integrated resource plan - wapa · ed3 integrated resource plan adopted 1/25/12 profile data...

INTEGRATED RESOURCE

PLAN

THIRD FIVE-YEAR UPDATE

ELECTRICAL DISTRICT NUMBER THREE OF PINAL COUNTY

AND THE STATE OF ARIZONA

January 25, 2012

ED3 Integrated Resource Plan Adopted 1/25/12

Table of Contents

Page #

Profile Data Board of Directors 3 Contact Persons 4 District Goals and Objectives 5 Competitive Situation District Contract Information 5 Regulations Applicable to District 5 Regulations Applicable to District Customers 5 Competition With District Service 5 Load and Resource Information Historical and Five-Year Load Forecast 6 Customer Profile Information 8 Supply Side Resources 9 Demand Side Resources 11 Identification and Comparison of Resource Options 11 Designation of Options 12 Action Plan Resource Action Plan 12 Validation and Evaluation 13 Conservation Action Plan 14 Validation and Evaluation 14 Environmental Effects 16 Public Participation 17 Appendices Appendix A—Map of District Service Territory Appendix B—Current Rate Schedules Appendix C—Load and Resource Information Appendix D—Integrated Resource Plan Public Meeting Notice

3


Profile Data Electrical District Number Three, Pinal County ("ED3" or “the District”) is an electrical district established in 1926 by the Board of Supervisors of Pinal County pursuant to what is now Chapter 12 of Title 48 of the Arizona Revised Statutes. ED3 was organized to provide, and since 1961 has provided, electrical power and energy which originally was primarily for pumping water for irrigation. ED3 obtained its original power purchase certificate from the Arizona Power Authority (“the Authority”) in 1960. ED3 is governed by a seven-member Board of Directors. At present there are 33 employees, including a manager and a secretary, both of who hold the same positions for Electrical District Number One, Pinal County, (“ED1”) to whose interests ED3 has succeeded. For ease of operations and discussions, references herein to ED3 also include ED1. The District’s current Board of Directors and relevant contact persons are detailed below. On May 26, 2010, the Arizona Corporation Commission approved the transfer to the District of approximately 3,800 metered connections which were within the District's service boundary but were being served by Arizona Public Service Company (“APS”). These transferred customers had historically received electric service from APS power lines that were actually connected with the District's electric system. As result of the transfer of customers and related electric facilities, the District's meter customer base grew from 19,000 to nearly 23,000, and the District became the only electric utility with the responsibility of maintaining critical electric infrastructure and ensuring reliable service in its 245,500 acre service area (excluding the Ak-Chin Indian Reservation). ED3 serves agricultural irrigation pumping loads, residential, commercial and industrial users, and certain other loads. Approximately 95% of the irrigation pumps served by the District are leased by Maricopa Stanfield Irrigation and Drainage District (“MSIDD”). The rest of the pumps are owned and operated by District customers. ED3 owns a substantial amount of 12-kV distribution lines and a lesser amount of 69-kV lines purchased from APS in 1960 under a thirty-year leaseback arrangement. ED3 assumed full electrical operation of its system to all customers in October 2001. ED3 also owns ten distribution level substations, and part of the Maricopa substation with Western Area Power Administration (“Western”). ED3 receives power and energy on the Parker-Davis System purchased from the Authority and Western, as well as other supplemental sources. ED3 also provides wholesale wheeling services to APS and the Ak-Chin Indian Community for service to their retail customers. A map of ED3's service territory is provided in Appendix A.

Board of Directors Dan Thelander—Chairman Bryan Hartman—Vice-Chairman Kelly Anderson—Secretary Pat Talla—Treasurer

David Stueve Larry Hart Jim Whitehurst

4


Contact Persons William H. Stacy—Manager Electrical District No. 3 of Pinal County

41630 W. Louis Johnson Dr. Maricopa, AZ 85238 Ph: (520) 424-9021

Fax: (520) 424-3281

Kenneth Saline—Engineering Consultant K.R. Saline & Associates, PLC 160 N. Pasadena, Ste. 101 Mesa, AZ 85201-6764 Ph: (480) 610-8741 Fax: (480) 610-8796

ED3 purchases power from the Authority (Hoover Power), Western (SLCA/IP and Parker Davis Power), and APS. In addition, ED3 is a participant in the Hoover Power Resource Exchange Program and a party to an Integrated Resource Scheduling Agreement which permit ED3 and other similarly situated utilities to integrate and exchange Hoover and SLCA/IP power resources. The power and energy from the Authority, Western and APS are transmitted over the Parker-Davis transmission system, the Pacific Northwest - Pacific Southwest Intertie transmission system, the CRSP transmission system, APS’s transmission system and ED3’s system. The policies for service and rates for power provided by ED3 to its customers are determined and set by its Board of Directors. Copies of ED3's current rate schedules are attached as Appendix B. The resource scheduling and utilization of the District’s resources have been managed through the Authority’s Resource Exchange Program and through the District’s participation in an Integrated Resource Scheduling program for Hoover and SLCA/IP resources, respectively. These resource management programs have provided flexibility for the District to re-pattern its resources monthly to meet its changing loads and exchange the resources with other preference entities who can temporarily utilize the power during the same periods. The District anticipates that current federal resources under contract and continuation of the Integrated Resource Scheduling procedures and Hoover Resource Exchange Program will be sufficient for the District to meet a portion of its monthly power and energy requirements. However, a portion of the District’s projected requirements over the next five-year period must be met through supplemental power purchases. For this timeframe, the District anticipates using its Hoover resource entitlement, its SLCA/IP and Parker-Davis entitlements, the Integrated Resource Scheduling program, Resource Exchange Procedures, APS and Southwest Public Power Resources Group (“SPPR Group”) or other supplemental resources to meet its projected loads.

5


District Goals and Objectives

Provide Reliable Electric Power at Lowest Practicable Cost, Consistent With Sound Business Principles

Enhance Customer Financial Stability by Providing Services Which Enhance

Property Values and Provide Long-Term Stability in Electric Power Rates

Operate ED3’s Electrical System to Provide Low Cost and Reliable Electric Services to All Customers in ED3’s Service Area

Promote Energy Efficiency and the Effective Management of Water and Power Resources

Competitive Situation

District Contract Information

Arizona Power Authority (Hoover Power Contract)

Western Area Power Administration (SLCA/IP Contract) Western Area Power Administration (Parker Davis Contract) Transmission/Ancillary Service & Supplemental Power Supply Agreement (APS)

Southwest Public Power Resources Group/Sempra Generation (Power Purchase Agreement)

Regulations Applicable to District

Energy Planning and Management Program (EPACT ’00)

Regulations Applicable to District Customers Arizona Department of Water Resources—Groundwater Management Act

Competition With District Service

There is competition for leasing the farm ground within ED3. Many of the land owners in ED3 and other districts lease ground to tenant farmers who lease property based upon lease cost and water costs (i.e., pumping costs). Therefore, to the extent that the costs in ED3 become significantly higher than other areas, the competition for farm ground may significantly impact the irrigated acres and electric load of the District.

6


Load and Resource Information

Historical and Five-Year Load Forecast:

The District most recently completed a load forecast in November 2011, containing Baseline, Pessimistic, and Optimistic scenarios through 2020. The results of that forecast are depicted below.

ANNUAL ENERGY REQUIREMENTS (MWh)

Year Baseline Pessimistic Optimistic

His

toric

al

2002 150,745 2003 218,544 2004 257,358 2005 277,344 2006 379,985 2007 503,824 2008 590,171 2009 570,019 2010 535,653

Pro

ject

ed

2011 653,833 653,833 653,833

2015 674,207 615,734 701,729

2020 703,673 643,791 731,854 Average Increase

2010-2020

3.14% 2.02% 3.66%

See Appendix C for more detailed information.

Overall, baseline forecast estimates for 2012 predict a small decrease in total energy requirements and peak demand due to a reduction in irrigation pumping loads bringing those loads back to historical levels from the unusually high 2011 levels. For the longer term (2010-2020), the Baseline forecast for total energy requirements and peak demand are forecasted to increase at a very modest 3.1% per year. Over the last five years, the District has added a number of residential customers, particularly with the transfer of customers from APS. However, the recent downtown in the real estate market has slowed the residential growth that was occurring in the ED3 service territory. Beginning in 2007, the City of

7


Maricopa, the primary municipality within the District's service area, experienced a sudden slowdown in residential market conditions as the previous year's housing frenzy cooled down significantly and went into an adjustment phase. Adverse economic conditions nationally and the resulting housing mortgage crisis have had a significant impact in the Pinal County area, causing a severe slowdown in housing permits, median home prices, and an increase in the number of foreclosures. Home loan programs, specifically lending in the sub-prime home loan market that previously was contributing to the rush of new home applicants, have become extremely stringent in their offerings making it much more difficult to qualify for home loans. It is expected that these changes in the real estate industry will be reflected in a reduction in the rate of population growth that has been occurring throughout Pinal County and the metropolitan Phoenix area. The City of Maricopa has been a popular destination for winter visitors and many of the new homes have a seasonal usage pattern that is typical of a winter visitor. The inventory of unsold homes and stream of foreclosure and short-sale activity in Maricopa have led to very low home prices that have attracted investors once again. Investor or bank-owned homes and seasonal use properties have created a large number of idle properties. Currently, there are approximately 2,000 empty homes (or 10% of residential meter connections) in the City of Maricopa and an additional 700 homes that are being lightly used or investment-type properties. At this time it is difficult to predict when significant growth in this sector will resume. Presently, for its Baseline forecast, the District expects growth in the 1.5% range for its residential meter connections and an annual kWh per customer of14,836 kWh/year over the five-year planning period. ED3 has continued to see a limited amount of growth in the commercial sector in the last few years. In Pinal County, small commercial and residential growth are highly correlated. This is a common characteristic seen in growing communities/economies. A specific level of industry is necessary to support a growing community. In the Maricopa area, this has equated to small commercial annual energy being approximately 7.7% of the annual residential usage during 2010. For each of the Pessimistic, Baseline and Optimistic forecasts, 2009’s more conservative ratio of 6.8% was used for the forecast period, reflecting a ratio closer to the historical average of 6.1%. Large commercial and industrial rate classes do not typically correlate well with growth in residential and small commercial but rather are impacted by sporadic increases and decreases as industry moves in and out of the area. Growth in industry is highly dependent on market conditions, proximity to resources, proximity to shipping routes, and proximity to the customer base. No attempt has been made to forecast these economic variables but rather any known large or industrial customers on the horizon in the forecast period are included in the forecast. For example, in late summer 2013 the 30 MW Pinal Power Biomass Power Facility is projected to come on line adding an additional 3MW of retail

