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Jefferson County PUD
Preliminary Cost of Service and Rate Design Results
December 9, 2014
Presented by:
Gary Saleba, PresidentEES Consulting, Inc.
A registered professional engineering corporation with offices in theSeattle and Portland metropolitan areasTelephone (425) 889-2700 Facsimile (425) [email protected]
EES
ConsultingEES
Agenda
Objectives Review of Rate Setting Process Electric Rate Study Assumptions COSA Results Electric Rate Design Policy Input Needed COSA Results and Proposed Rate Options Specific Electric Rate Design Proposals Summary of Electric Rate Study Policy Issues EES Recommendations Pole Attachment Rate Water/Wastewater Results Water/Wastewater Recommendations Questions / Answers
2
Objectives
Review Equity of Current Cost of Service Analysis (COSA) and Rate Design Goal is every customer pays fair share Cost allocations driven by usage, density and delivery voltage
Rate Restructuring Simplify current rate schedule structures and administration Make rates PUD-specific Address local concerns
3
Objectives (cont’d)
Traditional Rate Setting Principles/Bonbright Principles Rates should meet revenue requirement Rates should be cost based Rates should be easy to understand and administer Rates and the cost allocation process should conform to generally
accepted rate setting techniques Rates should provide revenue stability to the utility and rate stability
to the consumer RCW Legal Requirements (80.28.005)
Fair, just, reasonable and sufficient
4
Review of Rate Setting Process
Step 1 - Aggregate Revenue
Requirement (How much?)
Step 2 - Perform Cost of Service Study (Who
should pay?)
Step 3 - Design Rates (How to
collect?)
Step 4 - Implement
Rates
5
Electric Rate Study Assumptions
June 2013 –May 2014 Actual Loads Calendar Year 2015 Test Period/Budget Revenues Calculated Using Current Rates and Billing Determinants Forecast O&M Expenses per 2015 Budget Power Supply and Production Expenses Based on BPA
Rates/Projected Loads Debt Service Assuming No New Debt Capital Improvement Projects per the Budget and Funded by Rate
Revenues and Reserve Fund
6
COSA ResultsSummary of Revenue Requirement
7
Revenues 2015 2016 2017 2018
Present Rate Revenues $30,126,902 $30,781,403 $31,049,687 $31,409,098
Other Income $617,573 $636,100 $655,183 $674,839
Total Revenues $30,744,475 $31,417,503 $31,704,870 $32,083,937
Expenses Generation $14,838,505 $16,085,205 $16,437,055 $17,315,982
Transmission $1,344,426 $1,384,759 $1,426,302 $1,469,091
Distribution $3,198,066 $3,294,008 $3,392,828 $3,494,613
Customer Accounts and Services $800,000 $824,000 $848,720 $874,182
Administration and General $1,809,579 $1,863,866 $1,919,782 $1,977,376
Capital Projects $3,892,000 $4,757,000 $2,637,500 $2,447,500
Taxes $2,103,500 $2,166,605 $2,231,603 $2,298,551
Interest and Debt Service $5,800,000 $5,800,000 $5,800,000 $5,800,000
Total Expenses $33,786,076 $36,175,443 $34,693,790 $35,677,294
Surplus (Deficiency) in Funds -$3,041,600 -$4,757,940 -$2,988,920 -$3,593,358
Fund Balance (prior to rate increase) $9,365,275 $4,607,335 $1,618,415 -$1,974,942
Total Required Increase (Decrease) 9.9% 15.1% 9.4% 11.2%
Electric COSA ResultsRevenue to Cost Ratios
8
Revenues at Current Rates
Adjusted RatioMinimum System
Adjusted Ratio100% Demand
Residential (7) $18,754,671 89.1% 88.9%
Farm Service (8) 477,348 75.7% 89.4%
General Service (24) 4,070,992 165.0% 192.9%
Small Demand (25) 1,891,428 146.5% 132.3%
Large Demand (26) 675,410 149.1% 134.5%
Primary (31) 915,562 134.2% 113.3%
Irrigation (29) 7,472 26.7% 21.0%
Interruptible Schools 43 460,912 77.2% 65.3%
Street & Hwy Lighting 187,204 71.3% 81.5%
PTP 2,685,903 100.7% 100.7%
TOTAL $30,126,902 100.0% 100.0%
Accurate to +/- 10%
Electric Rate Design Policy Input Needed
Determine Overall Rate Adjustment How much and when to adjust rates May want small increase over multiple years or one time increase Timing depends on policy direction and software upgrades
Determine Method for Allocating Rate Increase Across Classes Across-the-board COSA based Move toward +/- 10 percent
Develop Proposed Rates PSE rates do not reflect JPUD costs Appropriate to simplify and combine some rate schedules Evaluate size of customer charge Consider eliminating block rates and seasonal differentials What to do about net metering and senior, disabled and/ or low income discounts New large single load policy 9
COSA Results and Proposed Rate OptionsResidential
Comparison of Rates to Unit Costs
Present Minimum System 100 Percent Demand
Basic Charge ($/day) $7.49 $29.63 $9.03
Energy Charge ($/kWh) $0.08511 (1st 600 kWh)$0.103589 (over 600 kWh) $0.0961 $0.1174
10
Proposed Rate Options COSA indicates above-average rate increase Increased customer charge justified by COSA and comparable utility rates Implement minimum bill? Remainder of increase to energy charge Move to flat energy rate, or reduce block rate differential to be consistent
with flat rates for BPA purchases and comparable utility rates? Schedule 8 not needed if Schedule 7 moves to flat rate
Specific Electric Rate Design ProposalsCommercial/Industrial
