Utah Department of Administrative Services Division of Administrative Rules

Utah Administrative Code

The Utah Administrative Code is the body of all effective administrative rules as compiled and organized by the Division of Administrative Rules (Subsection 63G-3-102(5); see also Sections 63G-3-701 and 702).

NOTE: For a list of rules that have been made effective since October 1, 2014, please see the codification segue page.

NOTE TO RULEFILING AGENCIES: Use the RTF version for submitting rule changes.


R746. Public Service Commission, Administration.

Rule R746-700. Complete Filings for General Rate Case and Major Plant Addition Applications.

As in effect on October 1, 2014

Table of Contents

R746-700-1. General Provisions Applicable to All 7XX Series Rules.

This rule provides provisions for complete filings for general rate case and alternative cost recovery for major plant addition applications and other 7XX series rules, meaning R746-700-1 through and including R746-700-51.

A. Purpose. The 7XX series rules apply to an application for a general rate case filed by a public utility for an increase or decrease in base rates pursuant to 54-7-12 and an application for alternative cost recovery for a major plant addition filed by an electrical corporation or gas corporation public utility for cost recovery of a major plant addition pursuant to 54-7-13.4.

B. A public utility anticipating to file a general rate case or major plant addition application shall file with the Commission a non-binding notification of its intent to file such application at least 30 days prior to the anticipated filing date of the application. The notification shall be served on all parties that participated in the public utility's last prior general rate case or major plant addition proceeding respectively. The Commission may grant an exception or modification to this notification requirement based on a showing of good cause by the public utility.

C. Minimum filing requirements for a complete filing. Sections 700-10, 700-20, 700-21, 700-22, 700- 23, 700-30, 700-40, 700-41, 700-50, and 700-51 set forth the information which must be contained in an application, testimony, exhibits, evidence, data, and any other informational documents filed with an application for the application to be considered a complete filing pursuant to 54-7-12(2) or 54-7-13.4(2).

D. Paper and Electronic media documents.

1. All documents filed with the Commission are to be in paper and electronic media versions as directed by R746-100. When a particular exhibit, data or informational document or its accompanying documentation required by a rule is voluminous, a proceeding participant shall file only three complete paper versions and the electronic media version with the Commission. The proceeding participant shall file any additional paper versions as subsequently directed by the Commission.

2. A proceeding participant is encouraged to provide voluminous material to other participants in a proceeding in an electronic media version. Unless a participant in a Commission proceeding notifies the Commission and other proceeding participants that it is unable or unwilling to receive documents in electronic media, provision of documents to a participant need only be in electronic media.

3. An applicant shall provide electronic media versions of its application and additional information and documents to be provided pursuant to any series 7XX rule to the Division of Public Utilities and the Office of Consumer Services, other parties granted intervention in the utility's last prior application proceeding, and any other person that has petitioned for intervention in the proceeding. An applicant need not provided these documents to a person whose intervention it opposes unless and until the person is granted intervention by the Commission. Notwithstanding the foregoing, the applicant shall provide a reasonable number of paper copies of the documents to the Division of Public Utilities and the Office of Consumer Services upon request.

E. Format, detail, etc. of documents, information, data, etc., indication of non-existence of information or unavailability of information of the type, detail or format described in a rule provision in the public utility's normal course of business and accounting, and confidential and privileged documents or information.

1. The format, detail, etc. of documents, data, information, etc. provided pursuant to any 7XX series rule shall be in the same format, detail, etc. as provided in the public utility's last prior proceeding or as otherwise directed by the Commission in or subsequent to the last prior proceeding. If a document, spreadsheet, schedule, etc. has internal formulas or other types of inter-cell relationships, the electronic media version shall be provided with such formulas or cell relationships intact.

2. If any series 7XX rule requires particular documents, data, information, etc. to be produced and the documents, data, information, etc. do not exist, the proceeding participant shall specifically so indicate. If any 7XX series rule requires information to be produced of a certain type or in a certain detail, format, etc. which is not so maintained in the normal course of business and accounting, the participant will so indicate and identify and provide what information does exist as maintained by the participant.

3. Information claimed to be confidential that would fall within any 7XX series rule that is filed or provided by a proceeding participant in connection with an application shall be filed or provided under the terms of R746-100-16 or any applicable protective order. If a proceeding participant believes a document, data, information, etc. would fall within any 7XX series rule but claims a privilege affects its production, in lieu of providing the document, data, information, etc., the participant shall provide a description of the document, data, information, etc. and explain the privilege's application to the document, data, information, etc.

R746-700-10. Test Period Information to Be Included With a General Rate Case Application.

A. Cases where the test period is first identified in the application.

1. The applicant will provide information which will demonstrate what adjustments are required to be made to the 12 months of actual, unadjusted results of operations data, including all regulated costs and revenues, contained in the most recent periodic reported results of operations submitted to the Commission, to arrive at the test period used by the applicant in its application, on both a Utah jurisdiction and total company basis. If the public utility does not submit periodic reported results of operations to the Commission, the applicant shall use the public utility's most recently audited 12-month period in lieu thereof as the base period upon which the test period used in the application is developed.

a. Adjustments to be demonstrated include, but are not limited to: normalization adjustments, annualization adjustments, accounting adjustments, adjustments to reflect prior Utah regulatory decisions and policies made by the Commission with respect to any item or matter (including those which are not supported or advocated by the applicant for use in the general rate case) contained in the application, and all further adjustments to arrive at the test period used by the applicant in the general rate case filing.

b. The applicant will provide information explaining why the test period used is the most appropriate for the case.

c. In addition to the information relating to each adjustment identified in compliance with R746-700- 10.A1.a, the applicant will also provide a summary index which identifies each adjustment or portion of an adjustment made in the filing material which can be used to locate where each adjustment or portion thereof is addressed, treated, applied, etc. in the application, testimony, exhibits and other documentation submitted. The summary index may be presented in testimony, as a table embedded in testimony, as an exhibit to testimony, or in any other manner so long as it is clearly identified.

2. If the test period used in the application is a future test period, in addition to the demonstration of adjustments to be made for the test period used by the applicant in the general rate case application, the applicant will make the same demonstration for the 12-month period ending on the last day of June or December, whichever is closest, following the filing date of the application if this alternative period does not have an end date beyond the test period used in the general rate case application.

B. Cases where the test period is identified and approved prior to the filing of an application.

1. An applicant planning to file an application may first request Commission approval of a test period to be used prior to filing an application. The request to approve the proposed test period shall be accompanied by testimony and exhibits providing information supporting the proposed test period.

2. Subsequent to the Commission's approval of a test period, the applicant may then submit an application, using as the test period for the case the test period previously approved by the Commission and need not provide the alternative test period demonstration required by R746-700-10.A.2.

R746-700-20. Information For a General Rate Case Application for an Electrical Corporation or a Gas Corporation.

