Glasgow Electric Plant Board

Transcription

1 FINANCIAL STATEMENTS AND SUPPLEMENTARY INFORMATION June 30,

2 Table of Contents June 30, 2018 REPORT Independent Auditors Report 1 FINANCIAL STATEMENTS Required Supplementary Information: Management s Discussion and Analysis 4 Financial Statements: Statement of Net Position 10 Statement of Revenues, Expenses, and Changes in Net Position 12 Statement of Cash Flows 13 Notes to the Financial Statements 15 Required Supplementary Information: Schedule of Utility s Proportionate Share of the Net Pension Liability and Schedule of Utility s Contributions County Employees Retirement System 39 Schedule of Utility s Proportionate Share of the Net OPEB Liability and Schedule of Utility s Contributions County Employees Retirement System 41 Supplementary Information: Statement of Combining Revenues, Expenses, and Changes in Net Position By Division 43 Schedule of Operating Revenue and Expense Electric Division 44 Schedule of Operating Revenue and Expense CATV Division 47 Schedule of Operating Revenue and Expense LAN Division 49 Schedule of Operating Revenue and Expense JMYTC Division 51 Schedule of Statistical Information Electric Division 52

3 Table of Contents June 30, 2018 Independent Auditors Report on Internal Control over Financial Reporting and on Compliance and Other Matters Based on an Audit of Financial Statements Performed in Accordance with Government Auditing Standards 54 Schedule of Comments and Recommendations 56 THOUGHT LEADERSHIP Join Our Conversation

4 REPORT

5 Carr, Riggs & Ingram, LLC 922 State Street Bowling Green, Kentucky PO Box 104 Bowling Green, Kentucky (270) (270) (fax) Independent Auditors Report Board of Directors Glasgow Electric Plant Board Glasgow, Kentucky 167 South Main Street Russellville, Kentucky (270) (270) (fax) Report on the Financial Statements We have audited the accompanying financial statements of the Glasgow Electric Plant Board (the Utility ), a component unit of the City of Glasgow, Kentucky, as of and for the year ended June 30, 2018, and the related notes to the financial statements, which collectively comprise the Utility s basic financial statements as listed in the table of contents. Management s Responsibility for the Financial Statements Management is responsible for the preparation and fair presentation of these financial statements in accordance with accounting principles generally accepted in the United States of America; this includes the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error. Auditors Responsibility Our responsibility is to express an opinion on these financial statements based on our audit. We conducted our audit in accordance with auditing standards generally accepted in the United States of America and the standards applicable to financial audits contained in Government Auditing Standards, issued by the Comptroller General of the United States. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free from material misstatement. An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the financial statements. The procedures selected depend on the auditors judgment, including the assessment of the risks of material misstatement of the financial statements, whether due to fraud or error. In making those risk assessments, the auditor considers internal control relevant to the entity s preparation and fair presentation of the financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity s internal control. Accordingly, we express no such opinion. An audit also includes evaluating the appropriateness of accounting policies used -1-

6 Board of Directors Glasgow Electric Plant Board and the reasonableness of significant accounting estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion. Opinion In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Glasgow Electric Plant Board as of June 30, 2018, and the changes in financial position, and its cash flows thereof for the year then ended in accordance with accounting principles generally accepted in the United States of America. Emphasis of Matter As described in Note 1 to the financial statements, in 2018, the Utility adopted new accounting guidance, GASB Statement No. 75, Accounting and Financial Reporting for Postemployment Benefits Other Than Pensions. Our opinion is not modified with respect to this matter. Other Matters Required Supplementary Information Accounting principles generally accepted in the United States of America require that the management s discussion and analysis and select pension and other postemployment benefits (OPEB) information on pages 4 through 9 and 39 through 42 be presented to supplement the basic financial statements. Such information, although not a part of the basic financial statements, is required by the Governmental Accounting Standards Board, who considers it to be an essential part of financial reporting for placing the basic financial statements in an appropriate operational, economic, or historical context. We have applied certain limited procedures to the required supplementary information in accordance with auditing standards generally accepted in the United States of America, which consisted of inquiries of management about the methods of preparing the information and comparing the information for consistency with management s responses to our inquiries, the basic financial statements, and other knowledge we obtained during our audit of the basic financial statements. We do not express an opinion or provide any assurance on the information because the limited procedures do not provide us with sufficient evidence to express an opinion or provide any assurance. Other Information Our audit was conducted for the purpose of forming an opinion on the financial statements that collectively comprise the Utility s basic financial statements. The statement of combining revenues, expenses, and changes in net position and schedule of operating revenue and expense per division are presented for purposes of additional analysis and are not a required part of the basic financial statements. Such information is the responsibility of management and was derived from and relates -2-

7 Board of Directors Glasgow Electric Plant Board directly to the underlying accounting and other records used to prepare the basic financial statements. Such information has been subjected to the auditing procedures applied in the audit of the basic financial statements and certain additional procedures, including comparing and reconciling such information directly to the underlying accounting and other records used to prepare the basic financial statements or to the basic financial statements themselves, and other additional procedures in accordance with auditing standards generally accepted in the United States of America. In our opinion, the statement of combining revenues, expenses, and changes in net position and schedule of operating revenue and expense per division are fairly stated in all material respects, in relation to the basic financial statements as a whole. The schedule of statistical information electric division has not been subjected to the auditing procedures applied in the audit of the basic financial statements and, accordingly, we do not express an opinion or provide any assurance on it. Other Reporting Required by Government Auditing Standards In accordance with Government Auditing Standards, we have also issued our report dated October 18, 2018, on our consideration of the Utility s internal control over financial reporting and on our tests of its compliance with certain provisions of laws, regulations, contracts, and grant agreements and other matters. The purpose of that report is solely to describe the scope of our testing of internal control over financial reporting and compliance and the results of that testing, and not to provide an opinion on internal control over financial reporting or on compliance. That report is an integral part of an audit performed in accordance with Government Auditing Standards in considering Glasgow Electric Plant Board s internal control over financial reporting and compliance. CARR, RIGGS & INGRAM, LLC Bowling Green, Kentucky October 18,

8 FINANCIAL STATEMENTS

9 MANAGEMENT S DISCUSSION AND ANALYSIS As management of the Glasgow Electric Plant Board, we offer readers of the Utility s financial statements this narrative overview and analysis of the financial activities of the Utility for the fiscal years ended June 30, 2018 and All amounts, unless otherwise indicated, are expressed in dollar amounts. Financial Highlights Management believes the Utility s financial condition is strong. The Utility is well within the stringent financial policies and guidelines set by the Board and management. The graphs on the following pages highlight key financial data. Management wants to inform the reader that although there are two years of financial information provided, year-to-year comparisons are not possible. This is due to the implementation of GASB75 Accounting and Financial Reporting for Postemployment Benefits Other Than Pensions and the lack of information for periods prior to the current fiscal year. Revenues/Expenses: Revenues for FY 2018 show a decrease. This is due to grant monies received from a TVA/EPA project being included in revenue in the previous year. The same is applicable for expenses. Significant Expenses: Purchased power for Electric decreased slightly from last fiscal year. This correlates to the decrease in sales revenues. Programming expense increased over the previous fiscal year, reflecting price increases from our cable programming vendors. LAN bandwidth expense decreased slightly from the previous year due to the reduction in cost of service. Debt Service Coverage (Times): Decreased from the previous year. Continues to meet bond requirements as well as TVA recommendation. Capital Asset and Long-term Debt Activity: We have met all deposit requirements to our bond reserve accounts and payments of principal and interest on bonds have been met. OVERVIEW OF THE FINANCIAL STATEMENTS AND SUPPLEMENTARY INFORMATION Management s Discussion and Analysis (MD&A) serves as an introduction to, and should be read in conjunction with, the financial statements and supplementary information. The MD&A represents management s examination and analysis of the System s financial condition and performance. Summary financial statement data, key financial and operational indicators used in the System s strategic plan, budget, bond resolutions and other management tools were used for this analysis. The Financial Statements and Supplementary Information are made up of four sections: 1) the -4-