8


station use load at a 95% load factor to the District sales. However, the Pinal Power facility is included in the Baseline and Optimistic forecasts only. Five large commercial accounts are also anticipated to come online between 2011 and 2015 with a total load of 8,400 MWh. This load has been included at a staged in 20% per year from 2011 to 2015 for the Pessimistic, Baseline, and Optimistic large commercial forecasts. The District’s largest irrigation customer is MSIDD. The MSIDD Irrigation forecast is based upon the economics of surface water availability and demand for water which is driven primarily by cropping expectations and commodity prices for grains, cotton etc. The continued availability of surface water, which offsets the need for pumped water, for agricultural purposes over the long-term is uncertain. What is known is that the current 400,000 acre-foot pool of water set aside for agricultural use by the Central Arizona Water Conservation District, the entity responsible for the allocation of Central Arizona Project (“CAP”) surface water, will be reduced gradually to 225,000 over the next 18 years. Other classes of service (General Service and Lighting) represent a relatively small share of ED3’s total load and are projected to experience only limited growth over the forecast period. See Appendix C for a graphical illustration of how the District schedules its resources to cover its loads in a typical year.

Customer Profile Information

As of September 2011, the District’s customers were divided into the following categories (as a percentage of total number of customers):

o Residential—87.3% o Commercial—6% o Industrial—<1% o Pumping—1.7% o Street Lights/Other—4.9%

See Appendix C for a graphical illustration, as well as a chart depicting historical and projected annual energy sales by customer class. The following chart highlights how the District’s loads have changed over the last five years.

9


Fiscal Years Ending December 31

2006 2007 2008 2009 2010

Number of Meter Connections

Residential

11,876

14,460

16,064

16,460

19,743

Commercial

591

732

877

853

1,356

Irrigation

418

416

342

345

305

Other

638

900

831

853

1,188

Total Customers

13,523

16,508

18,114

18,511

22,592

Megawatt-Hour Sales (MWh) Residential 146,766 204,001 215,461 214,183 221,399

Commercial

84,679 115,589 148,992 164,934 168,745

Irrigation 121,262 147,470 174,444 145,221 111,194

Other

12,578

16,613

15,197

11,638

13,505

Total Electric Sales 365,286 483,673 554,093 535,977 514,844

Supply Side Resources The District anticipates that current federal resources under contract and continuation of the Integrated Resource Scheduling procedures and Hoover Resource Exchange Program will be sufficient for the District to meet a portion of its monthly power and energy requirements through the short-term planning period. Additional purchases of supplemental power will continue to be made to cover other power requirements. For the long-term planning period, the District has determined to secure an additional long-term resource to diversify its portfolio of suppliers and provide additional options for firming through the Resource Exchange Program. As described in the District’s prior Plan, ED3 spent several years participating with the SPPR Group in evaluating future resource opportunities. The SPPR Group is an association of forty not-for-profit electric utilities, including cooperatives, municipalities, tribal power authorities, and irrigation and electric districts providing service in Arizona, California, and Nevada. Taking advantage of the Group’s size to broaden the scope of possible supplies, multiple options for resources were considered, including both construction of a generating unit and purchase of a portion of an existing generating unit. Ultimately, however, both of these options became infeasible due to economic and regulatory circumstances. The Group then issued a Request for Proposals (“RFP”), in response to which a variety of proposals could be submitted, including unit contingent proposals, turnkey proposals, 25-year purchase power agreements, slice of utility system offers in which the sale would be treated with the same firmness as native load, and the sale of existing generating units. The RFP was later modified to reflect the changing requirements of the participants, and required bids to be for unit

10


contingent power or firm power from dedicated units, including slice of system sales. Bids were also required to be for fully dispatchable service. Ultimately, due to economic and other considerations, it was determined that the most practicable option was a long-term power purchase agreement. Beginning January 1, 2015, the District will begin operating, as a member of the SPPR Group, under its new Power Purchase Agreement with Sempra Generation. The District also intends to issue an RFP in 2012 to evaluate additional resources for meeting future needs. Detailed below are the District’s current contractual commitments:

Arizona Power Authority (Hoover Power) at Santa Rosa/Test Track Substation

o Hoover A Capacity & Energy 15,290 kW (Maximum with Hoover Firming Capacity) 52,261,000 kWh (Contract Entitlement)

o Expires September 30, 2017 Salt Lake City Area/Integrated Project Capacity at Santa Rosa/Test Track

o Winter Season CROD: 2,678 kW o Summer Season CROD: 8,027 kW o Contract Term: Expires September 30, 2024 o Energy entitlements by fiscal year:

Winter Season

Energy (kWh) Summer Season

Energy (kWh) Fiscal YearFY 2012 - FY 2024 4,911,326 14,607,336

Parker-Davis Project at Santa Rosa/Test Track Substation

o Winter Season CROD: 4,203 kW o Summer Season CROD: 5,164 kW o Annual Firm Energy: 24,927,033 kWh o Expires September 30, 2028

Transmission/Ancillary Service & Supplemental Power Supply Agreement (APS)

o APS Firm Capacity and Energy at Santa Rosa/Test Track Substation

2012 2013 2014 Peak Capacity (MW) 104 90 90 Annual Energy (MWh) 471,872 415,680 408,224

o APS supplies ancillary services including energy imbalance services o Expires December 31, 2014.

Power Purchase Agreement (Sempra Generation—through SPPR Group)

o Firm Capacity and Energy 65,000 kW

11


Energy as needed o Effective January 1, 2015; expires December 31, 2039

Demand Side Resources Within the last few years, there has been a shift in the District’s customer base. However, a considerable portion of the District’s electric power is still utilized to pump groundwater for agricultural purposes. The following is a list of some of the on-going water conservation practices which are implemented by the District’s customers to efficiently utilize groundwater and thereby electricity.

Alternate Furrow Irrigation

Cut-Back Irrigation

Angled Rows

Shortened Field Lengths

Land Leveling

Precision Tillage

Graded Furrow or Border

Portable Sprinklers

Uniform Slopes

Deficit Irrigation

Soil & Water Amendments

Cropping Pattern-Winter vs. Summer

Use of Gated Pipe

Micro spray Systems

Tail Water Recovery

Irrigation Scheduling

Concrete Ditch Lining

Tiered Electric Rates

The District has also implemented a number of other demand side management programs as its load base has changed, including residential time-of-use rates and incentives for residential and small commercial customers installing solar power.

Identification and Comparison of Resource Options

The identification of options for additional resources within this IRP is coordinated through an examination of the costs and benefits for each resource. Because the majority of the District’s farm customers already implement numerous irrigation and agricultural efficiency practices in their operations and because the Arizona Groundwater Management Act heavily regulates the use of groundwater, opportunities for additional energy savings through demand side management programs (“DSM”) for these customers are very limited. However the District will continue to look for other opportunities for energy savings from evolving technological advances in agricultural practices. To the extent practicable, the District will also endeavor to promote customer awareness of pumping workshops and other similar forums for further education on advancements in water conservation practices and technology. As feasible, the District will also endeavor to implement additional conservation programs for other customers. However, due to the significant amount of new or recent construction in the District’s service territory, other customer classes are more likely to have already implemented the most current energy efficiency standards or practices. Therefore, opportunities for additional energy savings at this time are more limited.

12


Designation of Options

If additional resources are needed, the least cost option is identified from a cost benefit analysis. This information is considered by the Board of Directors in public meetings and combined with other information to select an Action Plan for the District which conforms to the regulations and guidelines of the Energy Planning and Management Program. The selection of the District’s Action Plan also includes consideration for reliability of service, economics, rate impacts and price elasticity, environmental effects, regulatory impacts and risks, legal considerations and risks, competitive impacts, social acceptance and public considerations and any other factors which may be identified from time-to-time which may be pertinent in selecting or implementing an Action Plan.

Action Plan

Resource Action Plan

The time period covered by the District’s Action Plan is the five-year period from 2012 through 2016.

