitate communication between the City
advisory body and the Council. A Council Liaison is an ex officio non-voting member of
the advisory body, not a regular voting member and shall not serve as Chan, unless the
Ashland Municipal Code specifically requires the Liaison to serve as Chair or in a voting
capacity. Notwithstanding the above, the Council Liaison to the Planning Commission
shall be considered a non-member Liaison and not an ex-officio member as regards
quasi-judicial matters.
2. City Councilors serve as liaisons to City commissions and boards, as well as ad hoc +
committee and task forces and are expected to represent the full City Council in
interacting with these such -entities.
3. City Councilors may attend meetings of City Advisory Boards and Commissions and
other ad hoc entities as citizens of Ashland. When attending as a citizen, Council
members must identify their comments as personal views or opinions not a representation -
of City Council policy.
B. Attendance.
Liaisons should attend a®ular meetings of the Commissions and Boards, or Ad hoc _
Committees or Task Forces to which they have assigned as time permits and should make
special efforts to attend meetings in response to specific requests to participate in discussion
on topics the Council may need to be aware of or provide input on.. III die _..-111 A Iissar.ss
ffik the Mayei: to he -assig ed Liaisons shall not attend quasi-judicial proceedings when
the final appeal or final decision is or could come before the City Council.
f
C. Deliberations.
The City Council values diversity of opinion. A significant role of an advisory body is to
represent many points of view in the community and to provide the Council with advice j
based on a full spectrum of concerns and perspectives. Accordingly, Council liaisons to City 1
Page 15 of 18
EXHIBIT A
advisory bodies should not attempt to direct debate, lobby, or otherwise influence the
direction or decisions of any advisory body to which he or she has been assigned. Council
liaisons are encouraged to field and answer questions as appropriate for an ex-officio
member of the advisory body. Undue influence over the decisions of any City advisory body
shall be grounds for removal of a Liaison assignment under paragraph I below.
D. Respect for Presiding Officer.
City Councilors attending advisory body meetings as liaisons shall accord the same respect
toward the Chair and other members as they do towards die Mayor, Presiding officer or each
other.
E. Council Information. t
City Councilors will inform the advisory bodies to which they have been appointed liaison of
about Council agenda items and Council decisions that may be of interest to the advisory
body. Liaisons shall also encourage advisory board members to attend Council meetings to
keep abreast of Council action, policy matters and the activities of the city. Te `--i'- e the -
h Chair
sh..1 ..,.-:..A
: 1. ..lace on the Agenda for the advisory body, labeled "Report of
F. Role of Liaison as Regards Vacancies.
The Council liaison for each advisory body, together with the advisory body chair and
\ assigned staff liaison will make recommendations to the Mayor for appointment of citizens to
fill vacancies on their respective advisory bodies.
G. Reporting to the Council
Ito-'unc~l liaisons sheFF{fenedtesF4ymav report to the entire Council onsignhficant and
important acthvuie's of eeeh-a~advhsoryabodyrio whicF they have been assigned' The chair
w .•r r ,..t.,. y,
of~each advh~sory~bodyichould be-mvitede'znect to g~,hvee- at least one shert-ennrie4- ,
presentation Jo_lhe Councl each year on the advisory bolt s anneal eoa1S`and
Fsrr nAr r a_ .
accomplishments and on recommended eoals for the Council to consider adopting. ~ Liaisons eallnoelrt [a9] oo m~aroro=~yt~h°'" ~
and rim o` ert m imml one c is
may seek assistance from the relevant staff liaison to accomplish this reporting responsibility. H. Liaison Appointment Process and Tenn.
~Ihe Mayor will appoint a Councilor io act as'a Council liaison to each and every advisor
y
:
commisshon'o~ board, Councilors interested in a particular subject area should inform the eommeotluo7 i i si 1 rti ewe "c
Mayor of their interest and the Mayor should take the expression of interest and/or a ne c a ,'s c :nn Zairy w n d
Councilor' s preference into account when making appointment decisions. Liaison
appointments shall be for a term of one year unless otherwise expressly stated.