10 introductory sections, 2) the financial section, 3) the other supplementary information section and 4) the internal control and compliance section. The introductory section includes the System s directory. The financial section includes the MD&A, the independent auditor s report, the financial statements with accompanying notes, and the supplementary information. The other supplementary information section includes selected financial and operational information. The internal control and compliance section includes the report on internal control and compliance. These sections make up the financial report presented here. REQUIRED FINANCIAL STATEMENTS A Proprietary Fund is used to account for the operation of the System, which is financed and operated in a manner similar to private business enterprises where the intent is that the costs of providing services to the general public on a continuing basis be financed or recovered primarily through user charges. The financial statements report information about the System, using accounting methods similar to those used by private sector companies. These statements offer short- and long-term financial information about its activities. The Statement of Net Assets presents the financial position of the System on a full accrual historical cost basis. The statement includes all of the System s assets and liabilities and provides information about the nature and amounts of investments in resources (assets) and the obligations to the System s creditors (liabilities). It also provides the basis for computing rate of return, evaluating the capital structure of the System, and assessing the liquidity and financial flexibility of the System. The Statement of Revenues, Expenses and Changes in Net Assets presents the results of the business activities over the course of the fiscal year and information as to how the net assets change during the year. All changes in net assets are reported as soon as the underlying event giving rise to the change occurs, regardless of the timing of the related cash flows. This statement measures the success of the System s operations and can be used to determine whether the System has successfully recovered all of its costs. This statement also measures the System s profitability and credit worthiness. The Statement of Cash Flows presents changes in cash and cash equivalents, resulting from operations, financing and investing activities. This statement presents cash receipts and cash disbursements information, without consideration of the earnings event, when an obligation arises. The Notes to Financial Statements provide required disclosures and other information that are essential to a full understanding of material data provided in the statements. The notes present information about the System s accounting policies, significant account balances and activities, material risk, obligations, commitments, contingencies and subsequent events, if any. -5-

11 FINANCIAL ANALYSIS The Statement of Net Position and the Statement of Activities report information about the Utility s activities that help measure the financial health or financial position of the Utility. Over time, an increase in the Utility s net position is an indicator of whether its financial health is improving or deteriorating. Other non-financial factors, such as changes in economic conditions, customer growth and legislative mandates should also be considered when analyzing this information. It is important to note the Utility implemented GASB 68 and GASB 71 during FY 2015 and GASB 75 during the current year. The analysis below focuses on the Utility s net position (Table 1) and activities (Table 2) during the current and previous fiscal years. Table 1 CONDENSED STATEMENT OF NET POSITION June 30, 2018 June 30, 2017 Current and other assets $ 16,483,736 $ 16,425,525 Capital assets 31,815,465 31,996,908 Total assets 48,299,201 48,422,433 Deferred outflows of resources 4,064,155 1,794,655 Total deferred outflows of resources 4,064,155 1,794,655 Non-current liabilities 28,951,238 26,615,292 Other liabilities 9,274,714 8,888,150 Total liabilities 38,225,952 35,503,442 Deferred inflows of resources 996,149 32,720 Total deferred inflows of resources 996,149 32,720 Invested in capital assets 16,082,666 15,105,466 Unrestricted (2,941,411) (424,540) Total net position $ 13,141,255 $ 14,680,926 The increase in deferred outflows, non-current liabilities, and deferred inflows, as well as the decrease in total net position, are due to the recording requirement of pension and OPEB related activities as stated by GASB68, GASB71 and GASB

12 Table 2 CONDENSED STATEMENT OF ACTIVITIES June 30, 2018 June 30, 2017 Revenues: Electric $ 29,055,620 $ 29,906,792 Cable TV 5,226,738 5,416,172 LAN 2,983,209 2,813,259 JMYTC 55,275 56,100 Total revenues 37,320,842 38,192,323 Expenses: Electric $ 28,782,055 $ 29,350,250 Cable TV 6,584,755 6,443,762 LAN 1,280,605 1,286,324 JMYTC - - Total expenses 36,647,415 37,080,336 Change in net position 673,427 1,111,987 Effect of adoption of GASB 75 (2,213,098) - Total net position - beginning 14,680,926 13,568,939 Total net position - ending $ 13,141,255 $ 14,680,926 The prior period adjustment in 2018 is related to the implementation of GASB 75. CAPITAL ASSETS AND DEBT ADMINISTRATION Capital Assets At the end of fiscal year 2018, the System had $31.8 million (net of accumulated depreciation) invested in a broad range of Utility capital assets. This investment includes land, land rights, distribution and transmission systems and their related equipment, and various types of equipment, including Cable TV, and broadband fiber optic plant. Based on the uses of the aforementioned assets, they are classified for financial purposes as transmission plant, distribution plant, general plant, electric plant held for future use, construction in progress, and other property Telecom. This investment represents an overall decrease (net of increases and decreases) of 0.1% from last year. Only small capital projects have been completed in the current year. The following tables summarize the System s capital assets, net of accumulated depreciation, and changes therein, for the years ended June 30, 2018 and These changes are presented in detail in Note 5 to the financial statements. -7-

13 Table 3 UTILITY PLANT IN SERVICE, NET OF ACCUMULATED DEPRECIATION June 30, 2018 June 30, 2017 Transmission plant $ 1,627,886 $ 1,695,440 Distribution plant 18,947,427 18,751,298 General plant 6,454,041 6,462,834 Electric plant held for future use 10,000 10,000 Construction in progress 430, ,339 Other property - Telecom 4,346,084 4,781,997 Total capital assets (net) $ 31,815,465 $ 31,996,908 The only portion of plant that had significant additions was Construction in Progress, due to an increase in work performed by contract labor. No other major additions occurred in the current year, along with continued depreciation caused net capital assets to decrease from previous years. The Utility plans on using existing financial resources, increased funds from planned rate increases and proceeds from future bond issues to continue upgrading and expanding existing and adding new systems where it sees fit. Debt Administration Principal payments are due in the upcoming fiscal year in the amount of $2,293,651 with interest payments totaling approximately $591,523 also due. Details relating to the outstanding debt can be found in Note 6. The System is well within its debt covenants and foresees no problems in the future relating to outstanding debt. DEBT SERVICE COVERAGE Operating revenues $ 36,773,954 $ 37,046,094 Operating expenses 35,069,514 34,752,419 Operating income 1,704,440 2,293,675 Depreciation expense 2,200,699 2,125,342 Net revenue before debt service 3,905,139 4,419,017 Estimated debt service 2,885,174 2,918,793 Coverage (times) ECONOMIC FACTORS AND NEXT YEAR S RATES The Utility s wholesale energy provider changes the Total Monthly Fuel Cost (FCA) on a monthly basis. Each month the fuel cost charge is adjusted to reflect TVA s actual costs of providing the fuel -8-

14 necessary to produce the energy sold to the Utility. For the last several years, and again this year, TVA is increasing the base energy wholesale rates by 1.5%, on average, and is also implementing a Grid Access Charge, which is equivalent to one cent per kwh sold, effective October 1, 2018, while also implementing a corresponding one cent reduction in the base rate to make this move revenue neutral. The Utility s board will implement new retail rates, as recommended by TVA, to collect the additional revenue necessary to offset this rate increase and those should become effective on October 1, 2018 as well. The Utility also is asking TVA to approve rate adjustments to the Utility s retail rates that will bring in additional revenue to offset increasing operating costs. This adjustment will likely be effective December 1, The Utility s Board and management will need to analyze and adjust cable and internet rates annually to accomplish the mandate of operating on a not-for-profit basis. The transparent, costbased rates are projected to generate additional revenue for these services in order to keep the combined cable and internet businesses at a break-even point, to maintain this status. On April 1, 2012, the EPB moved to the TVA mandated Time-of-Use (TOU) wholesale rate environment. Detailed studies by the Utility, over several years, uncovered numerous wholesale/retail rate mismatches wherein low load factor customers were being served at a loss which was facilitated by excess revenues collected from higher load factor customers. In years past, Glasgow enjoyed the consistent growth of several industrial, high load factor customers, which allowed the Utility to make a lot of the money necessary to operate the local power grid. The electricity sold to these large companies also provided excess revenue that was used to reduce the electric bills to homes and small businesses, who previously were not paying enough to cover the actual cost to serve them. Unfortunately, in recent years, industrial sales have decreased and that has made it difficult to maintain the system reliability and low costs that customers expect. After analyzing all this data, a new retail rate structure, called the Variable Cost Retail Rate, was developed to make rates fairer for everyone by ceasing to use the over-collection of revenue from any class of customers as a way to lower rates for another class of customers. This rate was approved by TVA and put into effect for all retail customers on January 1, After complaints by Glasgow City Council, in September 2016 an optional conventional all-in kwh rate was developed and offered by the EPB after approval from TVA. The impact on a full year of revenues on both retail rates has been analyzed for the accomplishment of the rate design goals and needed changes to meet the goals, as mentioned above, have been recommended to the board, and the board has approved the recommended changes contingent upon TVA s approval of same. CONTACTING THE AUTHORITY S FINANCIAL MANAGEMENT This financial report is designed to provide a general overview of the System s finances for all those with an interest in the System s finances and to demonstrate the System s accountability for the money it receives. Questions concerning any information provided in this report or requests for any additional information should be directed to the General Manager of Glasgow Electric Plant Board, P.O. Box 1809, Glasgow, KY