The District has determined that to provide reliable electric power at the lowest practicable cost, consistent with sound business principles, the District will continue using its long-term entitlements of Hoover, SLCA/IP and Parker Davis power to supply a portion of the District’s projected long-term power requirements. The current federal resources and continuation of the Authority Hoover Resource Exchange Program and the Integrated Resource Scheduling procedures will be sufficient for the District to meet a portion of its monthly power and energy requirements through the short-term planning periods. Additional purchases of APS or other supplemental power will continue to be made to cover additional load requirements over the short-term. For the long-term planning period, the District has identified a need for additional resources, with the objective of increasing its options for firming resources purchased through the Resource Exchange Program and to serve as a successor for long-term contracts which will terminate in coming years. Therefore, ED3 has entered into a long-term power purchase agreement as a member of a group of public power entities. In addition, in 2012 the District intends to issue an RFP to cover the forecasted needs above the hydro and SPPR Group resources and possibly for other ancillary services. Service would commence at a date yet to be determined, but would likely be within the five-year IRP planning window. Arizona Authority for Public Power (a newly formed joint action agency), SPPR Group, nearby generating utilities and other marketing and scheduling entities will be the target recipients or conduits of the RFP. This is the only Resource Plan Action Item identified at this time. Further Action Items may be identified depending on the

13


responses to the RFP. Therefore, the District has identified the following Milestones: Action Item: In 2012 ED3 will issue an RFP to cover future forecasted needs. Milestone: Responses to the RFP will be evaluated for their adequacy. Milestone: If responses to the RFP do not produce a satisfactory result within a timeframe agreeable to ED3, the District will begin a process to identify an alternate Action Item.

Validation and Evaluation The District will evaluate and secure sufficient one or more additional supply side options, such as a purchase power contract, in order to meet forecasted loads at the lowest practicable cost, consistent with sound business principles. Securing sufficient purchased power resources is integral to maintaining the rate stability of ED3 and necessary to maintain system reliability. ED3’s review of resource options will include consideration for reliability of service, economics, rate impacts and price elasticity, environmental effects, regulatory impacts and risks, legal considerations and risks, competitive impacts, social acceptance and public considerations and any other factors which may be identified from time-to-time which may be pertinent in selecting or implementing an Action Plan. The District provides electricity to MSIDD for use in pumping groundwater to farmlands which are also served from surface water supplies from the CAP. CAP water is delivered to the MSIDD as well as to farmlands outside the irrigation district boundaries but still within ED3's boundaries. The CAP began delivering water to farmlands within the District in 1988 and the CAP policies for pricing and availability of CAP water have changed dramatically since the start of CAP deliveries. Since pumped water and CAP water are both essential in providing a reliable supply of water to farmed lands, the impacts of CAP water deliveries upon the District’s loads can be significant from year-to-year. CAP water price support programs and in-lieu programs are currently being implemented to encourage additional CAP water usage which impacts the District’s annual pumping loads. Even if CAP water could supply the entire water requirements for most farms, the electric supplies are needed to backup the surface water system to reliably meet the water requirements of the farmed lands during shortages on the Colorado River, canal outages and to supply ineligible farm lands due to CAP regulations. The pumps are also used to augment surface water supplies in peak months when canal limitations may restrict the amount of water which can be supplied from CAP. While the impact of CAP water is significant upon the seasonal electric requirements of the District, the District’s current resources and flexibility provided from the Hoover Resource Exchange Program and Integrated Resource Scheduling program should be sufficient for the District to adjust its resources to the changes in load

14


requirements which may result from changes in CAP water delivered to District land owners for the five-year planning horizon. The District continuously reevaluates the possible need for new resources, the availability of less costly resources and the potential for additional DSM activities. The District’s Resource Action Plan enhances customer financial stability by providing services that will enhance property values and provide long-term stability in electric power rates. The District will monitor any adjustments to the Plan for the long-term resource needs and will annually review its electric loads and resources for any significant changes. In the event the loads of the District are projected to materially increase above those levels forecasted in the Load and Resource Information, other than normal deviations due to cropping changes or weather impacts, the District will review its forecast and evaluate the need for modifying its IRP and notify Western accordingly. In any event, the District will evaluate its load forecast and resource information in detail every five years and refresh its IRP, in accordance with Western’s regulations.

Conservation Action Plan

The District has decided to continue certain conservation activities to promote and maintain energy efficiency and customer awareness for conserving electric, water, and land resources.

Period: Calendar Years 2012 through 2016 Activities: Transmission and Distribution System Improvements

Time-of-Use Load Management Program Tiered Demand & Energy Rates

Pump Inspection Program Customer Outreach and Education Residential Time-of-Use Rates Solar Rebate Program

Validation and Evaluation

Transmission and Distribution System Improvements ED3 has invested substantial resources, both fiscal and otherwise, in constructing and upgrading its transmission and distribution system to meet its load requirements. The District has been involved in several transmission expansion projects, including the ED5-Palo Verde Project and the Palo Verde-South East Valley 500kv Line Project (expected online in May 2014), to meet its projected long term needs for transmission capacity. The completion of these projects will provide the District with increased operational flexibility and reliability to its transmission system. The Palo Verde-South East Valley project will also provide the District access to competitive generation located at the Palo Verde

15


Hub. Expansion of and improvements to the distribution system also continue on a regular basis. Such improvements assist the District in maintaining a low level of losses and improving system reliability. Time-of-Use Load Management Program/ Tiered Demand & Energy Rates/Pump Inspection Program Several years ago, the District’s Board adopted and has continued an aggressive pumping load management program with the primary objective being the reduction of the District’s peak demand requirement. The District designed the Load Management Program to encourage voluntary load shifting and peak demand reduction through Tiered Demand & Energy Rates and the installation of time-of-use meters on several of the District’s accounts.

The District also has an agreement with the MSIDD, its single largest electric customer, for a pump optimization program which enables the District to select usage of the most efficient pumps and wells of least depth in order to maximize the cumulative productive capacity of all irrigation wells relative to their cumulative resource input. The District also has in place an aggressive well inspection program where the field service crews inspect and identify any defective components which could be repaired or replaced in order to increase the efficient operation of MSIDD’s pumps. The historical success of the District’s conservation program is evident in the significant increases in the system load factor over time. Additionally, the agreement with MSIDD incorporates a load shedding program where, when possible during peak summer months, pumping loads are turned off and water deliveries are made from existing canal capacity. This allows ED3 to essentially shave its peak load for three to four hours during the peak of the day. Customer Outreach and Education ED3 has its own website, upon which it has posted a series of energy savings tips and suggestions, customized for both the summer and winter seasons, and covering such subjects as appliances, lighting, pool equipment, and heating/cooling systems. The District also provides its customers with recommended links to further information on home energy audits and energy-savings improvements. ED3 also publishes flyers with energy savings tips which it distributes to its customers. Residential Time-of-Use Rates ED3 currently offers two time-of-use rates to its residential customers in order to encourage conservation during periods of peak energy consumption. One rate offers off-peak rates before 12 p.m. and after 7 p.m. on weekdays year-round, as well as all day on the weekends. The other rate offers off-peak rates before 9 a.m. and after 9 p.m. on weekdays year-round, as well as all day on weekends.

16


The rates are offered on a first-come, first-served basis as the necessary metering equipment becomes available. Solar Rebate Program On September 22, 2010, the ED3 Board of Directors voted to adopt the City of Maricopa’s Solar Rebate Program. The City of Maricopa’s Solar Rebate Program is designed to encourage the installation of photovoltaic (PV) systems on residential or commercial buildings. By adopting the City of Maricopa’s program, the District hopes to encourage its customers to purchase and install their own PV systems. The District provides both a residential incentive rate and small commercial incentive rate of $1.35 per installed DC-Watt with a per customer rebate limit of $10K. This is in addition to rebates offered by the City of Maricopa.

Environmental Effects

The District is required, to the extent practicable, to minimize adverse environmental effects of new resource acquisitions and document these efforts in the IRP. As noted above, the District has secured an additional long-term resource which will become effective January 1, 2015. In procuring this resource, the District worked collaboratively with a group of other similarly situated entities, known collectively as the SPPR Group. Options for meeting anticipated future needs were carefully considered, including the consideration of renewable resources. The SPPR Group also utilized an Independent Market Monitor bidding process overseen by the Arizona Corporation Commission to ensure the request for proposals process resulted in the best alternative, and provided an unbiased evaluation platform. However, no appropriate renewable resource was identified. The resource ultimately selected is output from a natural gas supplied plant. Selection of a gas fired generation source will help the District avoid future purchases from coal-fired generation, or market purchases from a blended fuel mix which may include nuclear or coal. For ED3, the SPPR resource is intended to ultimately augment or replace current supplemental power supply arrangements which utilize thermal resources. In addition, the acquisition of this resource will allow the District the flexibility to incorporate additional renewable resources which require firming, such as wind or hydro generation. Environmental impact will also be considered in evaluating any future resource acquisitions. Ultimately, the District intends to utilize hydroelectric resources to meet much of its electric loads. To the extent the District utilizes the Authority Hoover Resource Exchange Program and the Integrated Resource Scheduling procedures to optimally utilize the hydroelectric resources of the District and other similarly situated utilities, such efforts should be environmentally beneficial because such increased utilization would offset steam generation purchases. In addition to maximizing the hydroelectric resources, the District’s farm customers are involved in substantial water conservation programs in their farming practices. The investment made by the District’s customers in installed water conservation technology

17


is extensive and far-reaching. Their ongoing conservation practices and ongoing maintenance of conservation investments continue to conserve significant amounts of groundwater, and thereby electricity, annually. To the extent the District sponsors conservation activities and information activities with its customers, the conservation of groundwater is the fundamental achievement, which is environmentally beneficial and economically sound. In addition, the overall irrigation efficiency of each farm customer is heavily regulated by the State of Arizona through the Groundwater Management Act.