Appointments are generally made on an annual basis in January and the Mayor shall make an
effort to rotate liaison assignments if there is more than one Councilor expressing a !
preference for an specific appointment.
1. Removal from a Liaison Assignment.
The Mayor or a Councilor may be removed for any reason from a specific liaison position or -
assignment upon two-thirds vote of the entire Council
Section 2.04.110 Council Representatives to State, Regional, Community and other
i
Page 16 of 18 - -
EXf11BIT A -
t
External Organizations.
i
A. Role and Responsibilities of Council Representatives.
1. City Councilors may be appointed, either by the City or by another entity, to serve as the
City of Ashland's representative to Stale, Regional, and Community organizations. In all
cases, the City's representative will follow the bylaws and guidelines for service of the -
organization to which they have been appointed.
2. The purposes of serving as an official Representative to State, Regional, Community, and
other external organizations are to ensure effective working relationships with other
agencies and organizations, ensure that Ashland uses all possible avenues to achieve
community goals; achieve City Council goals both within the community and in the
Rogue Valley; protect the home rule authority of the City of Ashland to make decisions
that arc best for the community; ensure that key City revenue streams are protected; and
secure federal and state funds for projects that benefit the City of Ashland and other
community institutions.
i
3. City Councilors are expected to represent the full City Council in their work as -
Representatives. Representing a position other than the official position of the City of
Ashland is grounds for removal under paragraph E.
4. City Representatives serving as voting members on another organization' s Board of
Directors (such as the Rogue Valley Council of Governments) should work in the best
interest of that organization when not in conflict with best interest of the City of Ashland.
When presented with a conflict, the member shall declare the conflict and, if necessary,
recuse himsell7herself from the matter.
5. If the City Councilor serving as a Representative is asked to take an official position on
an issue that affects die City of Ashland and the City' s official position is unknown or
unclear, the City Councilor should request that the item be placed on a City Council
agenda in accordance with AMC 2.04.030 for full City Council action. - `
6. City Council members may attend meetings of state, regional, and community
organizations as citizens of Ashland . When attending as a citizen, Council members
must identify their comments as personal views or opinions not a representation of City
Council policy.
B. Attendance.
Representatives should attend all regular meetings of the organizations to which they have
assigned. In the event a Councilor has difficulty attending, the Representative should find an
alternate to attend on the City's behalf. In the event of a continuing scheduling conflict, the i
City Representative should ask the Mayor to be reassigned.
C. Reporting to the Council.
Council Representatives shall periodically report to the entire Council on significant and t
important decisions activities of each state, regional, and community organizations to which
they have been assigned. Council members may also request that representatives of these j
organizations may be invited to give a short annual presentation to the Council.
Page 17 of 18
i
f
EXHIBIT A
1). City Representative Appointment Process and Temr. p
1. The Mayor will appoint a Councilor to represent the City to state, regional, and
community organizations to which the City is entitled to an official delegate. The City
Council shall confirm these appointments.
2. The Mayor and City Councilors may also be invited by external organizations to
represent either the City of Ashland or "Cities" in general. In these cases, the Mayor or ?
Councilor that has been asked to serve will inform the City Council in a regular meeting
of the assignment and request that the City Council confirm the appointment.
3. Councilors interested in a particular subject area should inform the Mayor of their interest -
and the Mayor should take the expression of interest and/or a Councilor' s preference into
account when making appointment decisions. City Representative appointments shall be
for a tern of one year unless otherwise expressly stated. Appointments are generally
made on an annual basis in January and the Mayor shall make an effort to rotate liaison
assignments ifthere is more than one Councilor expressing a preference for an specific
appointment...
E. Removal from a Representative Assignment
The Mayor or a Councilor may be removed for any reason from a specific representative
position or assignment upon two-thirds vote of the entire Council.
Section 2.04.120 Councilor Expenses
A. The City will reimburse a Councilor or the Mayor for expenses that are directly related to
City business in accordance with the City's reimbursement policy.
i
Councilors are required to submit all statements as required by ORS 244.