15 Statement of Net Position As of June 30, 2018 Assets Current assets Cash and cash equivalents $ 7,589,333 Accounts receivable - less allowance for doubtful accounts of $63,141 3,962,369 Materials and supplies 551,787 Prepayments 117,581 Total current assets 12,221,070 Utility plant Utility plant in service 54,501,305 Other property - Telcom 12,609,098 Less accumulated depreciation (35,294,938) Total utility plant - net 31,815,465 Other assets Restricted cash and cash equivalents 3,430,124 Other investments 290,940 Goodwill - net of accumulated amortization of $1,082, ,922 Software - net 47,680 Total other assets 4,262,666 Total assets 48,299,201 Deferred Outflows of Resources Pension related 3,084,803 Other post-employment benefits related 846,393 Deferred loss on debt refunding 132,959 Total deferred outflows of resources 4,064,155 The accompanying notes are an integral part of the financial statements. -10-

16 Statement of Net Position As of June 30, 2018 Liabilities Current liabilities Accounts payable $ 4,754,026 Current portion of long-term debt 2,293,651 Accrued vacation 495,998 Accrued taxes 256,667 Consumer deposits 1,110,692 Accrued interest 69,608 Other accrued liabilities 169,323 Unearned revenue 124,749 Total current liabilities 9,274,714 Non-current liabilities Unearned revenue 200,836 Bonds payable - net of current portion 15,910,283 Notes payable - net of current portion 860,360 Net pension liability 8,909,464 Net other post-employment benefits liability 3,070,295 Total non-current liabilities 28,951,238 Total liabilities 38,225,952 Deferred Inflows of Resources Pension related 835,397 Other post-employment benefits related 160,752 Total deferred inflows of resources 996,149 Net Position Net investment in capital assets 16,082,666 Unrestricted (2,941,411) Total net postion $ 13,141,255 The accompanying notes are an integral part of the financial statements. -11-

17 Statement of Revenues, Expenses, and Changes in Net Position For the year ended June 30, 2018 Operating Revenues $ 36,773,954 Operating Expenses Cost of sales and service 26,102,515 Operations expense 5,956,899 Maintenance expense 746,348 Provision for depreciation 2,200,699 Amortization of goodwill 63,053 Total operating expenses 35,069,514 Total operating income 1,704,440 Nonoperating Revenue (Expenses) Interest and other income 90,270 Interest expense (704,380) Loss on disposition of property (5,933) Amortization of debt discount (6,522) TVA SET project revenues 59,060 TVA SET project expenses (90,261) Total nonoperating expenses (657,766) Income before transfers 1,046,674 Transfers Transfers out - tax equivalents (373,247) Change in net position 673,427 Net position beginning of year 14,770,379 Effect of adoption of GASB 75 (2,213,098) Net position end of year $ 13,230,708 The accompanying notes are an integral part of the financial statements. -12-

18 Statement of Cash Flows For the year ended June 30, 2018 Cash flows from operating activities Cash received from customers and others $ 36,553,664 Cash paid to suppliers and employees (31,236,996) Net cash provided by operating activities 5,316,668 Cash flows from capital and related financing activities Principal paid on bonds and notes (2,266,449) Interest paid on bonds and notes (708,259) Net construction and acquisition of plant (2,149,353) Net cash used in capital and related financing activities (5,124,061) Cash flows from non-capital financing activities Increase in customer deposits 47,762 Amounts paid to others - tax equivalents (373,247) Net cash used in non-capital financing activities (325,485) Cash flows from investing activities Interest received 89,740 Net cash provided by investing activities 89,740 Decrease in cash and cash equivalents (43,138) Cash and cash equivalents beginning of year 11,062,595 Cash and cash equivalents end of year $ 11,019,457 The accompanying notes are an integral part of the financial statements. -13-

19 Statement of Cash Flows For the year ended June 30, 2018 Reconciliation of operating income to net cash provided by operating activities Operating income $ 1,704,440 Adjustments to reconcile change in net position to net operating activities: Provision for depreciation 2,324,863 Amortization 69,575 TVA SET project unreimbursed expenses (31,201) Increase in accounts receivable (198,391) Decrease in materials and supplies 94,752 Increase in prepayments and other current assets (60,763) Increase in deferred inflows/outflows on pension, net (637,230) Increase in deferred inflows/outflows on other post-employment benefits, net (685,641) Decrease in deferred outflows on debt refunding 16,800 Increase in accounts payable and accrued expenses 335,160 Increase in pension liability 1,568,663 Increase in other post-employment benefit liability 857,197 Decrease in unearned revenue (41,556) Net cash provided by operating activities $ 5,316,668 The accompanying notes are an integral part of the financial statements. -14-

20 Notes to Financial Statements NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Reporting Entity The Glasgow Electric Plant Board (the Utility ), a nonprofit utility company was created by ordinance of the City of Glasgow, Kentucky enacted on January 6, 1958, and respectively, under the provision of Kentucky Revised Statute to and the governing board of the utility is appointed by the City of Glasgow City Council. The Utility is a distributor of electrical power under the authority of the Federal Energy Regulatory Commission (FERC) and the Tennessee Valley Authority (TVA). The Plant Board provides electric service, cable television, internet access, and other miscellaneous services within their service area, to residents of the City of Glasgow and portions of Barren County, Kentucky. These financial statements present only the Glasgow Electric Plant Board, a component unit of the City of Glasgow, Kentucky. Measuring Focus, Basis of Accounting, and Financial Statement Presentation The Utility's financial statements are presented on the full accrual basis of accounting in accordance with accounting principles generally accepted in the United States of America. Revenues are recorded when earned, and expenses are recorded when a liability is incurred, regardless of the timing of related cash flows. The accounting policies of the Utility conform to applicable generally accepted accounting principles as defined in the pronouncements of the Governmental Accounting Standards Board (GASB). Enterprise funds distinguish operating revenues and expenses from non-operating items. Operating revenue and expenses generally result from providing services and delivering goods in connection with the enterprise fund's principal ongoing operations. The principal operating revenues of the Utility are charges for sales to customers for sales and service. Operating expenses for the enterprise funds include the cost of sales and service, administrative expense, and depreciation on capital assets. All revenues and expenses not meeting this definition are reported as nonoperating revenues and expenses. The books of account are kept in accordance with the provision of the power contract with Tennessee Valley Authority and meet the requirements of the FERC's chart of accounts. The Utility, through the business of providing services to customers (nearly all of whom are local residents), grants credit to those customers, and which is basically unsecured. This results in the Utility incurring monthly losses associated with uncollectible accounts and is reflected in the Utility s operating expenses. When both restricted and unrestricted resources are available for use, it is the Utility's policy to use restricted resources first, and then unrestricted resources as needed. -15-