An applicant submitting a general rate case application shall provide the following information with the application, on a total company and Utah jurisdictional basis using the allocation methods used in the public utility's last general rate case proceeding or any allocation method subsequently approved by the Commission. An applicant will provide an index which identifies where in the application, testimony, exhibits, documents, information, data, etc. filed with the application the applicant has responded to and complied with these R746-700-20 rule requirements. The index may be presented in testimony, as a table embedded in testimony, as an exhibit to testimony, or in any other manner so long as it is clearly identified.

A. Historical results of operations information:

1. actual, unadjusted results of operations, including all regulated costs and revenues, for an historical 12-month period as contained in its last periodic reported results of operations filing submitted to the Commission.

2. adjusted results of operations for the same period.

3. a description of any significant changes in accounting policies for the 24-month period prior to the historical period and any subsequent accounting changes through the date of the general rate case application and, if a forecasted test period is used, any future significant changes included in a future test period, along with their impact on the filing. Significant changes for this purpose are anything referenced or that would be referenced in footnotes of financial statements or auditor's reports.

B. If a non-forecasted test period is used in the application, the applicant shall provide information identifying and supporting each and every modification to the historical results of operations to arrive at the non-forecasted test period used in the general rate case application.

C. If a fully or partially forecasted test period is used in the application, which forecasted test period was not previously approved by the Commission for the general rate case application, the following forecasted test period information shall be provided (the format of the forecasted test period data shall be comparable to the historical results of operation information):

1. Revenues, with details supporting the test period revenues including (as applicable):

a. Usage, per customer by customer class

b. Demand and energy usage

c. Assumptions used in the development of the revenue forecasts

d. Billing determinants, by customer class, used to calculate the forecast test period revenues.

e. Charges, fees, and rates used in the forecast development

f. Contract changes or other specific changes anticipated in the forecast.

2. Operating Costs, using the same cost categories as used in the base period used for compliance with R746-700-10.A, with details supporting the test period operating cost information, including:

a. Forecasted costs relying on escalators or drivers will include the details of the base costs and the key drivers that impact the forecasted amount. If forecasted costs are not based on historical levels that have been inflated or escalated, the applicant shall provide supporting documents in the most detailed level available.

b. The information will identify the index or rate of inflation applied to accounts, budget items or specific cost components that result in adjusted costs in the forecasted test period. Source documents supporting the index or rate of inflation applied will be identified and will be provided or made available.

3. Labor Costs shall be identified separately. The applicant will provide:

a. The actual most recent number of full-time equivalent employees and, separately, the forecasted number of full-time equivalent employees for the forecasted period. The most recent number of actual contract labor employees and the forecasted number of contract labor employees for the test period will also be provided as available and separately identified. The most recent number of actual union labor employees and the forecasted number of union labor employees for the test period will also be provided as available and separately identified.

b. The associated costs related to the full time equivalent labor and contract labor levels. Direct employees, contract employees, union and nonunion employees will each be provided separately.

c. Overtime costs, premiums, incentives, or other labor costs included in the forecast, with each provided separately. Union and nonunion costs shall be provided separately.

d. Any assumed salary and wage increases included in the projected labor costs will be identified. Any of the increases supported by a union contract will be so identified.

e. Pensions and benefits, overheads or other employee benefit costs that are included in the forecast period. Each of the separate employee benefit components will be separately identified (i.e., medical, dental, pensions, etc.) Any assumptions regarding projected increases in such costs caused by factors other than changes in full time employee levels will be identified and described, with supporting assumptions identified.

f. If projected increases in pension expense cause a material cost impact, at a minimum, the following information should be provided for one year prior to the historical period through the test period: service cost, interest cost, expected return on assets, net amortization and deferral, amortization of prior service cost, and total net periodic pension cost. The information shall also include for each of the 12-month periods the expected long-term rate of return on assets, discount rate, salary increase rate, amortization of transition asset or obligation, percent of pension cost capitalized, minimum required contribution per IRS, maximum allowable contribution per IRS, and actual (or projected) contribution made to the trust fund. Also included shall be the projected year-end balance at the end of each of the 12- month periods for accumulated benefit obligation, projected benefit obligation, fair value of plan assets, and market related value of assets.

4. Capital Expenditures or additions. The applicant will provide capital expenditures detail, and changes affecting rate base, including:

a. The detail for the changes, beginning with the start of the historic period results of operation through the test period. The detail will include dollar amounts and in-service dates.

b. The detailed calculation of depreciation expense and accumulated depreciation impacts as a result of the capital expenditures affecting rate base. For depreciation expense, the information will include the balances by plant account or function, depending on how the projection is done, to which the depreciation rates are being applied and the respective depreciation rates being used, by account or function, depending on how the projection is done.

c. Interdependencies of capital expenditures to operation and maintenance items will be identified.

d. A list will be provided of all major capital additions to rate base individually exceeding $1,000,000 or 0.01% of total company net plant in service, whichever is greater for each year, beginning with the year prior to the historic periodic reported year through the test period. Projects under $1,000,000 shall be grouped in aggregate utilizing the utility's usual plant categorizations. A brief description will be provided for each major capital addition in the list.

i. exceeding 0.1% of total company net plant in service or $5,000,000, whichever is greater, for an electrical corporation, or

ii. exceeding 0.1% of total company net plant in service or $1,000,000, whichever is greater, for a gas corporation.

e. Detailed calculation of plant retirements.

5. Regulatory Adjustments. The applicant will provide details of all the regulatory adjustments required in the filing:

a. Information for recurring regulatory adjustments, such as amortizations, indicating compliance with past Commission orders for any item included in the filing.

b. Separately, a reversing adjustment and the reasons for non-inclusion or departure from a Commission ordered practice or adjustments if the applicant does not wish to have them apply to the application.

c. Unless already included in unadjusted results, regulatory adjustment information will include disallowances from prior orders, implementation of accounting orders approved by the Commission, or other adjustments necessary to make the forecasted test period data acceptable for ratemaking in Utah. Each of the regulatory adjustments will be supported by prefiled testimony or a detailed description contained within the schedules.

6. Other Rate Base. Details of other rate base accounts shall be provided by the applicant. For other items of rate base, such as deferred debits, accumulated deferred income taxes, materials and supplies, miscellaneous rate base, customer advances, deferred credits, etc., the applicant shall provide information showing the 12-month period of the historical results of operations, and any changes, both debits and credits, to those amounts through the test period resulting in the projected amount included in the filing. The information shall provide descriptions of any adjustments and modifications made to the historical period amounts and assumptions included in the projections. For any accounts in which no change from the historical level is proposed, a description of why the amount is not forecasted to change shall be included.

7. Taxes. Forecasting methods, calculations and key assumptions used to adjust historical tax information to projected costs and results will be provided on a tax item basis (i.e., income, FICA, property taxes, etc).

R746-700-21. Cost of Service and Rate Design Information for a General Rate Case Application for an Electrical Corporation or a Gas Corporation.