Page 18 of 18
EXHIBITB
i
PROPOSED AMENDMENTS TO PROVISIONS OF: ~
i
UNIFORM POLICIES AND OPERATING PROCEDURES FOR ADVISORY r
COMMISSIONS AND BOARDS
Section 2.10.005 Purpose
Advisory commissions and boards (advisory bodies) require uniform rules, policies and
operating procedures to assure maximum productivity and fairness for members and the public.
Except where otherwise provided in this Code, the following policies and procedures govern all
the City's commissions and boards, as well as ad hoc entities. Nothing herein removes the
requirement for compliance with more specific regulations and guidelines set forth by state i
statute, administrative rate, ordinance, or resolution specific to the advisory body. These rules
do not apply to the elected Parks and Recreation Commission.
r
Section 2.10.020 Terms, Term Limits and-Vacancies.
All successors to original members of an advisory commission or board, shall have a three (3)
year term, except as otherwise provided in the appointment order. Notwithstanding the three
year limitation, Planning Commissioners and Budget Committee members not on City Council
shall serve four (4) year terms. All regular terms shall commence with appointment and shall
expire on April 30 of the third year, unless otherwise provided in the appointment order. The
appointing authority may stagger terms in the original appointment order as necessary.
Members may serve three (3) terms on any single commission or board, after which time the
Mayor and Council will give due consideration to other qualified candidates before making a
reappointment. Any vacancy shall be filled by appointment by the Mayor, with confirmation by
the City Council, for any unexpired portion of the term as provided in AMC 2.04.090.C.
Section 2.10.025 Meetings and Attendance.
Unless otherwise provided by law, the number of meetings related to business needs of an
advisory commission, or boards may be set by the advisory body. All--Each members ere
expeeterUFemust attend e4l--at least seventy-five percent (75%) of the full advisory body's
regularly scheduled meetings, study sessions and special meetings which occur within each
twelve-month Period from May I to April 30 and while the person is a member of the advisorv
body- when-eppFiceble. Generally. advisory bodies may not allow alternates to represent or
stand in for a member at a meetin~~Votw"ithstandin°°t; tbe~foregoine 'r'ule on.advisorv,boo ;
withTs°°mefo~'inembes who'ta're-annointed Nviiri enti[roth'cr'than th6 the':Mavor:a`nd'City.Council
a Hk-vho.se"~ rve?M-Ti represenfti[ive of the appomhng enut~'an altemzte~:inat oarticioaie and vote
for`'rthe n eed member e,,"" ioz "al "an 7mectin ofThe aiiviso .bpd"`s"and'such~"aAici'ztimn b
the.al[emate willTbe~deeined=to'.be attend ancebv the mined memben.~ A member should provide , to meet OQ.>a.%o addr m dath r 150
ry.
at least 48-hour notice to both the chair of the advisory bodv and the staff liaison reeardine env ZZWE gin:c ~fn
Manned absence from a scheduled meeting of the advisory body. In the event an unexpected urn ism t~~ orP m,eM1 o,.
emergency will cause a member to W, Te- ..,e,,,b 01 be absent from a meeting, the member must -
notify the chair or the staff liaison at least two hours prior to the meeting. Andras
atteHding a minimum oftwo thifils (2A3) of all seheduled meetings (inelusive af study sessions
Page] of 3
i
EXHIBIT E
^°a special meetings) shall be considered inactive and the position Each advisory body i
should review member Aattendance shat be ed b the eamm'ss'en eF bAA-'' a i g the
sehed ed me - ' approximately every six months • A4
sentand report to the Mayor and City Council c,n the need for appointments or
re-appointments, if necessary. -
Section 2.10.040 Quorum and Effect of Lack Thereof
otherwise - neebng quonim shall consist of morethan one-hale Of the total
Unless number of?a-t!lhonzed'members of"ttie body, mcludmgiany vacant ;posmons., Jon voting ex j ewaaa4it[12]aMth`tviitiz r°ar uss
c,~. C brs .p ed~'~t t°`Yen y
officio members staff and liaisons do not count toward the quorum. A. f s es i°r r :
to adopt on m . Members need not be physically present at a meeting if an sr';!'~,n ~ a r r m°°mue.