21 NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED) Jointly Governed Organization Glasgow Electric Plant Board Notes to Financial Statements The Utility is one of the municipal utility members of the MuniNet Fiber Agency. This association was created to link the local municipal utilities in western Kentucky to each other for redundancy and for the economic access to Internet Access Providers (IAPs), available through group purchasing. The Utility s participation in MuniNet Fiber Agency is designed to produce lower cost access to internet bandwidth than that which it could procure by itself. The cost associated with the joint venture is maintained on the equity method and reflected in other investments in the accompanying financial statements. Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues, expenses, and other changes in net position during the reporting period. Estimates and assumptions are reviewed periodically and the effects of revisions are reflected in the financial statements in the period that are determined to be necessary. Actual results could differ from the estimates. Cash Equivalents The Utility's cash equivalents are considered to be liquid investments with original maturities of three months or less. For the purposes of the statements of cash flows, cash and cash equivalents consist of restricted and unrestricted cash and cash equivalents. Accounts Receivable Trade receivables result from unpaid billings for service to customers and from unpaid billings related to work performed or materials sold to certain entities. All trade receivables are shown net of an allowance for uncollectible accounts. The allowance for uncollectible customer accounts recorded by the Utility is based on past history of uncollectible accounts and management's analysis of current accounts. Materials and Supplies All materials and supplies inventories are valued at the lower of average cost or net realizable value, using the first-in/first-out (FIFO) method. -16-

22 NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED) Prepaid Items Glasgow Electric Plant Board Notes to Financial Statements Certain payments to vendors reflect costs applicable to future accounting periods and are recorded as prepaid items in the financial statements. Restricted Assets Certain proceeds of the bond issues, as well as certain resources set aside for their repayment, are classified as restricted assets on the statement of net position because they are maintained in separate bank accounts and their use is limited by applicable bond covenants. Additionally, certain funds are set aside for construction funded through long-term debt and for the creation of reserves for depreciation of plant and the retirement of related debt. Utility Plant Utility plant, which include property, plant, equipment, and construction in progress, are defined by the Utility as assets with an initial, individual cost of more than $500 and an estimated useful life in excess of five years. Such assets are recorded at historical cost or estimated historical cost if purchased or constructed. Original cost includes materials, labor, transportation, and such other indirect costs as engineering, supervision, and employee fringe benefits. Assets acquired through contributions from developers or other customers are capitalized at their fair market value at the date of donations. The cost of normal maintenance and repairs that do not add to the value of the asset or materially extend assets' lives are not capitalized. Major outlays for capital assets and improvements are capitalized as projects are constructed. Interest incurred during the construction phase of capital assets is included as part of the capitalized value of the assets constructed. For the years ended June 30, 2018 and 2017, there was no capitalized interest. As property units are retired in the ordinary course of business, the cost of the property plus removal cost less salvage, is charged to accumulated depreciation. Property, plant, and equipment of the Utility are depreciated using the straight-line method over the following useful lives: General Plant Transmission Plant Distribution Plant Other Property - Telcom 5-40 years years years 5-40 years -17-

23 NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED) Compensated Absences Glasgow Electric Plant Board Notes to Financial Statements It is the Utility's policy to permit employees to accumulate earned but unused personal benefits. Personal leave earned by employees is accrued based on years of continuous service. The maximum personal leave that can be carried forward from year to year is the greater of 1,040 hours or the total converted amount under the new policy at January 1, All personal leave pay has been accrued and is reflected as a liability in the financial statements. When an employee ceases to be employed, all benefits shall cease to accrue at the end of the month during which active employment ends. Unearned Revenue Unearned revenue arises when assets are recognized before revenue recognition criteria have been satisfied. Deferred Outflows of Resources Pension related The Utility reports decreases in net position that relate to future periods as deferred outflows of resources in a separate section of its financial statement of net position. The deferred outflows of resources reported in this year s financial statements include (1) a deferred amount arising from the refunding of bonds, (2) a deferred outflow of resources for contributions made to the Utility s defined benefit pension plan between the measurement date of the net pension liabilities from the plan and the end of the Utility s fiscal year, and (3) deferred outflows of resources related to the differences between the expected and actual demographics for the cost sharing defined benefit plan. The deferred refunding amount is being amortized over the remaining life of the refunding bonds as part of interest expense. Deferred outflows for pension contributions will be recognized in the subsequent fiscal year. The deferred amounts related to the actuarial assumptions for demographic factors in the cost sharing pension plan will be recognized over a closed period equal to the average of the expected remaining services lives of all employees participating in the plan. Deferred Inflows of Resources Pension related The Utility s statement of net position reports a separate section for deferred inflows of resources. This separate financial statement element reflects an increase in net position that applies to a future period(s). Deferred inflows of resources are reported in the Utility s various statements of net position for actual pension plan investment earnings in excess of the expected amounts included in determining pension expense. This deferred inflow of resources is attributed to pension expense over a total of 5 years, including the current year. Deferred inflows of resources also include changes in the proportion and differences between employee contributions and the proportion share of contributions in the cost sharing plan. -18-

24 NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED) Deferred Inflows and Outflows of Resources OPEB related Glasgow Electric Plant Board Notes to Financial Statements The Utility s statement of net position reports a separate section for deferred inflows and outflows of resources related to OPEB which includes only certain categories of deferred outflows of resources and deferred inflows of resources. These include differences between expected and actual experience, changes of assumptions, and differences between projected and actual earnings on plan investments. Deferred outflows include resources for the Utility s contributions made subsequent to the measurement date. Deferred outflows and inflows related to differences between projected and actual earnings on plan investments are netted and amortized over a closed five-year period. Net Pension Liability For purposes of measuring the net pension liability, deferred outflows/inflows of resources related to pensions, and pension expense, information about the fiduciary net position of the Certified Employees Retirement System (CERS) and additions to/deductions from CERS fiduciary net position have been determined on the same basis as they are reported by CERS. For this purpose, benefit payments (including refunds of employee contributions) are recognized when due and payable in accordance with the benefit terms. The Utility s proportionate share of pension amounts were further allocated to each participating employer based on the contributions paid by each employer. Pension investments are reported at fair value. Note 8 provides further detail on the net pension liability. Net Other Post-Employment Benefits (OPEB) Liability For purposes of measuring the net OPEB liability, deferred outflows/inflows of resources related to OPEB, and OPEB expense, information about the fiduciary net position of the Certified Employees Retirement System (CERS) and additions to/deductions from CERS fiduciary net position have been determined on the same basis as they are reported by CERS. For this purpose, benefit payments are recognized when due and payable in accordance with the benefit terms. The Utility s proportionate share of OPEB amounts were further allocated to each participating employer based on the contributions paid by each employer. OPEB investments are reported at fair value. Note 9 provides further detail on the net OPEB liability. Post-Employment Health Care Benefits Retired Utility employees receive some health care benefits depending on their length of service. In accordance with Kentucky Revised Statutes, these benefits are provided and advanced-funded on an actuarially determined basis through the CERS plan. -19-

25 NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED) Long-term Obligations Glasgow Electric Plant Board Notes to Financial Statements Bond premiums and discounts are deferred and amortized over the life of the bonds using the effective interest method. Net Position The Utility classifies its net position into the following three categories: Net investment in capital assets - This represents the Utility s total investment in capital assets, net of accumulated depreciation, reduced by the outstanding balances of bonds that are attributable to the acquisition, construction, or improvement of those assets. Deferred outflows of resources and deferred inflows of resources that are attributable to the acquisition, construction, or improvement of those assets or related debt also should be included in this component of net position. Restricted - The restricted component of net position consists of restricted assets reduced by liabilities and deferred inflows of resources related to those assets. Generally, a liability relates to restricted assets if the asset results from a resource flow that also results in the recognition of a liability or if the liability will be liquidated with the restricted assets reported. Unrestricted - The unrestricted component of net position is the net amount of the assets, deferred outflows of resources, liabilities, and deferred inflows of resources that are not included in the determination of net investment in capital assets or the restricted component of net position. When an expense is incurred that can be paid using either restricted or unrestricted resources, the Utility s policy is to first apply the expense towards restricted resources, and then towards unrestricted resources. Subsequent Events The Utility has evaluated any recognized or unrecognized subsequent events for consideration in the accompanying financial statements through October 18, 2018, which was the date the financial statements were made available. Recently Issued and Adopted Accounting Pronouncements In June 2015, the GASB issued Statement No. 75, Accounting and Financial Reporting for Postemployment Benefits Other Than Pensions. The objective of this Statement is to address accounting and financial reporting for OPEB that is provided to the employees of state and local governmental employers. This Statement establishes standards for recognizing and measuring liabilities, deferred outflows of resources, deferred inflows of resources, and expenses. -20-