An applicant shall file the following Cost of Service and Rate Design information with any general rate case application. An applicant will provide an index which identifies where in the application, testimony, exhibits, documents, information, data, etc. filed with the application the applicant has responded to and complied with these R746- 700-21 rule requirements. The index may be presented in testimony, as a table embedded in testimony, as an exhibit to testimony, or in any other manner so long as it is clearly identified.

A. A Utah Class Cost of Service Study.

1. A Utah Class Cost of Service Study based on the test period with supporting documentation including the development of allocation factors.

2. If a new customer class is proposed, the applicant shall either:

a. include class cost of service studies; one which uses only existing customer classes and another with the newly proposed class included, or

b. explain why no cost of service study including the new customer class is included and how the new customer class is to be treated in setting rates in the case.

B. Its proposal for spreading any Utah revenue requirement change among the rate schedules. This will include the dollar and percentage revenue requirement change for each rate schedule.

C. Its proposed rates for each rate component of each rate schedule and the billing determinants for the test period for all rate components used to calculate revenues necessary to recover the proposed revenue requirement. An exhibit will be provided showing the test period blocking based on adjusted actual and forecasted billing units in the development of the revenues for each rate schedule.

D. Its proposed tariff sheets for all tariff provisions for which it proposes changes.

1. An applicant need not include proposed tariff sheets for changes to tariff pages showing rates, charges, or fees if these proposed price changes are provided in a readily identifiable form elsewhere in the application.

R746-700-22. Additional Information for a General Rate Case Application Using a Forecasted Test Period Filed by an Electrical Corporation or a Gas Corporation.

If not already included with the application, pursuant to R746-700-20 or R746-700-21, an applicant shall also file with the Commission the following information or documents when filing a general rate case application which uses a forecasted test period. An applicant will provide an index which identifies where in the application, testimony, exhibits, documents, information, data, etc. filed with the application the applicant has responded to and complied with these R746-700-22 rule requirements. The index may be presented in testimony, as a table embedded in testimony, as an exhibit to testimony, or in any other manner so long as it is clearly identified. Contemporaneously with the filing of an application, an electrical corporation or gas corporations shall provide the following information and documents to the parties specified in R746-700-1.E.3, unless the information or document is already included in or with the application.

A. Definitions. As used herein, the following terms shall have the indicated meanings:

1. Time Periods. Definitions of time periods for which information is to be provided in compliance with this rule are as follows:

a. Year: A 12-month period designated as "12 months ending Month Date, Year".

b. Base Year (BY): The 12-month historical period ending on the ending date for the most recent periodic reported results of operations filing submitted for the public utility, or if it does not file periodic results of operations, the base period upon which the test period used in the application is developed.

c. Test Period (TP): The 12-month period used as the test period for the general rate case application.

d. Historical Year(s) (HY): Year(s) immediately preceding the Base Year.

e. To Date: Up to the most recent date for which information is reasonably available to the public utility in preparing its general rate case application.

f. Workpapers: The documents and source material used to develop the inputs to the general rate case filing. The type, nature, level of detail, format, etc. of the information compilation, schedule, document, etc. shall be reasonably comparable to that provided to parties in the public utility's prior general rate cases.

2. Provide, Describe, etc. The terms "provide" or "describe," or terms with similar meaning, shall mean to deliver available electronic copies and/or paper copies of designated data and documents to interested persons; provided that, when necessary and appropriate, prompt arrangements may be made for review of designated data and documents at a utility location in Utah or at another mutually agreeable place. Spreadsheets and workpapers are to be provided in "live" electronic format (not PDF), i.e. models and spreadsheets are to be provided with formulas intact and input data available.

3. Materiality. Materiality is defined as a change in requested Utah jurisdictional revenue requirement equal to or greater than 0.1 % of total state revenue requirement or $500,000, whichever is less.

4. Model(s). The term Model(s) shall mean the major analytical software tools and spreadsheets used by the utility to develop its general rate case application. Smaller analytical tools, such as special purpose electronic spreadsheets, are not included in the definition of the term Model(s) for purposes of this rule.

B. Revenue Requirement Information.

1. Forecasted test period data. A comparison of the Test Period data Results of Operations (RO) to the Base Year actual, unadjusted RO and adjusted RO on both a jurisdictional and total company basis. This is to be made available in a side-by-side comparison on a consistent basis by FERC Account.

2. Operating and Capital Budgets. A comparison of the utility's operating budget and capital budget to the actual results for the Base Year, the prior Historical Year, and To Date on a total company basis. This comparison is to be at the most detailed level available and provide available explanation for material variances.

3. Labor Costs. A comparison of budgeted labor costs and number of full-time equivalents to the actual labor costs and full-time equivalents by year for the Base Year and the prior Historical Year on a total company basis. These shall show separately, to the degree available, the direct labor costs, premiums, incentives, benefits and overhead costs. These shall show contract labor costs separately from direct labor costs, and union labor costs separate from nonunion costs. The information shall provide available explanations for material variances.

4. Workpapers. The information shall provide the forecast workpapers (including assumptions, spreadsheets and tests).

5. Forecasted Data - Revenue Requirement.

a. Support and explanations for forecasted values, including Base Year starting values, adjustments made to the Base Year values and key drivers that impact the forecasts, together with supporting documents.

b. Indices, inflation rates and escalation factors used in preparing forecasts, including supporting source documents.

c. A revenue requirement workbook that tracks all input data beginning with the Base Year through the Test Period. This will provide summarized revenue requirement sections of the jurisdictional allocation model for the Base Year, the Test Period and any intervening year. The workbook and summaries are to include, inter alia, billing determinants, rate base and capital structure, including dollar capitalization, for the specified Years.

d. Complete net power cost calculations for any intervening year between the Base Year and Test Period.

6. Models. Workable versions of Models utilized in determining or projecting rate case values, with formulae intact and source data included, along with available instructions and write-ups regarding use of the Model and written descriptions of the Model and its inputs.

C. Cost of Service Information

1. Forecasted Data - Class Cost of Service. Class cost of service data on a Utah allocated basis under all approved jurisdictional allocation methods for the Base Year and Test Period.

2. Forecasted Data - Rate Design. Test Period rate design data on a Utah allocated basis under all approved jurisdictional allocation methods used for reporting purposes.

D. Miscellaneous Information

1. Accounting - Changes. A detailed description of Material changes in accounting policies or procedures adopted by the utility since the prior general rate case or as anticipated through the end of the Test Period. This will include a detailed description of the impact of change in accounting policy or procedure on the Test Period and identify the basis of the change.