Public Participation The District has held one public meeting to discuss the development of the District’s IRP. Prior to the meeting, the District posted notice in advance of the meeting, giving the time and place of the meeting and specifying that the District would be considering a draft IRP at the meeting. The notice was posted in accordance with statutory open meeting law requirements. The notice stated that the draft IRP would be available to the public in advance of the meeting and that public comment on the draft IRP would be accepted at the meeting. A copy of the notice is attached as Appendix D. At the meeting, the draft IRP was presented to the Board. After discussion and the opportunity for public comment, the Board authorized the preparation of a final IRP, with such revisions as the Board deemed appropriate. There were no public comments.

APPENDIX A -- Map of District Service Territory

6 S 2 E6 S 2 E

7 S 4 E7 S 4 E

5 S 5 E5 S 5 E 5 S 6 E5 S 6 E5 S 3 E5 S 3 E

6 S 3 E6 S 3 E

4 S 3 E4 S 3 E

6 S 4 E6 S 4 E

4 S 4 E4 S 4 E

6 S 6 E6 S 6 E

5 S 4 E5 S 4 E

6 S 5 E6 S 5 E

4 S 1 E4 S 1 E

7 S 6 E7 S 6 E7 S 5 E7 S 5 E

4 S 2 E4 S 2 E

5 S 2 E5 S 2 E5 S 1 E5 S 1 E

4 S 5 E4 S 5 E

7 S 1 E7 S 1 E 7 S 2 E7 S 2 E

4 S 6 E4 S 6 E

6 S 1 E6 S 1 E

7 S 3 E7 S 3 E

8 S 5 E8 S 5 E8 S 1 E8 S 1 E 8 S 2 E8 S 2 E 8 S 3 E8 S 3 E 8 S 4 E8 S 4 E 8 S 6 E8 S 6 E

5 S 7 E5 S 7 E

4 S 7 E4 S 7 E

7 S 7 E7 S 7 E

6 S 7 E6 S 7 E

4 S 1 W4 S 1 W

5 S 1 W5 S 1 W

6 S 1 W6 S 1 W

7 S 1 W7 S 1 W

3 S 1 E3 S 1 E 3 S 3 E3 S 3 E 3 S 4 E3 S 4 E 3 S 5 E3 S 5 E 3 S 6 E3 S 6 E3 S 2 E3 S 2 E

8 S 7 E8 S 7 E8 S 1 W8 S 1 W

3 S 7 E3 S 7 E3 S 1 W3 S 1 W

88

13

24

12

25

36

13

24

36

12

24

12

25

13

01

07 11 11

01

0708 12 09

01

1009 080712 1008 09

01

34

020405

11

03

11

35

10

02

09

06

33

12 08 11 12100907 07 1008

29

0301

28

09

11

19

0201

36

13

11

11

31

11

07

11

04

11

05

36

30

11

03

11

0511

04

17

11

36

04

18

11

01

07

06

06

25

1111

05

12 0811

11 11

01

11

31

11

05 04

11

11

11

17 35

25

11

05

11

02

11

16

06

04

32

06

0506

11

01

0811

11

06

14

0311

11

33

23

12

12

24 22

27

06

20

15

32

13

01

17

35

20

14

11

24

22

20

05

36

29

30

19

21

28 28

25

32

07

18

24

03

27

29

03

09

32

36

23

31

15

10

16

26

12

1617

13

21

32

20

26

35

03

22

24

29

34

04

15

02

12

36

10

17

23

13

34

22

18

17

01

19

25

29

05

34

20

20

24

08

28

04

03

13

23

03

34

34

21

17

02

04

23

14

26

26

13

08

13

29

21

30

15

14

14

25

20

02

09

29

03

36

05

18

02

17

23

23

34

02

14

31

10

32

01

21

14

33

24

16

24

12

35

33

01

16

26

32

06

34

18

0535

28

29

16

02

09

02

03

03

02

27

12

25

20

13

08

32

20

35

2529

27

12

21

1916

18

10

06

23

06

29

10

25

32

14

05

36

25

36

21

28

08

2823

16

24

33

22

03

10

16

08

33

20

16

2124

13

25

08

35

14

07

04

09

10

13

31

01

07

36

33

31

17 17

33

05

32

32

29

26

09

15

27

14

08

14

35

3636

29

14

34

26

2524

21

32

09

36

25

30

05

25

25

08

10

16

22

06

2023

03

09

24

26

19

02

08

13

2124

24

12

17

18

24

17

20

22

20

26

08

14

2023

23

33

21

02

09

13

30

23

10

27

23

12

22

28

32

32

2828

36

18

24

30

23

08

27

24

18

06

07

01

28

26

01

13

33

28

28

04

03

32

32

35

26

34

12

02

23

35

17

30

14

35

29

10

01

10

32

12

29

05

09

35

22

33

28

09

04

09

21

09

20

21

2423

0808

22

19

25

35

19

21

26

01

24

02

2625

27

04

36

25

05

34

33

16

10

32

03

26

10

34

09

32

35

04

20

36

29

14

10

10

23

14

04

21

12

27

04

2721

10

03

36

03

17

25

33

27

36

12

14

05

2821

02

08

27

05

28

33

25

16

26

34

29

03

26

32

05

02

24

17

0815

15

28

07

06

26

15

25

36

34

15

29

27

34

17

18

20

23

19

36

08

25

17

27

20

31

02

13

04

34

35

21

08

14

24

17

20

09

02

24

03

23

35

23

36

29

24

12

28

13

02

25

1617

21

33

31

35

23

01

03

25

33

26

20

15

32

2729

14

32

35

04

10

35

29

09

16

30

34

28

17

29

34

36

33

23

14

21

27

02

05

21

22

36

05

36

20

20

35

12

26

05

14

08

34

15

05

17 15

02

23

34

06

20

13

32

25

03

10

08

24

31

15 16

06

13

32

19

22

15

29

35

18

12

13

09

19

29

05

12

17

14

31

21

3532

20

04

23

05

06

19

15

29

20

13

24

35

09

26

26

25

34

31

18

12

13

28

30

30

35

26

01

36

33

35

07

22

29

34

14

24

26

01

13

23

02

14

25

01

04

22

02

32

1921

29

14

23

01

27

17

34

17

33

26

33

32

14

05

07

23

25

24

13

18

31

15

04 05

22

04

26

19

21

07

26

13

12

30

23

02

08

07

24

24

27

28

31

25

22

09

18

27

36

10

33

03

19

3532

20

20

31

06

28

02

12

24

10

23

02

14

19

13

01

05

09

18 1509

2224

01

07

21

25

08

05

28

08

20

36

04

06

13

22

08

12

21

25

17

04

1414

20

27

22

30

25

04

27

14

12

30

16

31

24

29

04

10

23

03

22

17

28

01

29

34

04

26

20

34

04 01

20

12

17

26

26

09

33

3029

19

10

06

33 36

07

01

05

19

16

14

09

31

30

32

05

32

26

13

08

33

32

34

05

36

31

03

31

09

20

21

33

22

01

06

30

07

36

23

19

15

32

02

12

16

01

10

33

08

10

22

29

29

17

08

33

33

25

34

06

31

26

20

07

03

35

02

02

22

09

07

12 07

09

13

01

06

34

35

09

30

33

35

31

17

22

1512

17

23

33

29

33

15

01

30

18

16

06

30

08

32

35

31

21

14

31

26

30

30

30

28

22

07

12

35

0710

36

18

19

23

31

27

35

18

02

22

01

01

2019

29

07

19

07

18

19

10

27

30

31

03

31

19

18

06

31

19

13

36

35

06

17

18

19

30

18

31

06

31

06

19

30

30

07

17

14

30

30

07

18

07

19

04

18

07

1919

18

30

31

18

31

07

30

19

08

18

06

30

19

06

13

06

18

19

1818

30

17

19

3026

31

18

31

07

06

07

06

31

35

18

13

06

07

31

07

24

36

34

18

3332

30

03

34

10

46

19

15

2227

34

03

18

1621

10

09

03

15

2227

34

15

33

09

04

22

10

28

16

28

04

21

15

27

21

34

33

22

16

27

04

03

10

09

15

10

34

2227

34

03

22

03

27

34

10

15

27

34

22

03

0205 04 030603 0504

04

02 01

03 0205

27

1617

22

28

16

282927

1513

26 27

15

25

16

21

16

14

21 22

28

15

16

1516

15

1516

21

16

16

2827 27

14

16

15

22

28

23

28

15 16

27 2827

15

25

2641

35

42

15

2253 40 3728

45 525147 50

25 2829 2726 2630 25 2930 28 27

43

3026 25 2526 2629 27 2830 2728 29

23

27

23 2323

4433

Electrical District Number Three − DISCLAIMER:K.R. Saline & Associates, PLC Does not warrant the accuracy or location of the facilities shown

krsa

data

2\20

11\IR

P\M

AP\

ED3

C

reat

ed: 0

8/20

06 E

dite

d: 0

6/14

/201

1 -

BLS

arc

view

10

Sour

ces:

Tow

nshi

p R

ange

Sec

tion:

201

0 ES

RI

D

istri

ct B

ound

ary

: Ve

rifie

d by

KR

SA w

ith

lega

l res

olut

ion

Se

rvic

e Te

rrito

ry a

men

ded

in 2

011

LegendTownships

Sections

County Boundary

District Boundary

A R I Z O N AA R I Z O N A

ED3

0 3 61.5 Miles

1 in = 5 miles

PinalPinal

SECTION B

RATES

APPENDIX B -- Current Rate Schedules

SECTION B – RATE SHEETS Last Update: 01/26/2011 RATE

NUMBER DESCRIPTION

REVISION NUMBER

CURRENT DATE

01 Residential Service 8 01/01/11

01 TOU - A Residential Service – Time of Use (TOU) 9:00 a.m. to 9:00 p.m. 6 01/01/11

01 TOU - B Residential Service – Time of Use (TOU) Noon to 7:00 p.m. 1 01/01/11

02 Small Commercial Service 6 11/21/08

03 Large Commercial Service 5 11/21/08

04 Industrial Service 7 11/21/08

05 - D Agricultural Irrigation Pumping Service (Steps 1 & 2) 10 01/01/11

05 - H Agricultural Irrigation Pumping Service (All) 3 01/01/11

06 Agricultural Related Pumping Service 8 08/30/10

07 Non-Agricultural Pumping Service 6 11/21/08

08 Cotton Gin Service 6 11/21/08

09 Dusk to Dawn Lighting 6 (Corrected)

01/01/11

10 Gates and Turnouts 8 01/10/10

11 Street Lighting 5 (Corrected) 01/01/11

12 Unmetered Load 3 11/21/08


R ATp AIt TSapS RT

A12 TP RIt T 12

REVISION NO

Applicability To residential power with no

Availability n all areas wihe availability

Type of ServSingle-phase,and amendedprimary 12.5 kService does

Rates The monthly c

Adjustments1. The Rene2. The bill is

Tax Plus applicabl

Reconnect Cn the event ahat ED3 disco

The reconnec

1. The recon2. The Mont

Basic ServicEnergy Char First All A MONTHLY M

E

O.: 8

use only in so motor over 5

ithin the Distry of power an

ice 60 Hertz 120

d by the DistrickV feeders thnot include in

charges for th

ewable Energ

subject to the

le sales tax to

Charge consumer reonnect the ele

ct charge shal

nnection charhly Minimum

ce Charge / Mrge / kWh t 500 kWh

Additional kWh

MINIMUM BIL

ELECTRICA

single private 5HP, heating

ict as now sed energy as d

0 / 240 volts. ct Board of Dat are require

ndividual unde

his class of se

y Surcharge e Purchased

o the above.

equests that Eectric service

ll be the great

ge outlined inBill times the

Month

h

LL

AL DISTRIC

RARESIDE

residences oand cooling s

rved. Subjecdetermined in

Subject to alirectors. “Un

ed to be consterground serv

ervice shall co

Rider shall bePower Cost A

ED3 reconnec to the same

ter of:

n ED3's Servie number of m

CT NO. 3 O

ATE NO. 01 NTIAL SERV

r apartments served throug

ct to the requin the opinion o

ll standard poderground Setructed undervice drops fro

onsist of a sum

e applied to aAdjustor as se

ct electric servlocation, the

ce Rules andmonths the se

Overhead$12

$0.09$0.09

$30

OF PINAL C

VICE

R

for lighting, agh one meter.

rements of thof the District

olicies, conditiervice” applierground speciom overhead l

mmation of th

all retail electret forth in the

vice within a tconsumer sh

d Regulationsrvice has bee

d Service .50

915 915

.00

COUNTY

REVISION EF

appliances do.

he primary put.

ions, rules anes to all customifically for thelines.

he following c

ric service unde PPCA Rider

twelve (12) mhall pay ED3 a

; or en disconnect

UPri

FFECTIVE: 0

omestic single

rposes of the

nd regulationsmers who are

eir area. Unde

osts based on

der this schedr.

month period oa reconnect c

ted.

ndergroundmary Service

$16.50

$0.0900 $0.1150

$30.00

01/01/2011

e-phase

e District and

s as adopted e served off oerground

n usage:

dule.

of requesting charge.

e

f


REV ApplTo reand m AvaiIn all availa TypeSinglamen Term1. S

(2. C

m RateThe m

Adju1. T2. T Tax Plus RecoIn theED3 The r 1. T2. T

ISION NO.: 6

licability esidential usemeasured thr

lability areas within ability of nece

e of Service le-phase, 60 nded by the D

ms and CondService underTOU) meter.

Customer’s seminimum of tw

es monthly charg

Basic ServiceEnergy Charg On P Off P MONTHLY MOn Peak Hou(Monday – Fr Off Peak Hou

ustments The RenewabThe bill is sub

applicable sa

onnect Charge event a condisconnect th

reconnect cha

The reconnecThe Monthly M

E

6

e only in singlerough one me

the District aessary equipm

Hertz 120 / 24District Board

itions r this rate sch

electing Timewelve (12) mo

ges for this cl

Charge / monge / kWh Peak kWh

Peak kWh

INIMUM BILL urs riday)

urs

ble Energy Subject to the Pu

ales tax to the

ge nsumer requehe electric ser

arge shall be

ction charge oMinimum Bill t

ELECTRICA

RES

e private resideter.

s now servedment, power a

40 volts. Subof Directors.

hedule will bec

-of-Use Servionths.

ass of service

Math

9

All

urcharge Rideurchased Pow

e above.

sts that ED3 rvice to the sa

the greater o

outlined in EDtimes the num

AL DISTRIC

RATE N

SIDENTIAL S

(9:00 A.

dences or a s

d. Subject to and energy as

bject to all sta

come effectiv

ice under this

e shall consis

OVER(9:00 A

SUMMERay – October

$13.50

$0.1388

$0.0449

$30.00 9:00 a.m. to

9:00 p.m.

l other hours

er shall be appwer Cost Adju

reconnect eleame location,

of:

D3's Service Rmber of month

CT NO. 3 O

NO. 01 TOU –

SERVICE - TI

M. TO 9:00 P

single unit in a

the requiremes determined

andard policie

ve only after th

s rate schedul

st of a summa

RHEAD TOU AM – 9:00 PM)

WINNovemb

$13

$0.

$0.0

$309:00 a

9:00

All othe

plied to all retstor as set fo

ectric service the consume

Rules and Reghs the service

OF PINAL C

– A

ME-OF-USE

P.M.)

R

a multiple apa

ents of the prin the opinion

es, conditions

he District has

le will be requ

ation of the fo

NTERber - April 3.50

1128

0449

0.00 a.m. to0 p.m.

er hours

tail electric seorth in the PPC

within a twelver shall pay E

gulations; or e has been di

COUNTY

REVISION EF

artment throug

rimary purposn of the Distri

, rules and re

s installed the

uired to rema

ollowing costs

UND(9:0

SUMMERMay – Octob

$17.50

$0.1581

$0.0511

$30.00 9:00 a.m. t

9:00 p.m.

All other ho

ervice under tCA Rider.

ve (12) monthED3 a reconne

isconnected.

FFECTIVE: 0

gh one point

ses of the Distict.

egulations as

e required Tim

in on this sch

based on us

DERGROUND00 AM – 9:00 P

R ber Nove

to .

ours

9:9

All o

this schedule.

h period of reect charge.

01/01/2011

of delivery

trict and the

adopted and

me-of-Use

hedule for a

age:

TOU PM) WINTERember - April

$17.50

$0.1285

$0.0511

$30.00 00 a.m. to

9:00 p.m.

other hours

.

questing that


R ATd AIt TSa T1

2

RT

BaEn

MO O A12 TP RIt T 12

REVISION NO

Applicability To residential delivery and m

Availability n all areas wihe availability

Type of ServSingle-phase,and amended

Terms and C1. Service u

Use (TOU2. Customer

a minimum

Rates The monthly c

asic Service Cnergy Charge /

ON

OFF

MONTHLY MINN Peak Hours

FF Peak Hours

Adjustments1. The Rene2. The bill is

Tax Plus applicabl

Reconnect Cn the event ahat ED3 disco

The reconnec

1. The recon2. The Mont

E

O.: 1

use only in smeasured thro

ithin the Distry of necessary

ice 60 Hertz 120

d by the Distric

onditions nder this rate

U) meter. r’s selecting Tm of twelve (1

charges for th

harge / Month / kWh

Peak kWh

F Peak kWh

IMUM BILL (Monday – Fri

s

ewable Energ

subject to the

le sales tax to

Charge consumer reonnect the ele

ct charge shal

nnection charhly Minimum

ELECTRICA

R

single private ough one met

ict as now sey equipment,

0 / 240 volts. ct Board of D

e schedule wil

Time-of-Use S12) months.

his class of se

M

day)

A

y Surcharge e Purchased

o the above.

equests that Eectric service

ll be the great

ge outlined inBill times the

AL DISTRIC

RATE

ESIDENTIAL

(12:00

residences oter.

rved. Subjecpower and e

Subject to alirectors.

l become effe

Service under

ervice shall co

OVE(12:00

SUMMERMay – Octobe

$13.50

$0.18966

$0.04753

$30.00 12:00 p.m. to

7:00 p.m.

All Other Hour

Rider shall bePower Cost A

ED3 reconnec to the same

ter of:

n ED3's Servie number of m

CT NO. 3 O

E NO. 01 TOU

L SERVICE -

NOON TO 7:

r a single unit

ct to the requinergy as dete

ll standard po

ective only aft

r this rate sch

onsist of a sum

ERHEAD TOUNOON – 7:00

r W

Novem$

$0

$0

$

rs

12:07:

All O

e applied to aAdjustor as se

ct electric servlocation, the

ce Rules andmonths the se

OF PINAL C

U - B

TIME-OF-US

:00 PM)

R

t in a multiple

rements of thermined in the

olicies, conditi

ter the Distric

hedule will be

mmation of th

UPM)

WINTERmber - April $13.50

0.15382

0.04753

$30.00 00 p.m. to:00 p.m.

ther Hours

all retail electret forth in the

vice within a tconsumer sh

d Regulationsrvice has bee

COUNTY

SE

REVISION EF

e apartment th

he primary pue opinion of t

ions, rules an

ct has installed

required to re

he following c

U(12

SUMMMay – Oc

$17.5

$0.216

$0.054

$30.012:00 p.m

7:00 p

All Other

ric service unde PPCA Rider

twelve (12) mhall pay ED3 a

; or en disconnect

FFECTIVE: 0

hrough one po

rposes of thehe District.

nd regulations

d the required

emain on this

osts based on

UNDERGROUN2:00 NOON – 7ER

ctober No50

601

413

00 m. to .m.