26 Notes to Financial Statements NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED) Recently Issued and Adopted Accounting Pronouncements (Continued) For defined benefit OPEB, this Statement identifies the methods and assumptions that are required to be used to project the benefit payments, discount projected benefit payments to their actuarial present value, and attribute that present value to periods of employee service. Note disclosure and required supplementary information requirements about defined benefit OPEB also are addressed. The Utility has implemented the new requirements of this statement for fiscal year ended June 30, The implementation of GASB 75 resulted in the reduction of beginning net position by $2,213,098. Recent Accounting Pronouncements In November 2016, the GASB issued Statement No. 83, Certain Asset Retirement Obligations. This Statement addresses accounting and financial reporting for certain asset retirement obligations (AROs). An ARO is a legally enforceable liability associated with the retirement of a tangible capital asset. A government that has legal obligations to perform future asset retirement activities related to its tangible capital assets should recognize a liability based on the guidance in this Statement. The requirements of this Statement are effective for reporting periods beginning after June 15, The Utility is evaluating the requirements of this Statement. In January 2017, the GASB issued Statement No. 84, Fiduciary Activities. The objective of this Statement is to improve guidance regarding the identification of fiduciary activities for accounting and financial reporting purposes and how those activities should be reported. This Statement establishes criteria for identifying fiduciary activities for all state and local governments. The focus of the criteria generally is on (1) whether a government is controlling the assets of the fiduciary activity and (2) the beneficiaries with whom a fiduciary relationship exists. Separate criteria are included to identify fiduciary component units and postemployment benefit arrangements that are fiduciary activities. The requirements of this Statement are effective for reporting periods beginning after December 15, The Utility is evaluating the requirements of this Statement. In June 2017, the GASB issued Statement No. 87, Leases. The objective of this Statement is to better meet the information needs of financial statement users by improving accounting and financial reporting for leases by governments. This Statement increases the usefulness of governments' financial statements by requiring recognition of certain lease assets and liabilities for leases that previously were classified as operating leases and recognized as inflows of resources or outflows of resources based on payment provisions of the contract. It establishes a single model for lease accounting based on the foundational principle that leases are financings of the right to use an underlying asset. Under this Statement, a lessee is required to recognize a lease receivable and a deferred inflow of resources, thereby enhancing the relevance and consistency of information about governments' leasing activities. The requirements of this Statement are effective for reporting periods beginning after December 15, The Utility is evaluating the requirements of this Statement. -21-

27 NOTE 1: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED) Recent Accounting Pronouncements (Continued) Glasgow Electric Plant Board Notes to Financial Statements In April 2018, the GASB issued Statement No. 88, Certain Disclosures Related to Debt, Including Direct Borrowings and Direct Placements. The primary objective of this Statement is to improve the information that is disclosed in notes to government financial statements related to debt, including direct borrowings and direct placements. It also clarifies which liabilities governments should include when disclosing information related to debt. The requirements of this Statement are effective for reporting periods beginning after June 15, The Utility is evaluating the requirements of this Statement. In June 2018, the GASB issued Statement No. 89, Accounting for Interest Cost Incurred Before the End of a Construction Period. The objectives of this Statement are (1) to enhance the relevance and comparability of information about capital assets and the cost of borrowing for a reporting period and (2) to simplify accounting for interest cost incurred before the end of a construction period. This Statement requires that interest cost incurred before the end of a construction period be recognized as an expense in the period in which the cost is incurred for financial statements prepared using the economic resources measurement focus. The requirements of this Statement are effective for reporting periods beginning after December 15, The Utility is evaluating the requirements of this Statement. In August 2018, the GASB issued Statement No. 90, Majority Equity Interests An Amendment of GASB Statements No. 14 and No. 61. The primary objectives of this Statement are to improve the consistency and comparability of reporting a government s majority equity interest in a legally separate organization and to improve the relevance of financial statement information for certain component units. It defines a majority equity interest and specifies that a majority equity interest in a legally separate organization should be reported as an investment if a government s holding of the equity interest meets the definition of an investment. A majority equity interest that meets the definition of an investment should be measured using the equity method, unless it is held by a special-purpose government engaged only in fiduciary activities, a fiduciary fund, or an endowment (including permanent and term endowments) or permanent fund. Those governments and funds should measure the majority equity interest at fair value. The requirements of this Statement are effective for reporting periods beginning after December 15, The requirements should be applied retroactively, except for the provisions related to (1) reporting a majority equity interest in a component unit and (2) reporting a component unit if the government acquires a 100 percent equity interest. Those provisions should be applied on a prospective basis. The Utility is evaluating the requirements of this Statement. NOTE 2: CASH AND CASH EQUIVALENTS Deposits All deposits are in various financial institutions and are carried at cost. At June 30, 2018, the carrying amount of the Utility's deposits was $11,019,457 and the bank balance was $11,017,

28 Notes to Financial Statements NOTE 2: CASH AND CASH EQUIVALENTS (CONTINUED) Custodial Credit Risk The Utility's policies limit deposits and investments to those instruments allowed by applicable state laws. State statutes require that all deposits with financial institutions must be collateralized by securities whose market value is equal to 100% of the value of uninsured deposits. The deposits must be collateralized by federal depository insurance, by collateral held by the Utility's agent in the Utility's name, or by the Federal Reserve Banks acting as third party agents. State statutes also authorize the Utility to invest in bonds, notes or treasury bills of the United States or any of its agencies, certificates of deposit that are insured by the FDIC or similar entity or fully collateralized and savings and loan associations and federally chartered banks and savings and loan associations, repurchase agreements utilizing obligations of the United States or its agencies as the underlying securities, the state pooled investment funds, and mutual funds. Statutes also require that securities underlying repurchase agreements must have a market value of at least equal to the amount of funds invested in the repurchase transaction. As of June 30, 2018, the Utility had deposits of $53,990 in excess of the FDIC insured amount and collateral held by the bank s agent in the Utility s name. Restricted Cash and Cash Equivalents Restricted cash and cash equivalent balances are comprised of account balances either restricted for debt service in accordance with various revenue bond ordinances or restricted for construction funded through long-term debt. As of June 30, 2018 Restricted for debt service: Sinking fund reserves $ 2,306,585 Capital improvement reserves 231,588 Restricted for construction, funded through long-term debt: Construction funds 891,951 Total restricted cash and cash equivalents $ 3,430,

29 Notes to Financial Statements NOTE 3: ACCOUNTS RECEIVABLE Accounts receivable as of the fiscal year ended June 30, 2018 consisted of the following: As of June 30, 2018 Electric $ 3,642,347 Non-electric 320,022 Accounts receivable, net $ 3,962,369 NOTE 4: GOODWILL During 2001, the Utility purchased the local existing cable system from Comcast Corporation for a purchase price of approximately $3,000,000. The purchase price was derived by multiplying the number of local Comcast customers by the calculated national value given to a cable customer at that point in time. As part of the purchase, the Utility acquired capital assets with a fair value of approximately $1,424,000. The remaining $1,576,000 paid to Comcast above the fair value of the capital assets was reflected as goodwill, representing the estimated customer value of future revenue streams. Based on the 2001 date of the purchase, the acquisition is reported under APB No. 16, which requires the amortization of goodwill over the estimated benefit time period not to exceed 40 years. The Utility s management estimated the benefit period from the goodwill to be 25 years based on the expectation of the customer base longevity; therefore, the goodwill is being amortized over the period of 25 years. As of June 30, 2018, the remaining goodwill, net of accumulated amortization was $493,922. For the year ended June 30, 2018, the Utility recognized amortization expense related to goodwill totaling $63,