wa eq [e Ih0iem[UYIg~QY~O~N°'bC 6d5EaC'
another means of attendance (e.g. telephonic, interne[ etc.) has been established by the
membership and public meetings law requirements are met. If the Council members in na r iy rea: ncv,mmgiu, .,Spa
attendance do not constitute a guomm, 'r hefe ' ni r°- ° no deliberations 9s"' '
towards a decision or any other official business may be conducted, except for informational
Presentations by staff or invitees, shall -ke-eendueted, and the members nresent may adioum. of
matters a&erlised shall autanatietilly be eaminued to the next fegalady At
least a majority of the quomm is necessary to adopt any motion: some motions require the
affirmative vote of at least two-thirds of the members present.
Section 2.10.050. Election of Officers, Secretary, and Subcommittees. -
At its first meeting following the appointment or reappointment of memberseach year ,4-the
year the advisory commission or board shall elect a chair and a vice chair who shall hold office
at the pleasure of the advisory body. Neither the chair nor vice-chair shall serve as an officer for E -
more than twa-three consecutive annual terms. Without the need for an appointment, the head
of the City Department staffing the commission, committee or board shall be the Secretary and
shall be responsible for keeping an accurate record of all proceedings. The Department head i
may delegate such tasks to a staff liaison. Subcommittees may be formed for the purpose of
gathering information and forning a recommendation to be brought forward to the full advisory
body. °-°°ia F Only the full body can make recommendations to the City Council.
Subcommittees must comply fully with the requirements of Oregon Public Meetings law.
i
Section 2.10.060 Agendas and Minutes.
The chair or staff liaison will be responsible for the agenda of all meetings of advisory
commissions and boards. A member or staff liaison will be responsible for taking minutes.
Agendas and minutes will be posted on the eity's City's web site. Members are encouraged to
access those documents from the web site. Staff will email or mail documents to members upon
request. ~If the advisorybody has a current Council Liaison, the Liaison -shun-periedieally- l
should be given the opportunity to report to the commission or board periodically.
Section 2.10.065. Goals. -
Advisory commissions and boards are encouraged to establish annual goals and action items that
reflect the body's charge as stated in the specific commission ordinance. Advisory bodies are
t
Page 2 of 3
EXHIBITB "
expected to suggest, support and advance Council goals and are encouraged to look for ways
within their own unique responsibilities to do so.
Section 2.10.070. Rules and Regulations.
The advisory commission or board may make such rules and regulations as are necessary for its
govemance, including the conduct of meetings, when not inconsistent with Ashland City i
Charter, Ashland Municipal Code or Oregon law. These rules may be less formal than the
meeting procedure rules in AMC 2.04.4014obens Rules of Orde In the event of conflicts that
cannot be resolved less formally, RAMC 2.04.040 shall be used as the
standard for meeting rules and procedures. Failure to strictly fella gmply with Roberts-Rules
o€9rderthe rules on meetine procedure in AMC 2.04.040 shall not be cause to void or otherwise
disturb a decision or action. The body will strive to be clear in its proceedings.
T /ry'~L a ....fa..t~l... ..'Y'1...F A.... ..T..,.~'♦ ...6~ .,..6 ~.6F'~L.....N.. ......A.9, ..:1
xa ..s..`.~#tis'~§bY Via.-; `t ,:0Yga4MSia a•,"..tj~
non
~a .x. ghtt a,. thn
_ v;. ' _Yd .a._.. ::rc Comment lolsPro anxs edundmiif the
~gm _ ~ -v~ I P PnsM tim8esi 5 n 2100J0 abaK areare
adopt d
Section 2.10.105 Reports.
Each Aadvisory commissions and boards shall submit copies of its minutes to the eity-
eeexeilCitw Council and shall prepare and submit such reports and make such presentations to
Council as from time to time maybe requested by the Mayor and City Council. The chair of
each advisory body should expect to make at least one presentation to the Council each Year on -
the advisory body's goals and accomplishments and on recommended goals for die Council to
consider adopting Unless otherwise expressly provide in the Ashland Municipal Code or State
Law, all reports or recommendations of City advisory bodies committee shall be considered
advisory in nature and shall not be binding on the mayor or eity~& Council.