Hours A

der this schedr.

month period oa reconnect c

ted.

01/01/2011

oint of

e District and

s as adopted

d Time-of-

s schedule for

n usage:

ND TOU7:00 PM)

WINTERovember - Apr

$17.50

$0.17519

$0.05413

$30.00 12:00 p.m. to

7:00 p.m.

All Other Hours

dule.

of requesting charge.

r

ril

s


RATE NO. 02

SMALL COMMERCIAL SERVICE

REVISION NO.: 6 REVISION EFFECTIVE: 11/21/08 Applicability To all small retail businesses such as stores, shops, schools and other enterprises without demand metering and whose estimated monthly maximum demand is less than 50 kW. Service is applied at one (1) point of delivery and measured through one meter. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Single and three phase, 60 Hertz 120 / 240 and 480 overhead or underground. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. “Underground Service” applies to all customers who are served off of primary 12.5 kV feeders that are required to be constructed underground specifically for their area. Underground Service does not include individual underground service drops from overhead lines. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage:

1. The Renewable Energy Surcharge Rider shall be applied to all retail electric service under this schedule. Adjustments

2. The bill is subject to the Purchased Power Cost Adjustor as set forth in the PPCA Rider. Tax Plus applicable sales tax to the above.

Overhead Service

Underground Primary Service

Basic Service Charge / Month $18.00 $45.00 Energy Charge / kWh First 1,000 kWh All Additional kWh

$0.0850

$0.1070

$0.0850

$0.1070

Monthly Minimum $18.00 $45.00


RATE NO. 03

LARGE COMMERCIAL SERVICE

REVISION NO.: 5 REVISION EFFECTIVE: 11/21/08 Applicability To commercial customers whose monthly maximum demand is greater than 50 kW for three (3) consecutive months in any continuous twelve (12) month period ending with the current month. Service is applied at one point of delivery and measured through one meter with a demand reading. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Single and three phase, 60 Hertz 120 / 240 and 480 overhead or underground. Transformation is included in this rate. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. “Underground Service” applies to all customers who are served off of primary 12.5 kV feeders that are required to be constructed underground specifically for their area. Underground Service does not include individual underground service drops from overhead lines. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage:


2. The bill is subject to the Purchased Power Cost Adjustor as set forth in the PPCA Rider. Tax Plus applicable sales tax to the above. Determination of kW The actual kW supplied during the period of maximum use during the month as determined from reading of the District’s meter.

Overhead Service


Basic Service Charge / Month $32.55 $83.00 Demand Charge / kW-mo $11.08 $11.44 Energy Charge / kWh All kWh

$0.0553

$0.057 Monthly Minimum $32.55 $83.00


RATE NO. 04

INDUSTRIAL SERVICE

Page 1 of 2

REVISION NO.: 7 REVISION EFFECTIVE: 11/21/08 Applicability To non-agricultural customers whose monthly maximum demand is greater than 1,000 kW for three (3) consecutive months in any continuous twelve (12) month period ending with the current month. Service is applied at one (1) point of delivery and measured through one (1) meter with an actual or estimated demand reading. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Single and three phase, 60 Hertz 120 / 240 volt and 277 / 480 volt overhead. Transformation is included in this rate. Conditions 1. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board

of Directors.

2. “Underground Service” applies to all customers who are served off of primary 12.5 kV feeders that are required to be constructed underground specifically for their area. Underground Service does not include individual underground service drops from overhead lines.

3. Customers served under this rate schedule are subject to the Facilities Charge and the Facilities Rider unless

specified elsewhere. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage:

Tax Plus applicable sales tax to the above.

Overhead Service


Basic Service Charge / Month $37.00 $83.00 Demand Charge / kW-Mo $7.30 $7.30 Facility Charge / kW-Mo (Customer Specific – See Facilities Rider)

$3.25 $3.25

Energy Charge / kWh All kWh

$0.0501

$0.0501 Monthly Minimum $37.00 $83.00


RATE NO. 04

INDUSTRIAL SERVICE

Page 2 of 2

REVISION NO.: 7 EFFECTIVE: 11/21/08 Determination of kW The actual kW supplied during the period of maximum use during the month as determined from reading of the District’s meter. Adjustments 1. The Renewable Energy Surcharge Rider shall be applied to all retail electric service under this schedule. 2. The bill is subject to the Purchased Power Cost Adjustor as set forth in the PPCA Rider.

3. The District may increase or decrease billings based on any taxes, fees or charges levied by any governmental

authority for services provided under this schedule.

4. If the power factor falls below ninety-five percent (95%) at any point during any billing period, then the District man: a. Require that the customer correct the power factor to an acceptable level. b. Adjust the billing demand based on the following formula:

Minimum Monthly Required Power Factor = 95% Actual Average Power Factor (PF) = kWh / (kWh2 + kVARh2) 1/2

Adjusted Billing Demand = Monthly kW Demand *(1 + (.95 – PF))

c. Require the customer, at their cost, to be continuously metered with a separate meter that requires KVA, KVARs or actual power factor.


ELECTRICAL DISTRICT NO. 3 OF PINAL COUNTY

RATE NO. 05 – D

AGRICULTURAL IRRIGATION PUMPING SERVICE

REVISION NO.: 10 REVISION EFFECTIVE: 01/01/2011 Applicability To all irrigation motors operated by the Maricopa Stanfield Irrigation & Drainage District for the exclusive use of pumping water for the purposes of irrigating farm fields or to fill canals which are ultimately used to irrigate fields. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Three phase, 60 Hertz 120 / 240 and 480 overhead. Transformation is included in this rate. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage: Determination of Billing Demand The actual coincident kW supplied for all MSIDD wells during the single hour of maximum use in the month as determined from the MSIDD hourly log of well operations. * Step 1 - Energy billed under Step 1 will not exceed the amount of allocated monthly scheduled hydro energy. Monthly energy above Step 1 allocated hydro amounts will be billed at the Step 2 Rate.

Adjustments 1. For this rate schedule, the Purchased Power Cost Adjustor is incorporated into the base rates above. Tax Exempt.1

1 Per Arizona Attorney General Opinion No. 60-43 / R. S. Lynch Memos Dated 01/26/10 & 10/11/05

Overhead Service

Basic Service Charge / Month $14.63 Demand Charge / kW-Mo $7.00 Energy Charge / kWh Step 1 * Step 2

$0.0251 $0.0594

Monthly Minimum $14.63



RATE NO. 05 – H

AGRICULTURAL IRRIGATION PUMPING SERVICE

REVISION NO.: 3 REVISION EFFECTIVE: 01/01/2011 Applicability To all irrigation motors other than those operated by the Maricopa Stanfield Irrigation & Drainage District for the exclusive use of pumping water for the purposes of irrigating farm fields or to fill canals which are ultimately used to irrigate fields. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Three phase, 60 Hertz 120 / 240 and 480 overhead. Transformation is included in this rate. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage: Adjustments 1. For this rate schedule, the Purchased Power Cost Adjustor is incorporated into the base rates above. Determination of kW The actual kW supplied during the period of maximum use during the month as determined from reading of the District’s meter. Tax Exempt.1


Overhead Service

Basic Service Charge/Month $14.63 Demand Charge/kW-mo $5.42

Energy Charge/kWh All kWh

$0.0304




RATE NO. 06

AGRICULTURAL RELATED PUMPING SERVICE

REVISION NO.: 8 REVISION EFFECTIVE: 08/30/2010 Applicability To all irrigation motors operated for the exclusive use of pumping water for agricultural related purposes other than irrigating farm fields. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Three (3) phase, 60 Hertz 120 / 240 and 480 overhead. Transformation is included in this rate. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage:

Adjustments 1. The Renewable Energy Surcharge Rider shall be applied to all retail electric service under this schedule. 2. The bill is subject to the Purchased Power Cost Adjustor as set forth in the PPCA Rider. Determination of kW The actual kW supplied during the period of maximum use during the month as determined from reading of the District’s meter. Tax Exempt.1


Overhead Service

Basic Service Charge / Month $14.63 Demand Charge / kW-Mo $5.00 Energy Charge / kWh All kWh

$0.0280



RATE NO. 07

NON - AGRICULTURAL PUMPING SERVICE

REVISION NO.: 6 REVISION EFFECTIVE: 11/21/08 Applicability To all motors operated for the exclusive use of pumping water for all non-agricultural related purposes. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Single and three (3) phase, 60 Hertz 120 / 240 and 480 overhead. Transformation is included in this rate. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage:


2. The bill is subject to the Purchased Power Cost Adjustor as set forth in the PPCA Rider. Determination of kW The actual kW supplied during the period of maximum use during the month as determined from reading of the District’s meter. Tax Plus applicable sales tax to the above.