30 Notes to Financial Statements NOTE 5: UTILITY PLANT Utility plant activity as of June 30, 2018 was as follows: Balance Balance Description June 30, 2017 Additions Disposals June 30, 2018 Capital assets, not being depreciated Transmission plant $ 38,708 $ - $ - $ 38,708 Distribution plant 43, ,743 General plant 21, ,830 Plant held for future use 10, ,000 Construction in progress 295,339 2,029,743 1,895, ,027 Total capital assets, not being depreciated 409,620 2,029,743 1,895, ,308 Capital assets, being depreciated Transmission plant 2,909,970 20,487 6,835 2,923,622 Distribution plant 33,286,265 1,215, ,715 34,225,856 General plant 16,412, ,476 45,438 16,841,224 Other property - Telcom 12,418, ,913 89,474 12,575,393 Total capital assets, being depreciated 65,027,375 1,956, ,462 66,566,095 Less accumulated depreciation Transmission plant 1,253,238 91,133 9,927 1,334,444 Distribution plant 14,578,710 1,125, ,754 15,322,172 General plant 9,971, ,668 42,837 10,409,013 Other property - Telcom 7,636, ,846 35,494 8,229,309 Total accumulated depreciation 33,440,087 2,324, ,012 35,294,938 Total capital assets, being depreciated, net 31,587,288 (368,681) (52,550) 31,271,157 Total capital assets, net $ 31,996,908 $ 1,661,062 $ 1,842,505 $ 31,815,465 Depreciation expense amounted to $1,572,853 in the electric department, $425,382 in the CATV division, and $202,464 in the LAN division totaling $2,200,699 for the fiscal year ended June 30, Depreciation expense for the CATV and LAN divisions are included in the profits for each individual division. Included in additions are depreciation expenses charged to transportation expense in the amount of $124,164 for the fiscal year ended June 30,

31 Notes to Financial Statements NOTE 6: LONG-TERM DEBT At June 30, 2018, long-term debt consisted of the following: As of June 30, 2018 Revenue Bonds, Series 2009, due annually with varying interest rates commencing at 2.00% and increasing to 4.50% over the life of the bond issue, payable semiannually. Principal payments are due annually every June 1, and vary until payoff on June 1, $ 4,440,000 Revenue Bonds, Series 2011, due annually with varying interest rates commencing at 1.50% and increasing to 3.20% over the life of the bond issue, payable semiannually. Principal payments are due annually every December 1, and vary until payoff on December 1, ,220,000 Revenue Bonds, Series 2012, due annually with varying interest rates commencing at.70% and increasing to 4.125% over the life of the bond issue, payable semiannually. Principal payments are due annually every December 1, and vary until payoff on December 1, ,640,000 Revenue Bonds, Series 2014A, due annually with varying interest rates commencing at 2% and increasing to 3.50% over the life of the bond issue, payable semiannually. Principal payments are due annually every June 1, and vary until payoff on June 1, ,615,000 Revenue Bonds, Series 2014B, due annually with varying interest rates commencing at 2% and increasing to 2.75% over the life of the bond issue, payable semiannually. Principal payments are due annually every December 1, and vary until payoff on December 1, ,000 Revenue Bonds, Series 2016A, due annually with varying interest rates commencing at 2% and increasing to 2.75% over the life of the bond issue, payable semiannually. Principal payments are due annually every June 1, and vary until payoff on June 1, ,445,000 Refunding Revenue Bonds, Series 2016B, due annually with a 3% interest rate, payable semiannually. Principal payments are due annually every June 1, and vary until payoff on June 1, ,160,000 Note payable, Kentucky Infrastructure Association, due annually with interest at 0.6% over the life of the loan, payable semiannually. Principal payments are due semiannually every December 1 and June 1, until payoff December 1, ,

32 Notes to Financial Statements NOTE 6: LONG-TERM DEBT (CONTINUED) As of June 30, 2018 Note payable, Edmonton State Bank, to be paid in full with interest at 2.49% over a period of seven years. The full approval amount of this loan was $419,648. Principal payments are due on the 29th of each month until payoff on March 29, ,250 Total bonds and notes payable 19,069,011 Less unamortized premium (discount) on bonds - net (4,717) Less current portion of bonds and notes payable (2,293,651) Net bonds and notes payable $ 16,770,643 The Utility complied with all significant debt covenants and restrictions as set forth in the bond agreements. Amortization for the year ended June 30, 2018 was $6,522 which included $814 charged to the Electric Division and $5,708 charged to the CATV Division. The following is a summary of long-term debt transactions for the year ended June 30, 2018: June 30, 2017 June 30, 2018 Due in Less Description Balance Increases Decreases Balance Than 1 Year Revenue bonds, Series 2009 $ 5,300,000 $ - $ (860,000) $ 4,440,000 $ 590,000 Revenue bonds, Series ,605,000 - (385,000) 1,220, ,000 Revenue bonds, Series ,730,000 - (90,000) 1,640,000 95,000 Revenue bonds, Series 2014A 2,745,000 - (130,000) 2,615, ,000 Revenue bonds, Series 2014B 645,000 - (100,000) 545, ,000 Revenue bonds, Series 2016A 2,555,000 - (110,000) 2,445, ,000 Revenue bonds, Series 2016B 5,595,000 - (435,000) 5,160, ,000 Note payable, KIA 825,656 - (58,895) 766,761 59,250 Note payable, BB&T 15,227 - (15,227) - - Note payable, ESB 319,577 - (82,327) 237,250 84,401 Subtotal 21,335,460 - (2,266,449) 19,069,011 2,293,651 Less unamortized premium (discount) on bonds - net (9,322) - 4,605 (4,717) - Total bonds and notes payable $ 21,326,138 $ - $ (2,261,844) $ 19,064,294 $ 2,293,

33 Notes to Financial Statements NOTE 6: LONG-TERM DEBT (CONTINUED) The annual debt service requirements to maturity, including principal and interest, as of June 30 are as follows: Principal Interest Total 2019 $ 2,293,651 $ 591,524 $ 2,885, ,361, ,922 2,879, ,771, ,807 2,226, ,325, ,724 1,735, ,360, ,917 1,730, ,073,949 1,231,757 7,305, ,192, ,983 3,557, ,000 35, ,075 Total $ 19,069,011 $ 3,975,709 $ 23,044,720 NOTE 7: OPERATING LEASE The Utility had one ongoing equipment operating lease throughout the year. If the lease agreement is defaulted, the lessor has the option to require the Utility to do any combination of the following: (1) return the equipment and/or (2) immediately pay the present value of the unpaid balance of the lease plus the residual value of the equipment lease. Rental expenditures for the year ended June 30, 2018 were $12,224. The following is a schedule of the future minimum rentals under the lease: For the year ended June 30, Amount 2019 $ 4,075 NOTE 8: PENSION PLAN General information about the County Employees Retirement System Non-Hazardous ( CERS ) Plan Description The Utility contributes to the Non-Hazardous CERS plan, a cost-sharing multiple-employer defined benefit pension plan that covers all regular full-time members of each participating county, city, and school board, and any additional eligible local agencies electing to participate in the plan. CERS is administered by the Board of Trustees of the Kentucky Retirement System. CERS issues a publicly available financial report that can be obtained at

34 Notes to Financial Statements NOTE 8: PENSION PLAN (CONTINUED) Benefits Provided CERS provides retirement, disability, and death benefits to plan members. Retirement benefits may be extended to beneficiaries of plan members under certain circumstances. Prior to July 1, 2009, Cost of Living Adjustments (COLAs) were provided annually equal to the percentage increase in the annual average of the consumer price index for all urban consumers for the most recent calendar year, not to exceed 5% in any plan year. After July 1, 2009, the COLAs were limited to 1.5%. No COLA has been granted since July 1, Tier 1 - Non-Hazardous Tier 1 plan members who began participating prior to September 1, 2008, are required to contribute 5% of their annual creditable compensation. These members are classified in the Tier 1 structure of benefits. Interest is paid each June 30 on members accounts at a rate of 2.5%. If a member terminates employment and applies to take a refund, the member is entitled to a full refund of contributions and interest. Tier 2 - Non-Hazardous Tier 2 plan members, who began participating on, or after, September 1, 2008, and before January 1, 2014, are required to contribute a total of 6% of their annual creditable compensation, while 1% of these contributions are deposited in an account created for the payment of health insurance benefits under 26 USC Section 401(h) in the Pension Fund (see Kentucky Administrative Regulation 105 KAR 1:420E). These members were classified in the Tier 2 structure of benefits. Interest is paid each June 30 on members accounts at a rate of 2.5%. If a member terminates employment and applies to take a refund, the member is entitled to a full refund of contributions and interest; however, the 1% contribution to the 401(h) account is non-refundable and is forfeited. Tier 3 - Non-Hazardous Tier 3 plan members who began participating on, or after, January 1, 2014, are required to contribute to the Cash Balance Plan. The Cash Balance Plan is known as a hybrid plan because it has characteristics of both a defined benefit plan and a defined contribution plan. Members in the plan contribute a set percentage of their salary each month to their own account. Non-hazardous members contribute 5% of their annual creditable compensation and 1% to the health insurance fund (401(h) account) which is not credited to the member s account and is not refundable. The employer contribution rate is set annually by the KRS Board of Trustees based on an actuarial valuation. The employer contributes a set percentage of the member's salary. Each month, when employer contributions are received, an employer pay credit is deposited to the member's account. For non-hazardous members, their account is credited with a 4% employer pay credit. The employer pay credit represents a portion of the employer contribution. Contributions Employers participating in the CERS were required to contribute at an actuarially determined rate. Per Kentucky Revised Statute Section (33), normal contribution and past service contribution rates shall be determined by the KRS Board of Trustees on the basis of an annual valuation last -29-