2. Accounting - Write-offs. A detailed description of Material write-offs of assets and/or liabilities from the start of the Base Year - To Date that affect Utah revenue requirement. For each material write-off, the following will be provided:

a. Copy of journal entry recording the write-off;

b. Detailed description of the purpose of the write-off;

c. Copies of studies, reports or analyses done in determining whether or not to write off the asset;

d. Amount of the write-off and identification of the accounts charged on a total Company and a Utah jurisdictional basis; and

e. Amount included in the projected Test Period for write-offs, if any, on a total Company and a Utah jurisdictional basis, by account.

3. Affiliates - Organizational Charts. For the Base Year and Test Period and continuing To Date, the affiliates organization chart for the utility including a clear indication of affiliates, parent companies, divisions and subsidiaries indicating their regulatory status.

4. Affiliates. A detailed description of corporate restructurings and changes in affiliate relationships since the filing of the prior general rate case and also describe changes in the corporate and affiliate relationships between the Base Year and the end of the Test Period reflected in the filing.

5. Affiliates. A copy of Material new or Materially modified contracts or agreements entered into since the filing of the prior general rate case, including attachments thereto, if relevant to the costs the utility seeks to recover from Utah ratepayers through Utah regulatory operations or costs allocated or directly charged to Utah regulated operations included in the general rate case application, between the utility and/or its parent company and affiliated companies for services and/or goods rendered between or among them. This is to include a list of active contracts unless already provided in the most recent Affiliate Interest Report.

6. Affiliates. A copy of cost allocation manuals and/or policies and procedures that set forth the detailed cost allocation methodology and/or pricing methodology used to charge costs between affiliates that have changed since the filing of the prior general rate case.

7. Audit - Financial. A copy of each adjusting journal entry made in response to the utility's independent auditors' final recommendations in their most recent audit of the utility. Supporting documentation will be included. The information will also identify and provide adjusting journal entries included in the independent auditors' final recommendations that were not accepted by or made by the utility, along with a description of why the adjustment was not accepted or made.

8. Audit - Financial. A copy of management letters received from the utility's independent auditors or responses to those management letters for the Base Year, the prior Historical Year and the period To Date.

9. Audit - Financial Audit Workpapers. If access to audit workpapers is allowed by the utility's independent auditor, the utility will coordinate review of the financial audit workpapers for the most recent completed financial audit conducted by the utility's independent auditors at a mutually agreed upon location. If access to workpapers is not allowed by the independent auditor, the utility will coordinate the review of the most recent quarterly review conducted by the utility's independent external auditors prepared for the utility's board of directors.

10. Audits - Internal. A listing of internal audits conducted by or for the utility or its parent company for the Base Year, the prior Historical Year and To Date if relevant to the costs the utility seeks to recover from Utah ratepayers through Utah regulatory operations or the costs allocated or directly charged to Utah regulated operations included in the general rate case application. Notice of Internal Audit reports completed during the pendency of the case will be provided upon completion to all parties participating in the case.

11. Board of Directors - Meeting Minutes. The Board of Directors' meeting minutes for the Base Year, the prior Historical Year and To Date for the utility and the parent company if relevant to the costs the utility seeks to recover from Utah ratepayers through Utah regulatory operations or the costs allocated or directly charged to Utah regulated operations included in general rate case filings for the same period.

12. Budget. Complete copies of detailed annual operating and capital budgets for the Base Year through the end of the Test Period.

13. Budget. Copies of operating and capital budget instructions and directives provided to employees, including assumptions, directives, manuals, policies and procedures, timelines, and descriptions of budget procedures for the budget or forecast for the Test Period and To Date.

14. Budgets - Operating Plans. If available, copies of written operating plans that describe the utility's goals and objectives for the Base Year through the end of the Test Period.

15. Budget - Variance. A complete copy of quantitative and narrative monthly, quarterly and annual comparisons of operating and capital budgets to actual expenditures for the Base Year, the prior Historical Year, and for the period from the Base Year To Date.

16. Cost of Capital - Debt Expense. The currently forecasted financings for the next three years.

17. Cost of Capital - Debt Expense. The monthly balance of short-term debt and monthly short-term debt cost rates, for the Base Year, the prior two Historical Years and To Date.

18. Cost of Capital. Copies of the most recent bond rating agencies reports on the Company.

19. Employee Costs. A breakdown of the total amount of gross payroll and employee benefit costs (by benefit type) for the Base Year, the prior Historical Year and through the end of the Test Period between amounts expensed and amounts capitalized and provide the percentage of payroll and employee benefits (by benefit type) charged to expense for each Year.

20. For the Base Year, the prior Historical Year, To Date and for the Test Period, the amount of overtime, the amount of premium pay, the amount of other salary/labor costs and the amount of incentive compensation in total and expensed for each.

21. Employee Costs. A list of compensation and benefit studies the utility has for the Base Year, the prior Historical Year and To Date and indicate which of the studies were used (if any) in projecting the compensation and employee benefit costs for the Test Period.

22. Employee Costs - Employee Levels. Describe, in detail, Material employee reductions, employee severance plans, or early retirement programs conducted or anticipated by the utility during the Base Year, the prior Historical Year, and To Date and as projected through the end of the Test Period that are and are not reflected in the application. If anticipated, but not reflected in the application, explain why they are not included. This should provide information on major plans or programs beyond cost management efforts undertaken in the normal course of business. This should include, but not be limited to, a detailed description of the plan, number of employees offered or projected to be offered early retirement or severance, number of employees accepting or projected to accept early retirement or severance, projected cost savings and costs associated with the program. For costs incurred, identify the amounts, by FERC account, and the dates the entries were booked.

23. Employee Costs - Employee Level. Separate lists of the budgeted and the actual number of employees (where available), by month, for the Base Year, the prior Historical Year, the Test Period and To Date. If the labor force levels are other than full-time equivalent positions, provide a separate listing stated in terms of full-time equivalent positions.

24. Employee Costs - Wages and Salaries Levels. The actual percentage of increases in salaries and wages for exempt, non-exempt and union employees for the Base Year, the prior Historical Year, Test Period and To Date.

25. Employee Costs - Incentive Plans. Complete copies of bonus programs or incentive award programs in effect for the utility for the Base Year, the prior Historical Year, the Test Period and To Date. Identify incentive and bonus program expenses incurred in the Base Year, the prior Historical Year, the Test Period and To Date and identify the amounts included in the Test Period. Identify the accounts charged. Identify incentive and bonus program expenses charged or allocated to the utility from affiliates or the parent company in the Base Year, the prior Historical Year, the Test Period and To Date.

26. Employee Costs - Benefits. A listing of health and other benefits received by employees during the Base Year. Provide a detailed description of changes to employee benefits occurring subsequent to the Base Year To Date and anticipated future changes through the end of the Test Period that are reflected in the filing.

27. Employee Costs - Pensions. The two most recent pension actuarial reports prepared for the utilty.

28. Employee Costs - Post Retirement Benefits Other Than Pensions (PBOP). The two most recent PBOP actuarial reports prepared for the utility.