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Existing Rates Schedule 24 – No demand charge, seasonal energy charge Schedule 25 – Seasonal demand charge >50 kW, seasonal and declining block energy
charge Schedule 26 - Seasonal demand charge >50 kW, flat energy charge Schedule 31 - Seasonal demand charge >50 kW, flat energy charge
Proposed Rate Options COSA indicates below-average rate increase Establish 2 rates – with and without demand charge Schedule 24 customer charge increased and consider eliminating or reducing seasonal
energy differential to better match BPA costs Schedule 25/26/31 – consider having demand charge cover all kW (not just amount
over 50 kW), consider eliminating or reducing seasonal differences, eliminate declining block structure
Handle primary service through discount to demand and energy charges rather than separate rate
Specific Electric Rate Design ProposalsOther Classes
Irrigation Current rates are complicated with declining block energy rates and
seasonal for both demand and energy Consider move to general service rate
Interruptible Schools Less benefit of interruption to JPUD than to PSE Only paying 65% -75% of Costs Consider move to general service rate
12
Specific Electric Rate Design ProposalsOther Classes (cont’d)
Lighting Simplify rates with each rate reflecting a range of usage rather than one rate for each
type of light Differentiate rates based on who owns the pole Comparable utility rates
0 100W = $10/month 100W = $15/month Pole = $ 5/month
Port Townsend street lights Put on same schedule as above Monthly charge for balance of City-related lighting costs
Port Townsend Paper Pass through of BPA charges plus admin fees and taxes Apply standard % rate increase to administrative fees Need to re-evaluate when Clallam PUD transaction finalized
13
Specific Electric Rate Design ProposalsOther Classes (cont’d)
Net Metering Historical practice – 100 kW cap/ .5%of peak load or 500 kW total Current issues with net metering Options for going forward
Discounts Disabled/senior existing Low income possible
$500K to $1M in discounts $3 to $6 per month to recover from others Staff addition at 1 FTE to administer $.50 per month
Consider forgiving the customer charge as the crediting mechanism New Large Single Loads
Less than 10 MWa Issues with BPA-tiered rates Options Other PUD precedents
14
Summary of Electric Rate Study Policy Issues
Revenue Requirement Size of increase – one time or multiple increases Timing of increases
COSA Move towards COSA results Go across the board
Rate Design Simplify/consolidate/eliminate Size of customer charge/minimum bill Blocking Seasonality Net metering Discounts Street lights New large single load rate
15
EES Recommendations
Revenue Requirement 10% one time increase Implement in CY 2015
COSA Go across the board next year Move to +/- 10% of COSA in subsequent years where rate design changes
are revenue neutral
16
Rate Design Increase all customer charges
Residential to $15 - $20/month Minimum bill an option at $25/month
Commercial/Industrial 0 – 50 kW without demand meter Greater than 50 with demand meter Discount for primary metering
Eliminate farm, irrigation and school rates No blocking or seasonality Lighting rate with and without pole
Break at 100W Special contract with City
Discounts Policy call on who/how much Like waiving customer charge as method of crediting
Should implement new large single load policy before PUD needs it Net metering
Policy call Current policy generous for those using it
EES Recommendations (cont’d)
17
Pole Attachment Rate
Methodology Follows Washington State Regulations (RCW 54.04.045) Based on PSE records for number of poles and plant values Average gross plant per pole times carrying cost Assignable space divided by average 3 contacts per pole
Resulting Rates Current rate of $12 per attachment RCW based rate equals $25.03 per attachment Added revenues of $152,000
Recommendation Raise rate to $15 - $20 per attachment Refine needed input data Raise rate to full RCW rate next year
18
Water/Wastewater Results
19
Summary of Water/Wastewater 2015 BudgetConverted to Cash Basis
Present Rate Revenues $1,961,506
Other Charges $32,473
Interest Income $2,000
Total Operating Revenues $1,995,979
Purchased Water $16,000
Operations $450,000
Maintenance $360,000
Customer Accounts $118,853
Customer Service $130,000
Admin & General $107,184
Maintenance Gen Plant $60,000
Capital funded from rates $90,000
Long-term debt cost $451,796
Taxes $95,545
Total Operating Expenses $1,878,378
Operating Income $115,601
Water/Wasewater Recommendations
No Rate Increase Needed to Cover Cash Basis Work Towards Eliminating Customer Charge Difference Between
Systems Quimper=$21.50, Group A=$17.50, Group B=$20.00 Option 1: change all to $20.00 right away, reduces revenues roughly $20,000 Option 2: Raise Group A to $19.50 and Group B to $21.50, adds roughly $30,000
and raise Group A again the following year
Consumptive Rates and Commercial Rates are the Same for All Systems, No Changes Needed
Continue to Keep Different SDC’s by System Due to Historic Basis for the Charge
No Change to Wastewater Rate of $26
20
Questions / Answers
21