35 Notes to Financial Statements NOTE 8: PENSION PLAN (CONTINUED) Contributions (Continued) preceding the July 1 of a new biennium. The KRS Board of Trustees may amend contribution rates as of the first day of July of the second year of a biennium, if it is determined on the basis of a subsequent actuarial valuation that amended contribution rates are necessary to satisfy requirements determined in accordance with actuarial bases adopted by the KRS Board of Trustees. For the fiscal year ended June 30, 2018, participating employers contributed 14.48% of each employee's creditable compensation. The actuarially determined rate set by the KRS Board of Trustees for the fiscal year ended June 30, 2018 was 14.48%. Administrative costs of KRS are financed through employer contributions and investment earnings. Pension Liabilities, Pension Expense, and Deferred Outflows of Resources and Deferred Inflows of Resources Related to Pensions At June 30, 2018, the Utility reported a liability of $8,909,464 for its proportionate share of the net pension liability. The net pension liability was measured as of June 30, 2017, and the total pension liability used to calculate the net pension liability was determined by an actuarial valuation as of June 30, 2016 rolled forward to June 30, 2017 using standard update procedures. The Utility s proportion of the net pension liability was based on the Utility s share of 2017 contributions to the pension plan relative to the 2017 contributions of all participating employers, actuarially determined. At June 30, 2018, the Utility s proportion was %. For the year ended June 30, 2018, the Utility recognized pension expense of approximately $1,588,000. At June 30, 2018, the Utility reported deferred outflows of resources and deferred inflows of resources related to pensions from the following sources: Deferred Outflows of Resources Deferred Inflows of Resources Difference between expected and actual experience $ 11,088 $ 226,922 Net difference between projected and actual investment earnings on pension plan investments 707, ,424 Change of assumptions 1,643,785 - Changes in proportion and differences between employer contriutions and proportionate share of contribution 172,464 11,051 District contributions subsequent to the measurement date 549,471 - Total $ 3,084,803 $ 835,

36 Notes to Financial Statements NOTE 8: PENSION PLAN (CONTINUED) Pension Liabilities, Pension Expense, and Deferred Outflows of Resources and Deferred Inflows of Resources Related to Pensions (Continued) The $549,471 reported as deferred outflows of resources related to pensions resulting from Utility contributions subsequent to the measurement date will be recognized as a reduction of the net pension liability in the year ended June 30, As of June 30, 2018, other amounts reported as deferred outflows of resources and deferred inflows of resources related to pensions will be recognized in pension expense as follows: Actuarial Assumptions For the year ended June 30, 2019 $ 758, , , (114,787) Thereafter - The total pension liability, net pension liability, and sensitivity information as of June 30, 2017 were based on an actuarial valuation date of June 30, The total pension liability was rolled-forward from the valuation date (June 30, 2016) to the plan s fiscal year ending June 30, 2017, using generally accepted actuarial principles. The actuary did not perform the actuarial valuation as of June 30, 2016 but did replicate the prior actuary s valuations results on the same assumption, methods, and data, as of that date. The roll-forward is based on the results of the actuary s replication. Subsequent to the actuarial valuation date (June 30, 2016), but prior to the measurement date the KRS Board of Trustees reviewed investment trends, inflation, and payroll growth historical trends. Based on this review the Board adopted the following updated actuarial assumptions which were used in performing the actuarial valuation as of June 30, 2017 (measurement date), which were also used to determine the Total Pension Liability and Net Pension Liability as of June 30, Inflation 2.30% Salary Increases 3.05%, average Investment Rate of Return 6.25% The mortality table used for active members is RP-2000 Combined Mortality Table projected with Scale BB to 2013 (multiplied by 50% for males and 30% for females). For healthy retired members and beneficiaries, the mortality table used is the RP-2000 Combined Mortality Table projected with Scale BB to 2013 (set back 1 year for females). For disabled members, the RP-2000 Combined Disabled Mortality Table projected with Scale BB to 2013 (set back 4 years for males) is used for the period after disability retirement. -31-

37 Notes to Financial Statements NOTE 8: PENSION PLAN (CONTINUED) Discount Rate The projection of cash flows used to determine the discount rate of 6.25% assumed that local employers would contribute the actuarially determined contribution rate of projected compensation over the remaining 26 years (closed) amortization period of the unfunded actuarial accrued liability. The discount rate determination does not use a municipal bond rate. The target asset allocation and best estimates of arithmetic nominal rates of return for each major asset class are summarized in the KRS plan s CAFR. Sensitivity of the Utility s Proportionate Share of the Net Pension Liability to Changes in the Discount Rate The following presents the Utility s proportionate share of the net pension liability calculated using the discount rate of 6.25%, as well as what the Utility s proportionate share of the net pension liability would be if it were calculated using a discount rate that is 1-percentage-point lower (5.25%) or 1-percentage-point higher (7.25%) than the current rate: 1% Decrease Current Discount Rate 1% Increase (5.25%) (6.25%) (7.25%) Utility's proportionate share of the net pension liability $ 11,274,596 $ 8,939,464 $ 6,986,143 Pension Plan Fiduciary Net Position Detailed information about the pension plan s fiduciary net position is available in the separately issued KRS plan s CAFR. NOTE 9: POSTEMPLOYMENT BENEFITS OTHER THAN PENSIONS (OPEB) General Information about the County Employees Retirement System s (CERS) OPEB Plan Plan Description The Utility s employees are provided OPEB under the provisions of Kentucky Revised Statues, the Kentucky Retirement Systems (KRS) board administers the CERS Insurance Fund. The CERS Insurance Fund is a cost sharing, multiple employer defined benefit OPEB plan which provides group health insurance benefits for plan members that are all regular full-time members employed in nonhazardous duty positions of the Utility. OPEB may be extended to beneficiaries of the plan members under certain circumstances. The CERS Insurance Fund is included in a publicly available financial report that can be obtained at

38 Notes to Financial Statements NOTE 9: POSTEMPLOYMENT BENEFITS OTHER THAN PENSIONS (OPEB) (CONTINUED) Benefits Provided The CERS Insurance Fund provides hospital and medical benefits to eligible plan members receiving benefits from CERS. The eligible non-medicare retirees are covered by the Department of Employee Insurance (DEI) plans. Premium payments are submitted to DEI. The KRS board contracts with Humana to provide health care benefits to the eligible Medicare retirees. The CERS Insurance Fund pays a prescribed contribution for whole or partial payment of required premiums to purchase hospital and medical insurance. Contributions Employers participating in the CERS Insurance Fund contribute a percentage of each employee s creditable compensation. The actuarially determined rates set by the KRS board is a percentage of each employee s creditable compensation. For the year ended June 30, 2018, the required contribution was 4.70% of each employee s covered payroll. Contributions from the Utility to the CERS Insurance Fund for the year ended June 30, 2018, were $178,316. The KRS board may amend contribution rates as of the first day of July of the second year of a biennium, if it is determined on the basis of a subsequent actuarial valuation that amended contribution rates are necessary to satisfy requirements determined in accordance with actuarial bases adopted by the KRS board. Employees qualifying as Tier 2 or Tier 3 of the CERS plan members contribute 1% of creditable compensation to an account created for the payment of health insurance benefits under 26 USC Section 401(h) which are non-refundable and are forfeited. OPEB Liabilities, OPEB Expense and Deferred Outflows of Resources and Deferred Inflows of Resources Related to OPEB At June 30, 2018, the Utility reported a liability of $3,070,295 for its proportionate share of the net OPEB liability. The net OPEB liability was measured as of June 30, 2017, and the total OPEB liability used to calculate the net OPEB liability was determined by an actuarial valuation as of June 30, The Utility s proportion of the net OPEB liability was based on the Utility s share of 2017 contributions to the OPEB plan relative to the 2017 contributions of all participating employers, actuarially determined. At June 30, 2018, the Utility s proportion was %. For the year ended June 30, 2018, the Utility recognized OPEB expense of $349,