Overhead Service


Basic Service Charge / Month $31.64 $79.10 Demand Charge / kW-Mo $5.39 $5.39

Energy Charge / kWh $0.0723 $0.0723 Monthly Minimum $31.64 $79.10


RATE NO. 08

COTTON GIN SERVICE

REVISION NO.: 6 REVISION EFFECTIVE: 11/21/08 Applicability To all cotton seed milling gins which are primarily operated on a seasonal basis. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Three (3) phase, 60 Hertz 120 / 240 and 480 service. Transformation is included in this rate. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. Rates Summer Season: March through September Winter Season: October through February

The monthly charges for this class of service shall consist of a summation of the following costs based on usage:


2. The bill is subject to the Purchased Power Cost Adjustor as set forth in the PPCA Rider. Tax Plus applicable sales tax to the above. Determination of kW The actual kW supplied during the period of maximum use during the month as determined from reading of the District’s meter.

SUMMER Season

WINTER Season

Basic Service Charge / Month $36.20 $36.20 Demand Charge / kW-Mo $14.97 $8.07 Energy Charge / kWh All kWh

$0.0503

$0.0503

Monthly Minimum $36.20 $36.20



RATE NO. 09

DUSK TO DAWN LIGHTING

REVISION NO.: 6 (Corrected) REVISION EFFECTIVE: 01/01/2011 Applicability To all customers for the purpose of outdoor lighting other than street and highway lighting service of privately owned property. Electric service is provided from dusk to dawn. ED3 will install, own, operate and maintain the complete lighting installation, including lamp replacements. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Rates Customer is responsible for all installation costs. $100 Minimum Installation Charge. A non-refundable, one-time Security Deposit per light of $15 is also required. The monthly charge shall be computed at the following rates for the standard facility utilized to provide service. Tax Plus applicable sales tax to the above.

Lamp Type Lamp Wattage Lumens kWh / Month Charges per Lamp per Month

Mercury Vapor (Closed *) 175 W 7,900 74.5 $7.70

400 W 21,000 168.5 $17.68

High Pressure Sodium 50 W 4,000 20 $7.03

70 W 5,800 28.6 $7.22 100 W 9,500 40.3 $7.53 150 W 16,000 66.6 $8.23 200 W 22,000 84.9 $9.78 250 W 30,000 99 $10.46 400 W 50,000 153 $18.01

Low Pressure Sodium 35 W 4,800 21.7 $7.89

55 W 8,000 28.9 $8.52 90 W 13,500 45.2 $9.64 135 W 22,500 62.8 $12.21 185 W 33,000 79 $14.19

Metal Halide 75 W 5,600 32.7 $7.22 100 W 8,500 44.5 $7.53 175 W 12,000 74.2 $8.89 250 W 19,500 101.8 $11.09

* Installation no longer allowed by the EPA.


RATE NO. 10

GATES & TURNOUTS

REVISION NO.: 8 REVISION EFFECTIVE: 01/01/2010 Applicability To all irrigation motors operated for the exclusive use of opening or closing gates or turnouts for the purposes of irrigating farm fields or to fill canals which are ultimately used to irrigate fields. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Type of Service Three (3) phase, 60 Hertz 120 / 240 and 480 overhead. Transformation is included in this rate. Subject to all standard policies, conditions, rules and regulations as adopted and amended by the District Board of Directors. Rates The monthly charges for this class of service shall consist of a summation of the following costs based on usage:

Adjustments 1. For this rate schedule, the Purchased Power Cost Adjustor is incorporated into the base rates above. Tax Plus applicable sales tax to the above.

Overhead Service

Basic Service Charge / Month N/A Demand Charge / kW-Mo $5.00 Energy Charge / kWh All kWh

$0.0280

Monthly Minimum Based on 2 kW

and 100 kWh



RATE NO. 11

STREET LIGHTING

REVISION NO.: 5 (Corrected) REVISION EFFECTIVE: 01/01/2011 Applicability To all customers for the purpose of outdoor lighting of streets alleys, thoroughfares, public parks and playgrounds. Service is dusk to dawn and District will own, operate and maintain the street lighting system including lamps and glass replacements. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Rates The monthly charge shall be computed at the following rates for the standard facility utilized to provide service. Tax Plus applicable sales tax to the above. Notes 1. All facilities shall be owned, operated and maintained by ED3. 2. HPS = High Pressure Sodium. 3. Street lighting facilities installed under this rate schedule are the type currently being provided by ED3 as a Standard

Facility. The current Standard Facility consists of a galvanized steel pole, lamp, and accessories. 4. If customer requests facilities that are not covered by the standard facility (provided by ED3), the customer shall pay

the difference between the standard facility and the requested facility.

Lighting Charges

Type Lumen kWh / Month Charges per Lamp Per Month

Pedestrian Light 9,500 HPS 100 $32.45

Pedestrian Light 16,000 HPS 150 $34.73

Single Fixture Light 28,000 HPS 250 $37.04

Single Fixture Light 50,000 HPS 400 $41.88

Double Fixture Light 56,000 HPS 500 $50.62


RATE NO. 12

UNMETERED LOAD

REVISION NO.: 3 REVISION EFFECTIVE: 11/21/08 Applicability All customers who require electric service where demand and energy requirements are constant and subject to the limitations set forth in the notes section of this schedule. Service is applied at one (1) point of delivery where a fixed monthly energy use is determined by the District at service initiation and is not measured by metering equipment. Availability In all areas within the District as now served. Subject to the requirements of the primary purposes of the District and the availability of power and energy as determined in the opinion of the District. Rates


2. The bill is subject to the Purchased Power Cost Adjustor as set forth in the PPCA Rider. Tax Plus applicable sales tax to the above. Notes 1. This rate schedule is applicable only to loads where monthly demand (kW) and energy (kWh) requirements remain

constant. Monthly demand and energy requirements may not exceed 2 kW or 1460 kWh at 120 volts and 4 kW or 2920 kWh at 240 volts for each delivery point. Determination of fixed energy use will be based on an average 730 hour month.

2. Prior written approval by an authorized District representative is required before service is implemented under this schedule. Determination of fixed energy use amount will be agreed upon between Customer and District before service is implemented.

3. Prior written approval by an authorized District representative is required for any change in loads. 4. The District shall have the right to inspect the customer’s load facilities at any time to ensure compliance with the

provisions of this rate schedule.

Unmetered Service Basic Service Charge / month $6.85 Energy Charge / kWh $0.1152


Appendix C.1 – Historical Load Information and Load Forecast

Page 1 of 5 K. R. Saline & Associates, PLC 1/18/2012

ELECTRICAL DISTRICT NO. 3 CY 2011-2020 LOAD FORECAST

PREPARED OCTOBER 2011

BASELINE ED3 ONLY FORECAST

Year Meter

Connections % Growth Annual kWh %

Growth %Loss Factor

Total Energy Requirements

Avg Annual Load Factor Peak Demand

Avg Kwh/Cust

AC

TUA

L

2002 508 132,263,474 12.26% 150,744,785 52.2% 32,969 260,318

2003 1,458 187.0% 204,884,776 55% 6.25% 218,543,761 52.1% 47,885 140,508

2004 2,631 80.4% 246,754,534 20% 4.12% 257,357,670 50.3% 58,437 93,802

2005 5,617 113.5% 260,647,474 6% 6.02% 277,343,556 45.3% 69,896 46,402

2006 11,300 101.2% 366,077,985 40% 3.66% 379,985,452 42.4% 102,207 32,398

2007 14,335 26.9% 482,159,796 32% 4.30% 503,824,238 46.9% 122,675 33,635

2008 16,794 17.2% 555,705,060 15% 5.84% 590,171,049 44.9% 150,084 33,090

2009 17,752 5.7% 541,119,328 -2.6% 5.07% 570,019,307 45.0% 144,624 30,482 2010 18,779 5.8% 518,243,890 -4.2% 3.25% 535,652,600 44.1% 138,650 27,597

FOR

EC

AS

T

2011 21,007 11.9% 622,359,352 20.1% 4.81% 653,833,250 43.2% 172,619 29,626

2012 21,210 1.0% 600,283,612 -3.5% 4.81% 630,641,097 44.5% 161,935 28,302

2013 21,464 1.2% 615,873,929 2.6% 4.81% 647,019,847 44.5% 166,141 28,693

2014 21,720 1.2% 635,626,464 3.2% 4.81% 667,771,305 44.5% 171,470 29,265

2015 22,027 1.4% 641,752,788 1.0% 4.81% 674,207,449 44.5% 173,122 29,134

2016 22,339 1.4% 646,265,568 0.7% 4.81% 678,948,449 44.5% 174,340 28,929

2017 22,706 1.6% 651,606,528 0.8% 4.81% 684,559,512 44.5% 175,780 28,697

2018 23,079 1.6% 657,040,677 0.8% 4.81% 690,268,476 44.5% 177,246 28,469

2019 23,510 1.9% 663,357,231 1.0% 4.81% 696,904,469 44.5% 178,950 28,216

2020 23,949 1.9% 669,799,798 1.0% 4.81% 703,672,849 44.5% 180,688 27,967





PESSIMISTIC ED3 ONLY FORECAST

Year Meter


Growth %Loss Factor



Avg Kwh/Cust

AC

TUA

L

2002 508 132,263,474 12.26% 150,744,785 52.2% 32,969 260,318

2003 1,458 187% 204,884,776 55% 6.25% 218,543,761 52.1% 47,885 140,508

2004 2,631 80% 246,754,534 20% 4.12% 257,357,670 50.3% 58,437 93,802

2005 5,617 114% 260,647,474 6% 6.02% 277,343,556 45.3% 69,896 46,402

2006 11,300 101% 366,077,985 40% 3.66% 379,985,452 42.4% 102,207 32,398

2007 14,335 27% 482,159,796 32% 4.30% 503,824,238 46.9% 122,675 33,635

2008 16,794 17% 555,705,060 15% 5.84% 590,171,049 44.9% 150,084 33,090

2009 17,752 5.7% 541,119,328 -2.6% 5.07% 570,019,307 45.0% 144,624 30,482 2010 18,779 5.8% 518,243,890 -4.2% 3.25% 535,652,600 44.1% 138,650 27,597