29. Employee Costs - Pensions and Post Retirement Benefits Other Than Pensions (PBOP). The list of assumptions used by the utility and its actuaries regarding the pension and PBOP costs for the Test Period that are included in the filing.

30. Operation, Maintenance, Administrative and General (OMAG) Expenses - Other - Contributions. For the Base Year and the Test Period, a list of contributions for charitable and political purposes, if any, included in accounts other than below the line. Indicate the amount of the expenditure, the recipient of the contribution, and the specific account in which the expense is included in the filing. Also identify for the Base Year and the Test Period the amounts of contributions for charitable and political purposes charged to the utility from affiliates in accounts other than below the line accounts.

31. OMAG Expenses - Advertising. For the Base Year, the prior Historical Year and the Test Period the amount of advertising expense, by account, by type of advertising (i.e., informational, instructional, promotional).

32. OMAG Expenses - Dues, Industry Associations. The Material amounts included in the Base Year, the prior Historical Year and the Test Period for above-the-line payments to industry associations. Identify the organization/association name and amounts, along with the account in which the costs are included in the filing. If any of the dues or other amounts paid to the organizations/associations go toward lobbying and public relations efforts and are recorded in above-the-line accounts, provide the associated amounts included in the above-the-line accounts whether Material in magnitude or not.

33. OMAG Expenses - Outside Services Expense. An itemization of Material outside services expenses included in FERC account 923 for the Base Year, the prior Historical Year and the Test Period.

34. OMAG Expense - Injuries and Damages. The amount of injuries and damages expense for the Base Year, the prior Historical Year, the Test Period and To Date.

35. OMAG Expense - Insurance. The amount of insurance expense, by insurance type (i.e., property insurance, liability insurance, workers compensation, directors and officers liability insurance, etc.) for the Base Year, the prior Historical Year and the Test Period and identify the accounts the associated costs are included in.

36. OMAG Expense - Insurance. For insurance coverage for which the utility is self-insured, a description of that self insurance, a description of how it is accounted for in the utility's books and records and a description of activity for the Base Year, the prior Historical Year and the Test Period.

37. OMAG Expense - Legal Settlements. A list of Material amounts included in the Base Year and the Test Period (on a direct charge basis, affiliate billing, or allocation) that are the result of the settlement of lawsuits or other legal action.

38. OMAG - Uncollectibles - Bad Debt Reserve. For the Base Year, the prior Historical Year and the Test Period the beginning bad debt reserve balance, the amount written off, the recoveries, the reserve adjustment, other charges or credits, and the ending reserve balance. For the same periods, provide the total amount of retail revenue from retail sales and total retail bad debt expense.

39. OMAG - Uncollectibles. A detailed description of changes in the utility's collection policies or write-off policies since the filing of the prior general rate case.

40. OMAG - Cost-saving Programs. A list and detailed description of cost-saving or cost increasing programs and initiatives implemented during the Base Year, To Date, and included in the Test Period. This should provide information on major plans or programs beyond efforts undertaken in the normal course of business and having a Material impact.

41. Financial - Strategic Plans. Copies of completed strategic plans and the most recent plan approved by the Board of Directors for the utility and the plan that was utilized at the time of and in the preparation of its application, if different.

42. Penalties and Fines. A list of penalties and fines in the Base Year and the Test Period and indicate in which accounts the associated amounts are included.

43. Rate Base - Working Capital. A complete copy of the lead/lag study, with supporting workpapers, used to compute cash working capital for the utility's application.

44. Reserve Accounts. Information on whether or not the utility maintains reserve accounts (e.g., an injuries and damages reserve account). If so, provide the monthly balances in reserve accounts for the Base Year, the prior Historical Year, the Test Period and To Date. This listing should include the monthly debits and credits to the reserve accounts. Also, provide the amount included in the Base Year and the projected Test Period expenses, by account, for building-up the reserve balances.

45. Revenues: Regulated Retail Sales. Provide by customer class, by month, the number of customers, actual usage, and normalized usage for the Base Year, the prior Historical Year, the Test Period and To Date.

46. Revenues - Other. Provide on a total company and a Utah jurisdictional basis, for the Base Year, the prior Historical Year, the Test Period and To Date the amount of other nonregulated-retail-sales revenues by revenue type.

47. Sales of Property. For the Base Year, the prior Historical Year, the Test Period and To Date, information showing whether the utility sold property, in which the proceeds for a property, which alone, or for multiple properties, which in the aggregate, would be Material. If so, for each such sale identify the property sold; whether, when, and in what manner it was included in rate base; show details of how the gain or loss was calculated; indicate when the sale occurred; and explain how and whether the utility is treating such gain or loss in its application. For sales in which the proceeds would be Material, individually or in the aggregate, provide a list of any properties currently offered for sale and those projected to be offered for sale through the end of the Test Period. The property sales information may be limited to sales of property that had been or are included in Utah rates while in service.

48. Taxes: Income. A list of and provide copies or make available for review, subject to R746-100- 16, an appropriate protective order, confidentiality agreement, or other confidentiality protective arrangement, depending on specific content, revenue ruling requests, IRS responses, and correspondence between the utility and the IRS since the filing of the prior rate case.

49. Taxes: Income. Provide copies or make available for review, subject to R746-100-16, an appropriate protective order, confidentiality agreement, or other confidentiality protective arrangement, copies of the most recent State and Federal income tax returns in which the utility participated.

50. Taxes: Income. Provide a copy of the current tax sharing agreement in which the utility participates.

R746-700-23. Additional Power Costs Information for a Forecasted Test Period to Be Filed by an Electrical Corporation.

A. An electrical corporation that has included power costs in a forecasted test period shall also file with the Commission the following information or documents relating to its power cost projections with a general rate case application. An applicant will provide an index which identifies where in the application, testimony, exhibits, documents, information, data, etc. filed with the application the applicant has responded to and complied with these R746- 700-23 rule requirements. The index may be presented in testimony, as a table embedded in testimony, as an exhibit to testimony, or in any other manner so long as it is clearly identified. Contemporaneously with the filing of an application, an electrical corporation shall provide the following information and documents to the parties specified in R746-700-1.E.3, unless the information or document is already included in or with the application.

B. All information should be provided or available electronically and, in the case of Excel spreadsheets, with all formulas intact including all hierarchy of linked spreadsheets. The term "PCM" herein refers to any power cost model used by the utility, or any subsequent enhancements to or replacements of the power cost model used in the utility's last prior general rate case. The term "workpapers" means the documents used to develop the inputs to the PCM. This may include such items such as contracts, emails, white papers, studies, utility computer programs, Excel spreadsheets, word process documents, pdf and text files, computer programs, or any other data or documents relied upon to support the cost details in the application. If the inputs used in the PCM were developed from a document, such as a contract, provide the contract with the PCM inputs highlighted.

C. Power Cost Modeling Data:

1. Workpapers that show the source, calculations and details supporting the testimony, other exhibits and all PCM input data. The workpapers will include, at a minimum, copies of the net power cost report in Excel and the net power cost model database.