L
Page 3 of 3 -
i
Exhibit C
PROPOSED AMENDMENTS TO PROVISIONS ON:
CONSERVATION COMMISSION STAFF LIAISON
AND MISCELLANEOUS DEPARTMENT FUNCTIONS
Section 2.18.10 Established Membership (Conservation Commission)
The Conservation Commission is established and shall consist of nine (9) voting members including one
representative of the solid waste franchisee for the city; and one representative from Southern Oregon
University; and one representative from the Ashland School District and six (6) other voting members.
At least five (5) of the other members shall reside within the city. The commission shall also consist of
certain non-voting ex officio members, including the mayor or one council member serving as council
liaison, the Department of Community Development Director and the Electric Utility Director, the
Director of Public Works, the Building Official and City Administrator. The °1 Util ity Difeete
shall seFve as the pfimafy staff WaiseH and SeeFetai~, of the Commission. The primary staff liaison shall
be appointed by the City Administrator and shall serve as Secretary of the Commission. Voting members
shall be appointed by the Mayor with confirmation by the City Council.
Section 2.28.100 Electric Utilities Department Functions
The functions of the Electric Utilities Department are the construction, operation, and maintenance of the
electric distribution system; the installation of all new lines, services and meters; the maintenance of the
hydro-generation plant; the preparation and submission of proposed work programs including estimates
of cost; and the installation, maintenance and operation of all electrical equipment and facilities of the
City; , or as
Section 2.28.130 Finance Department - Functions
The functions of the Finance Department are the administration and collection of various City taxes,
licenses, and permits and the administration of ordinances and state laws applicable thereto; the receipt
and safekeeping of all City money; preparation and control of the City budget; procurement of materials,
supplies, equipment and services for all departments,
receipt, storage and issuance of supplies, materials and equipment; the disposal of surplus property; fiscal
and property accounting for all departments e_ eept the ^ shlan' °°f' " "^a ReeFe an ^ammisgian; data
processing; financial estimating, planning and programming; billing and collecting; investment of
temporarily idle funds in cooperation with the City Recorder; dispatching of utility connect and
disconnect orders; risk management and insurance administration; epefatien of the switelibeard;
the performance of all duties prescribed by the
City Charter and ordinances and the laws of the State for those officers and officials included in the
Finance Department; and the performance of such other functions as may be assigned by the City
Administrator or prescribed by the City Council.
Exhibit C
Section 2.28.340 Public Works Department-Functions
The functions of the Public Works Department are the construction and maintenance of all streets, alleys,
sidewalks, paths, bike paths, rights-of-way, and courts now open or which hereafter may be opened; the
cleaning of streets; the construction, maintenance, and operation of the sewer and storm drain systems;
the maintenance and operation of the sewage disposal plant; the construction, maintenance and operation
of the water distribution systems, the maintenance and operation of the water filtration plant; the
supervision of all work done on streets, alleys, or other public ways, land, buildings, or other structures by
anyone other than the City; supervision of the repair and maintenance of all motor equipment of the City;
exeept equipment Of !he o.._i.......a oo.._oation Ceffimissiefi; the performance of traffic engineering; the
planning, improvement and maintenance of the Ashland Municipal Airport; the performance of all phases
of engineering work required in connection with all the functions of said Department; the keeping of
records of all surveys and measurements made, which records shall be open for public inspection.
Section 2.28.354 Community Development Department - Functions
The functions of the Community Development Department are the preparation and maintenance of the
Comprehensive Land Use Plan of the City as required by State Law; the preparation of ordinances,
policies, maps and studies implementing said plan; the processing of applications for planning actions set
forth in Title 18 of this Code; with the assistance of the Police Department, the enforcement of all laws,
ordinances and regulations governing the erection and occupancy of buildings and structures, and the
alteration of or additions to buildings and structures as required in Title 15 of this code; and with the
assistance of the Police Department, the enforcement of all laws and ordinances governing zoning and
land-use as set forth in Title 18 of this code; and the development and iffiplefflematieft ef eflei:gy