FOR

EC

AS

T

2011 20,954 11.6% 622,359,352 20.1% 4.81% 653,833,250 43.2% 172,619 29,701

2012 21,142 0.9% 569,902,627 -8.4% 4.81% 598,723,688 44.5% 153,740 26,955

2013 21,380 1.1% 575,021,667 0.9% 4.81% 604,101,608 44.5% 155,120 26,896

2014 21,620 1.1% 580,183,696 0.9% 4.81% 609,524,691 44.5% 156,513 26,835

2015 21,912 1.4% 586,094,360 1.0% 4.81% 615,734,269 44.5% 158,108 26,747

2016 22,209 1.4% 590,388,485 0.7% 4.81% 620,245,555 44.5% 159,266 26,584

2017 22,560 1.6% 595,473,444 0.9% 4.81% 625,587,671 44.5% 160,638 26,396

2018 22,917 1.6% 600,647,390 0.9% 4.81% 631,023,273 44.5% 162,033 26,210

2019 23,332 1.8% 606,663,950 1.0% 4.81% 637,344,102 44.5% 163,656 26,001

2020 23,755 1.8% 612,800,841 1.0% 4.81% 643,791,347 44.5% 165,312 25,796





OPTIMISTIC ED3 ONLY FORECAST

Year Meter


Growth %Loss Factor



Avg Kwh/Cust

AC

TUA

L

2002 508 132,263,474 12.26% 150,744,785 52.2% 32,969 260,318

2003 1,458 187% 204,884,776 55% 6.25% 218,543,761 52.1% 47,885 140,508

2004 2,631 80% 246,754,534 20% 4.12% 257,357,670 50.3% 58,437 93,802

2005 5,617 114% 260,647,474 6% 6.02% 277,343,556 45.3% 69,896 46,402

2006 11,300 101% 366,077,985 40% 3.66% 379,985,452 42.4% 102,207 32,398

2007 14,335 27% 482,159,796 32% 4.30% 503,824,238 46.9% 122,675 33,635

2008 16,794 17% 555,705,060 15% 5.84% 590,171,049 44.9% 150,084 33,090

2009 17,752 5.7% 541,119,328 -2.6% 5.07% 570,019,307 45.0% 144,624 30,482 2010 18,779 5.8% 518,243,890 -4.2% 3.25% 535,652,600 44.1% 138,650 27,597

FOR

EC

AS

T

2011 21,160 12.7% 622,359,352 20.1% 4.81% 653,833,250 43.2% 172,619 29,413

2012 21,373 1.0% 626,208,601 0.6% 4.81% 657,877,163 44.5% 168,929 29,299

2013 21,637 1.2% 641,883,541 2.5% 4.81% 674,344,815 44.5% 173,157 29,666

2014 21,903 1.2% 661,721,625 3.1% 4.81% 695,186,148 44.5% 178,509 30,211

2015 22,221 1.5% 667,949,615 0.9% 4.81% 701,729,099 44.5% 180,189 30,059

2016 22,543 1.5% 672,565,428 0.7% 4.81% 706,578,343 44.5% 181,434 29,834

2017 22,920 1.7% 678,026,446 0.8% 4.81% 712,315,535 44.5% 182,908 29,582

2018 23,303 1.7% 683,582,569 0.8% 4.81% 718,152,642 44.5% 184,406 29,334

2019 23,745 1.9% 690,039,237 0.9% 4.81% 724,935,836 44.5% 186,148 29,060

2020 24,195 1.9% 696,624,509 1.0% 4.81% 731,854,137 44.5% 187,925 28,792



Electrical District No. 3 Historical and Projected Energy Requirements (kWh)

100,000,000

200,000,000

300,000,000

400,000,000

500,000,000

600,000,000

700,000,000

800,000,000

900,000,000

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

2023

2024

2025

2026

2027

2028

2029

2030

Energy Req

uiremen

ts (kWh)

Pessimistic Baseline

Optimistic



Electrical District No. 3 Historical and Projected Peak Demands (kW)

‐

50,000

100,000

150,000

200,000

250,000

2002

2003

2004

2005

2006

2007

2008

2009

2010

2011

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

2023

2024

2025

2026

2027

2028

2029

2030

Peak Demand (kW

)

Pessimistic

Baseline

Optimistic

Mild Weather (Baseline)

Extreme Weather (Baseline)

APPENDIX C.2 -- Resource Graph

SCHEDULED RESOURCES TO COVER TYPICAL PEAK DEMAND

ELECTRICAL DISTRICT NUMBER THREE

-

20,000

40,000

60,000

80,000

100,000

120,000

140,000

160,000

180,000

200,000

Oct-10 Nov-10 Dec-10 Jan-11 Feb-11 Mar-11 Apr-11 May-11 Jun-11 Jul-11 Aug-11 Sep-11

Cap

acity

(kW

) Arizona Public Service Power Block (APS)Arizona Public Service (APS)

Colorado River Storage Project (CRSP)

Parker Davis Project (PDP)

Arizona Power Authority (Hoover)

Peak Demand

Oct-10 Nov-10 Dec-10 Jan-11 Feb-11 Mar-11 Apr-11 May-11 Jun-11 Jul-11 Aug-11 Sep-11Arizona Power Authority (Hoover) 16,000 10,000 16,000 15,000 20,000 15,000 12,000 15,000 20,000 24,000 25,000 25,000 Parker Davis Project (PDP) 4,203 4,203 4,203 4,203 4,203 5,164 5,164 5,164 5,164 5,164 5,164 5,164 Colorado River Storage Project (CRSP) 1,000 3,000 1,000 1,000 1,000 2,000 4,000 4,000 8,000 7,000 6,000 4,000 Arizona Public Service Power Block (APS) 57,000 42,000 39,000 34,000 42,000 44,000 57,000 81,000 104,000 104,000 104,000 81,000 Arizona Public Service (APS) 37,532 7,068 - 10,800 1,249 16,384 14,143 13,408 28,540 31,604 32,441 47,846 Peak Demand 115,735 66,271 58,661 65,003 68,452 82,548 92,307 118,572 165,704 171,768 172,605 163,010

Resources

1 of 1 K. R. Saline & Associates, PLC 1/18/2012

APPENDIX C.3 -- Load Profile Information

Customer Type # of CustomersResidential 19,590 Small Commercial 1,161 Large Commercial 184 Industrial 3 Irrigation Pumping 265 Ag-Related Pumping 42 Non-Ag Pumping 73 Gins 3 Dusk to Dawn Lighting - Gates & Turnouts 1 Unmetered 5 Landscaping 108 Street Lighting 990 Total 22,425

Customer Profile

ELECTRICAL DISTRICT NUMBER THREE

0.82%

0.01%

1.18%

0.19%

0.33%

0.01%

0.00%

0.00%

0.02%

0.48%

4.41%

Residential

Small Commercial

Large Commercial

87.36%

5.18% Large Commercial

Industrial

Irrigation Pumping

Ag-Related Pumping

Non-Ag Pumping

Gins

Dusk to Dawn Lighting

Gates & Turnouts

Unmetered

Landscaping

Street Lighting

1 of 2 K. R. Saline & Associates, PLC 1/18/2012

Appendix C.3 – Load Profile Information


Electrical District No. 3 Historical and Projected Annual Energy Sales By Class (Baseline Forecast)

POSSIBLE JOINT APPEARANCE OF DIRECTORS COURTESY NOTICE

This notice is provided as a courtesy to the public that two or more Directors of MSIDD may be in attendance of the above-referenced meeting.

The Directors attending this meeting will NOT vote on any issue or discuss pending legal actions specifically

pertaining to the business of MSIDD.

ELECTRICAL DISTRICT NO. 3 BOARD OF DIRECTORS

NOTICE OF

REGULAR / CANVASS

MEETING

WEDNESDAY – JANUARY 25, 2012 10:00 A.M.

Pursuant to A.R.S. §38-431.02, notice is hereby given that ED3 has scheduled a

Regular / Canvass Meeting on Wednesday, January 25, 2012 at 10:00 a.m. at the District Administration Office at 41630 W. Louis Johnson Drive, Maricopa.

The purpose of the Canvass Meeting is for the Board to

Canvass the Election held January 14, 2012.

The District will also review and approve its updated Integrated Resource Plan. This Integrated Resource Plan (IRP), which is required by the Western Area Power Administration,

details the District's power resource plan for the next five years. The final IRP will be available to the public at the District's office prior to the meeting. Written comments regarding the IRP will be

accepted any time prior to or at the meeting. Public comments will also be accepted at this time. Please contact the District Administration office for more information.

Pursuant to ARS § 38.431.03 A (3) and (4) the Board of Directors may resolve into an Executive Session, which will not be open to the public, for the purpose of discussion

to obtain legal advice from attorney(s) and to discuss its position and instruct its representatives regarding contract negotiations.

The Agenda for this meeting will be available at the District

Administration Office twenty-four (24) hours prior to the meeting.

Posting Date: 01/20/12 Nancy Messer, Executive Assistant Direct: 520-424-0401 [email protected] www.ed3online.org

41630 W. LOUIS JOHNSON DRIVE MARICOPA, AZ 85138-5402

Administration Office Main (520) 424-9311

APPENDIX D -- Public Meeting Notice

integrated resource plan - wapa · ed3 integrated resource plan adopted 1/25/12 profile data...

Documents