2. Identification of the time periods (Reference Period) used to determine input items (e.g., outage rates) in the PCM which are based upon an examination, average, etc. of a multi-year period.

3. Compilations of actual net power costs produced by the utility that were referenced in the testimony or exhibits, to the extent that actual power cost results are discussed or cited in the utility's testimony or exhibits.

4. A list and explanation of all modeling or logic changes or enhancements to the PCM that have been implemented since the last prior general rate case. This will include a statement of the direction and amount of change in net power costs resulting from each such change and documentation describing each Material change as well as PCM runs and workpapers quantifying the impacts of these changes.

5. Access to or a copy of the PCM model used by the utility to compute power costs in the Test Period.

6. The latest documentation for the PCM.

7. The current topology maps in the PCM along with an explanation for all the differences that have been made to the topology since the last prior general rate case and an explanation of why the changes were made. Include supporting documentation, such as contracts resulting in changes to the transfer capabilities used in the PCM.

8. All documents, workpapers, data or other information used by the utility in determining, setting, or calculating any PCM input, constraint, etc., including, but not limited to, where applicable:

a. market caps,

b. outage rates (planned and unplanned) including all backup data showing each outage (planned or unplanned, etc.) and duration (planned or unplanned) considered in the Reference Period, including NERC cause code, type of event, duration, energy lost, etc.,

c. the date and a copy of any forward price curve used, showing monthly heavy load hour and light load hour,

d. short-term firm transactions (including short-term firm indexed transactions and swaps), each transaction or contract will have a designation as to its purpose (i.e., trading, arbitrage or balancing.),

e. all contracts modeled in the PCM that were not included in or have been amended since the last prior general rate case, providing for each:

(i) A copy of the contract (in pdf or electronic format, if available), and

(ii) input assumptions related to the contract,

f. all fuel cost inputs,

g. heat rate curves for each resource, including the derivation of the heat rate curves,

h. identification of each instance in which the utility changed any maximum capacities, minimum up or down times or unit minimum capacities for thermal or hydro generators modeled in the PCM since the last prior general rate case,

i. each load adjustment,

j. inputs for Qualifying Facility or QF contracts,

k. screens applied to restrict uneconomic dispatch of resources,

l. start up fuel costs, start up O and M costs and any other form of start up costs modeled,

m. loss factor data used to develop the load forecast for the system and for each state for the most recent five calendar years and for the most recent five fiscal years; include a comparison of those loss factors to those that were used in developing loads for the PCM for the test period used in the case,

n. the system level loss factors assumed in any PCM used in the most recent (or current) rate cases for any other jurisdiction in which the utility operates,

o. the actual generation of each coal, gas, hydro and wind generating unit modeled in the PCM for each month for the Reference Period,

p. hourly generator logs for each wind, coal, gas and hydro unit modeled in the PCM for the Reference Period,

q. the schedule for each generation unit's planned and actual outages for the test period, the most recent calendar year and the next four calendar years,

r. hourly logs for all contracts modeled in the PCM, showing actual data (hourly sales or purchases) for the Reference Period,

s. the details of Short Term Firm and Non-Firm transmission used by the utlity during the Reference Period.

t. for each of the transmission contracts whose costs are included in the PCM, identify the purpose of the transaction, why it is used and useful in the test period, the amount of capacity or type of transmission service it provides, and where the capacity or service provided by this contract is modeled in the PCM,

u. data for the Reference Period or for the most recent four years available for all third party transmission imbalance transactions that have been included in Short Term Firm or secondary transactions during that period,

v. any links and other inputs for Short Term Firm (including any related to SP 15) and Non-Firm transmission modeling used in the PCM,

w. the hydro planned and unplanned outage rate,

x. to the extent that the utility uses any ramping adjustment in its case, information describing and detailing all ramping adjustments made (including all ramping energy assumed to be lost for each outage event modeled in the ramping analysis),

y. the costs of wind integration as modeled in the PCM, and

z. hedging contracts, already in place and those assumed for forecasting purposes.

R746-700-30. Information for an Alternative Cost Recovery for a Major Plant Addition Application Filed by an Electrical Corporation or a Gas Corporation.

An applicant submitting an alternative-cost-recovery-for-a-major-plant-addition application shall include the following information as part of the application, on a total company and Utah jurisdictional basis using Commission approved allocation methods where applicable. If the same information was previously provided by the applicant in a prior proceeding in which the plant's construction or acquisition was approved by the Commission pursuant to 54-17-302, the applicant shall provide copies of such previously provided information with the application. If the plant's construction or acquisition was approved subject to conditions pursuant to 54-17-302, the information shall be provided as ordered by the Commission in the order approving the major plant addition subject to conditions. An applicant will provide an index which identifies where in the application, testimony, exhibits, documents, information, data, etc. filed with the application the applicant has responded to and complied with these R746-700-30 rule requirements. The index may be presented in testimony, as a table embedded in testimony, as an exhibit to testimony, or in any other manner so long as it is clearly identified.

A. General Information.

1. All documents and presentations that were provided to management, senior management and the Board of Directors of the utility and its affiliates related to the plant addition.

2. Copies of all Board of Directors' minutes of the utility and its affiliates where the plant was discussed, approved, reviewed, evaluated, or presented.

3. Details of the plant being acquired including its location, capacity, technologies used, project milestones or progress dates, projected in-service date and demonstrating that the plant addition is a major plant addition under 54-7-13.4.

4. Description of any changes, modifications, etc. to the existing utility plant/system that may be necessary to integrate the plant addition with the utility's system.

5. Information establishing the prudence of the plant addition, information addressing the provisions of 54-7-13.4, and the provisions of 54-17-302 and 54-17-303.

6. Information establishing the consistency of the plant addition to projected plant acquisitions in the utility's latest Integrated Resource Plan and its Action Plan. Show that the plant addition resource is as favorable or more favorable than the compared Integrated Resource Plan resource items in terms of least cost and least risk or explain why it need not.

7. Any and all documents and analyses that address the plant addition's projected costs, savings and benefits and demonstrate how and when the utility's ratepayers will see a net benefit from the plant addition and quantify the net benefit.

8. Where applicable, information on whether and how the plant addition has been or will be inspected as part of due diligence, including identification of who conducted or will conduct the inspection and copies of all reports or other documents prepared by the inspectors.

9. A list of all outside consultants or advisors used, or expected to be used by the utility in connection with the plant addition and all reports, including interim reports, prepared by outside consultants or advisors.

10. All internal reports that were prepared when analyzing the purchase or construction of the plant addition.

11. Where applicable, copies of contracts that are expected to be assumed following close of acquisition.

12. Where applicable, copies of all contracts between the utility and the seller or operator of the plant addition.

13. Where applicable, a history of the plant addition to be acquired including financial and performance characteristics for the past five years, or from the start of commercial operation, whichever is less.

14. Where applicable, information on the utility's understanding of the reasons why the seller is selling the facility.

15. Where applicable, information on the seller's book value of the plant.

16. An indication whether the seller will allow interested persons who have signed a confidentiality agreement with the utility access to the seller's books and records for audit, and what restrictions may apply to such access.

B. Financial and Revenue information.

1. Provide information of the revenues, costs and benefits arising from the plant addition, identifying any limits and conditions on forecast information/calculations.

2. Information on the net revenue impact of bringing the plant online and operating the plant within the utility's system compared to operations without the plant.

3. Justification for any acquisition premium the utility plans to include in rates and recover from ratepayers.

C. Capital cost, rate base and jurisdictional allocation information.

1. Information on how the utility plans to finance the construction or acquisition of the plant addition. This is to include the timing and amount of any equity, debt, or other security issuances and any documents to, or received from, any investment bankers or other entities regarding the issuance of any securities connected with the plant addition.

2. Information indicating whether the utility has discussed the plant addition with any rating agencies and provide any reports or rating agencies provided with respect to the plant addition. If not, indicate when it plans to discuss the plant addition with any rating agency.

3. Information on how much of the purchase price or construction costs the utility intends to place into rate base.

4. Information showing the amount and relating to any analysis of AFUDC associated with the plant addition.

5. Information on the utility's anticipated jurisdictional allocation for the plant addition and any change in allocation factors and other plant, revenue and expense/cost allocations arising from the plant addition.

D. Cost and Operating Expenses Information.

1. A complete analysis of all costs associated with constructing, acquiring and operating the plant for which the utility will seek recovery from Utah ratepayers and identify any costs for which no recovery will be sought from Utah ratepayers.

2. Information on all clearances, permits or other government regulatory authorizations necessary, to be modified and completed for the plant and their associated costs.

3. Information on any liquidated damages clause and early termination fees, penalties, or other expenses which may be incurred if the plant is not completed or acquired.

4. Information on whether that are any integration costs or fees (transmission, pipeline, etc.).

5. Information on any costs analysis analyzing bringing the plant online.

6. Information on how the plant addition will change and the amount of change on the utility's Operation and Maintenance costs.

7. All operating cost analyses that have been completed related to the plant addition.

8. The planned accounting treatment for the plant, including the proposed journal entries or other accounting entries for such planned accounting treatment.

9. A description of and the amounts for overhead, closing, contingent or any other costs for which the utility expects it will ask recovery as a result of the acquisition.

E. For an electrical corporation, the following Net Power Costs information.

1. The impacts of the plant addition on any utility power cost and production cost dispatch models. If any models are revised to accommodate the plant addition, the revised models will be available to the parties participating in the application proceeding.

2. A net power cost study (NPC) in the utility's production cost dispatch model that documents changes from previous net power cost estimates. All relevant workpapers and documentation to allow any other person to perform an independent analysis and verification of the NPC will be provided.

3. Show how the plant addition impacts planned outages, unplanned outages, and maintenance at the utility's generation resources.

R746-700-40. Information for a General Rate Case Application for a Telecommunications Corporation.

An applicant submitting a general rate case application shall provide the following information with the application, on a total company and Utah jurisdictional basis using Commission approved allocation methods. An applicant will provide an index which identifies where in the application, testimony, exhibits, documents, information, data, etc. filed with the application the applicant has responded to and complied with these R746-700-40 rule requirements. The index may be presented in testimony, as a table embedded in testimony, as an exhibit to testimony, or in any other manner so long as it is clearly identified.

A. General Information

1. Historical results of operations information consisting of actual, unadjusted results of operations, including all regulated costs and revenues, for an historical 12-month period used as a basis for the test period.

2. Adjusted results of operations for the same period. These adjustments shall include, but are not limited to, normalization adjustments, annualization adjustments, accounting adjustments, adjustments to reflect prior Utah regulatory decisions and policies made by the Commission with respect to any item or matter (including those which are not supported or advocated by the applicant for use in the general rate case) contained in the application.

3. Description and details for all additional adjustments necessary to arrive at the test period used in the general rate case application.

4. A description of any significant changes in accounting policies or procedures for the 12-month period prior to the historical period and any subsequent accounting changes through the date of the general rate case application and, if a future test period is used, any future changes included in a future test period, along with their impact on the filing. Significant changes for this purpose are anything referenced or that would be referenced in footnotes of financial statements or auditor's reports.

5. Information giving a fully referenced Part 64 and, where available, a Part 36 allocation. If no Part 36 allocation information is available, the utility shall provide an alternative permitting comparable cost of service allocations. Fully referenced means that sources of all total amounts are indicated and that source documents are included in the filed information. The names and sources of allocators to determine jurisdictional or non regulated portions shall be included in lines with the allocated amounts. The Part 64 allocation shall provide full allocation of all joint costs incurred by the utility for both non-regulated and regulated activities and affiliated companies.

6. A copy of each adjusting journal entry made with supporting documentation in response to the utility's independent auditors' final recommendations in their most recent audit of the utility. The utility will identify and provide adjusting journal entries included in the independent auditors' final recommendations that were not accepted by or made by the utility, along with a description of why the adjustment was not accepted or made.

7. A copy of management letters received from the utility's outside auditors or responses to those management letters for the time period of the beginning of the historical period to the date of filing of the application.

8. A listing of internal audits, and copies thereof, conducted by or for the Company or its parent for the time period beginning with the historical period to the date of the application, if relevant to the costs the utility seeks to recover from Utah ratepayers through Utah regulatory operations or the costs are allocated or directly charged to Utah regulated operations included in the general rate case application.

9. Beginning with the start of the historical period, provide the affiliates organization chart for the utility including a clear indication of affiliates, parent companies, divisions and subsidiaries indicating their regulatory status. Include a personnel organization chart with names that provides line of authority and reporting for board members, management and mid-management including joint responsibilities for non-regulated affiliate responsibilities.

10. A detailed description of corporate restructurings and changes in affiliate relationships since the prior general rate case and also describe changes in the corporate and affiliate relationships between the historical period and the end of the test period used in the application.

11. Beginning with the two years prior to the historical period through the date of the application, provide the beginning bad debt reserve balance, the amount written off, the recoveries, the reserve adjustment, other charges or credits, and the ending reserve balance. For the same period, provide the total amount of retail revenue from retail sales and total retail bad debt expense.

12. A detailed description of any changes in the utility's collection policies or write-off policies since the last general rate case.

13. A list of penalties and fines in the historical period and the test period and indicate in which accounts the associated amounts are included.

14. Description of all calculations and all supporting spreadsheets and explicit data source information for all numbers in the narrative portion of the application or any testimony and exhibits included with the application.

B. Tax adjustments

1. An exhibit explaining procedures used to calculate test period tax adjustments.

2. An adjustment summary for tax expenses for normalized results of operations.

3. Information explaining every adjustment that is done to test period tax expense and that is shown in the adjustment summary. Adjustments will be in "top sheet" form.

4. A list of, revenue ruling requests, IRS responses, and correspondence between the utility and the IRS since the last general rate case.

5. A copy of the current tax sharing agreement in which the company participates.

6. List all property held for future use included in rate base. Listed property shall not include any item included in plant in service in rate base and the pro forma balance. The description shall include:

a. Location of property;

b. Date of acquisition;

c. Original cost;

d. Accumulated depreciation;

e. net original cost;

f. Planned or expected in-service date; and

g. Planned or expected use of property.

7. Copies of supporting work papers on the account Property Held for Future Use which shall include an explanation of all additions and transfers, including:

a. Description of property;

b. Description of transaction; and

c. Amount.

C. An applicant need not file the following information or documents with a general rate case application, but shall have such information and documents available for delivery and shall include a certification with its application that this information and these documents have been prepared and are available at the time it files its general rate case application. Contemporaneously with the filing of an application, an applicant shall also deliver this information and these documents to the Division of Public Utilities.

1. The financial audit work papers for the most recent completed financial audit conducted by the utility's independent auditors. The utility will provide a letter authorizing the external audit firm to meet with requesting parties to discuss work papers with them and allow parties to make copies of selected work papers.

2. Any revenue ruling requests, IRS responses, and correspondence between the utility and the IRS since the last general rate case.

3. Copies of the most recent State and Federal income tax returns in which the utility participated.

R746-700-41. Cost of Service and Rate Design Information for a General Rate Case Application for a Telecommunications Corporation.

An applicant shall file the following Cost of Service and Rate Design information with any general rate case application.

A. A Utah Class Cost of Service Study or alternative comparable class cost of service information based on the test period with supporting documentation including the development of allocation factors.

B. Its proposal for spreading any Utah revenue requirement change among the rate schedules. This will include the dollar and percentage revenue requirement change for each rate schedule.

C. Its proposed rates for each rate component of each rate schedule and the billing determinants for the test period for all rate components used to calculate revenues necessary to recover the proposed revenue requirement.

D. Its proposed tariff sheets for all terms, rates, charges fees, etc. for which it proposes changes.

R746-700-50. Information for a General Rate Case Application for a Water Corporation.

An applicant shall be in compliance with the reporting requirements of R746-400 prior to submitting an application for a general rate case. If the applicant is not in compliance with that rule, the applicant shall first submit any missing reports prior to submitting an application for a general rate case. An applicant submitting a general rate case application shall provide the following information with the application:

A. General Information:

1. Most recent Division of Drinking Water certification/report.

2. Certificate of Public Convenience and Need Number granted by the Commission and its date.

3. Date the utility started operation.

4. The number of connections approved and current area served, which may be shown by service area map.

5. Ownership and officers.

6. Associated companies (if any).

7. A copy of its current tariff.

B. Engineering Information.

1. Source of water supply

2. Information for all Wells

3. Mains and meters information

4. Reservoirs information

5. Storage capacity

6. Service deficiencies and remedies

7. Service quality

8. Additions or improvements in the last five years

9. Any anticipated additions or improvements

10. Efforts to encourage conservation

C. Customer Connection Information

1. Each connection identified by unique lot number or address

2. The date first put into service

3. Whether metered or unmetered.

4. Whether classified as residential or commercial

5. The water usage per month or billing cycle, showing minimum and overage gallons used

6. The amount billed per month or billing cycle

7. The anticipated growth, showing minimum and overage gallons used

8. Water usage and billings projected for the next three years

9. Information on any secondary/irrigation water system (the same information as C. 1, 2, 5, 6, 7 and 8 above).

10. Identification whether secondary water is distributed through the culinary system.

D. Accounting and Financial Data, which shall include the prior two complete years and current up to the date of general rate case application, unless otherwise specified:

1. Identification (contact information) for any accountant used by the utility.

2. Copies of the General Ledger.

3. Copies of the Balance Sheet

4. Copies of the Income Statement

5. Pro Forma Income Statements, categorized by the National Association of Regulatory Utility Commissions, NARUC, System of Accounts, to include:

a. the prior two years of revenues and expenses, and

b. the projected revenues and expenses for the next three years, to include the Company's anticipated growth rate and requested rate increase.

6. A copy of or the utility's check register

7. Billing documentation/reports, tied back to the tariff rates

8. Information on the utility plant, including, but not limited to:

a. Acquisition date,

b. Acquisition price or cost,

c. Salvage value,

d. Expected useful life,

e. Annual depreciation amount per asset,

f. Accumulated depreciation per asset and reconciled to the total accumulated depreciation amount to the most recent Annual Report. (If these amounts do not match the most recent Annual Report provide detailed explanations for any needed adjustments),

g. If an asset was donated, the amount applied to Contribution in Aid of Construction per asset,

h. If donated, the accumulated amortization of the Contribution in Aid of Construction per asset and reconciled to the total accumulated amortization amount to the most recent Annual Report. (If these amounts do not match the most recent Annual Report provide detailed explanations for any needed adjustments), and

i. Projected future asset purchases for the next three years, providing the estimated acquisition date and price.

9. Copies of tax returns for the prior two complete years,

10. Information on all Notes Payable, Loans, and other Obligations, This will include all outstanding and those retired within the past two years, including:

a. Interest rate,

b. Beginning date,

c. Date of last scheduled payment (the Loan pay-off date), and

d. Amount of payment

E. Customer Notice Information

1. A copy of any notice sent to customers notifying them that the utility is seeking a rate increase.

R746-700-51. Cost of Service and Rate Design Information for a General Rate Case Application for a Water Corporation.

An applicant shall file the following Cost of Service and Rate Design information with any general rate case application.

A. A Class Cost of Service Study, if one has been prepared, based on the test period with supporting documentation including the development of allocation factors.

B. Its proposal for spreading any revenue requirement change among the rate schedules. This will include the dollar and percentage revenue requirement change for each rate schedule.

C. Its proposed rates for each rate component of each rate schedule and the billing determinants for the test period for all rate components used to calculate revenues necessary to recover the proposed revenue requirement.

D. Its proposed tariff sheets for all terms, rates, charges fees, etc. for which it proposes changes.

KEY

utilities, filings, applications, major plant additions

Date of Enactment or Last Substantive Amendment

September 23, 2009

Notice of Continuation

September 22, 2014

Authorizing, Implemented, or Interpreted Law

54-7-12(1)(b)(ii); 54-7-13.4(1)(a)(ii)


Additional Information

Contact

For questions regarding the content or application of rules under Title R746, please contact the promulgating agency (Public Service Commission, Administration). A list of agencies with links to their homepages is available at http://www.utah.gov/government/agencylist.html or from http://www.rules.utah.gov/contact/agencycontacts.htm.