39 Notes to Financial Statements NOTE 9: POSTEMPLOYMENT BENEFITS OTHER THAN PENSIONS (OPEB) (CONTINUED) OPEB Liabilities, OPEB Expense and Deferred Outflows of Resources and Deferred Inflows of Resources Related to OPEB (Continued) At June 30, 2018, the Utility reported deferred outflows of resources and deferred inflows of resources related to OPEB from the following sources: Difference between expected and actual experience Deferred Outflows of Resources Deferred Inflows of Resources $ - $ 8,528 Net difference between projected and actual investment earnings on pension plan investments - 145,101 Change of assumptions 668,077 - Changes in proportion and differences between employer contriutions and proportionate share of contribution - 7,123 District contributions subsequent to the measurement date 178,316 - Total $ 846,393 $ 160,752 For the year ended June 30, 2018, $178,316 was reported as deferred outflows of resources related to OPEB resulting from Utility contributions subsequent to the measurement date and before the end of the fiscal year will be recognized as a reduction of the net OPEB liability in the year ended June 30, Other amounts reported as deferred outflows of resources and deferred inflows of resources related to OPEB will be recognized in OPEB expense as follows: For the year ended June 30, 2019 $ 87, , , , ,566 Thereafter 34,

40 Notes to Financial Statements NOTE 9: POSTEMPLOYMENT BENEFITS OTHER THAN PENSIONS (OPEB) (CONTINUED) Actuarial Assumptions The total OPEB liability, net OPEB liability, and sensitivity information as of June 30, 2017 were based on an actuarial valuation date of June 30, The total OPEB liability was rolled-forward from the valuation date (June 30, 2016) to the plan s fiscal year ending June 30, 2017, using generally accepted actuarial principles. The actuary did not perform the actuarial valuation as of June 30, 2016 but did replicate the prior actuary s valuations results on the same assumption, methods, and data, as of that date. The roll-forward is based on the results of the actuary s replication. Subsequent to the actuarial valuation date (June 30, 2016), but prior to the measurement date the KRS Board of Trustees reviewed investment trends, inflation, and payroll growth historical trends. Based on this review the Board adopted the following updated actuarial assumptions which were used in performing the actuarial valuation as of June 30, 2017 (measurement date), which were also used to determine the total OPEB Liability and net OPEB Liability as of June 30, Inflation 2.30% Payroll Growth Rate 2.00% Salary Increase 3.05%, average Investment Rate of Return 6.25% Healthcare Trend Rates (Pre-65) Healthcare Trend Rates (Post-65) Initial trend starting at 7.25% at January 1, 2019, and gradually decreasing to an ultimate trend rate of 4.05% over a period of 13 years. Initial trend starting at 5.10% at January 1, 2019, and gradually decreasing to an ultimate trend rate of 4.05% over a period of 11 years. The mortality table used for active members is RP-2000 Combined Mortality Table projected with Scale BB to 2013 (multiplied by 50% for males and 30% for females). For healthy retired members and beneficiaries, the mortality table used is the RP-2000 Combined Mortality Table projected with Scale BB to 2013 (set back 1 year for females). For disabled members, the RP-2000 Combined Disabled Mortality Table projected with Scale BB to 2013 (set back 4 years for males) is used for the period after disability retirement. Discount Rate The projection of cash flows used to determine the discount rate of 5.84% for CERS non-hazardous assumed that local employers would contribute the actuarially determined contribution rate of -35-

41 -36- Glasgow Electric Plant Board Notes to Financial Statements NOTE 9: POSTEMPLOYMENT BENEFITS OTHER THAN PENSIONS (OPEB) (CONTINUED) Discount Rate (Continued) projected compensation over the remaining 26 years (closed) amortization period of the unfunded actuarial accrued liability. The discount rate determination used an expected rate of return of 6.25%, and a municipal bond rate of 3.56%, as reported in Fidelity Index s 20-Year Municipal GO AA Index as of June 30, However, the cost associated with the implicit employer subsidy was not included in the calculation of the actuarial determined contributions, and any cost associated with the implicit subsidy will not be paid out of the OPEB Plan trusts. Therefore, the municipal bond rate was applied to future expected benefit payments associated with the implicit subsidy. The target asset allocation and best estimates of arithmetic nominal rates of return of each major asset class are summarized in the KRS plan s CAFR. Sensitivity of the Utility s Proportionate Share of the collective net OPEB Liability to Changes in the Discount Rate The following presents the Utility s proportionate share of the net OPEB liability as of June 30, 2018, calculated using the discount rate of 5.84%, as well as what the Utility s proportionate share of the net OPEB liability would be if it were calculated using a discount rate that is 1-percentage-point lower (4.84%) or 1-percentage-point higher (6.84%) than the current rate: 1% Decrease Current Discount Rate 1% Increase (4.84%) (5.84%) (6.84%) Utility's proportionate share of the net pension liability $ 3,906,780 $ 3,070,295 $ 2,374,208 Sensitivity of the Utility s Proportionate Share of the collective net OPEB Liability to Changes in the Health Care Cost Trend Rates The following presents the Utility s proportionate share of the collective net OPEB liability, as well as what the Utility s proportionate share of the collective net OPEB liability would be if it were calculated using health care cost trend rates that are 1-percentage-point lower or 1-percentagepoint higher than the current rate: Health Care Current Health Care Trend Rate Health Care Trend Rate 1% Decrease Trend Rate 1% Increase District's proportionate share of the collective net OPEB liability $ 2,355,074 $ 3,070,295 $ 4,000,040 OPEB Plan Fiduciary Net Position Detailed information about the OPEB plan s fiduciary net position is available in the separately issued CERS financial report.

42 Notes to Financial Statements NOTE 10: COMMITMENTS Power Contract The Utility has a power contract with Tennessee Valley Authority (TVA) whereby the electric system purchases all its electric power from TVA and is subject to certain restrictions and conditions as provided for in the power contract. Such restrictions include, but are not limited to, prohibitions against implementing discriminatory rates; furnishing, advancing, lending, pledging, or otherwise diverting Utility funds, revenues, or property to other operations of the Utility; and the purchase or payment of, or providing security for indebtedness on other obligations applicable to such other operations. Projects Entered Into With Other Governmental Units The Electric Plant Board and five other city and county entities share the cost of operation of the Barren Information Technology System (BITS), an office engaged in mapping Barren County. The pro rata share of the cost to the Electric Plant Board for the year ended June 30, 2018 was $22,380. NOTE 11: RISK MANAGEMENT The Utility is exposed to various risks of loss related to torts; theft of, damage to, and destruction of assets; errors and omissions; injuries to employees; and natural disasters. During the year ended June 30, 2018, the Utility purchased commercial insurance for all of the above risks. Settled claims have not exceeded this commercial coverage in any of the past three years, and there has been no significant reduction in the amount of coverage provided. Unemployment Insurance The Utility is liable for coverage of its employees under the Kentucky Unemployment Insurance Act. The Board has elected not to make quarterly contributions to the Kentucky Unemployment Fund, but to reimburse the Fund for actual charges against the Utility. The Utility has elected to set up a partial reserve to one year's contribution based on the current number of employees. This reserve is to be increased as the number of employees increases or as benefits are charged to the Utility. NOTE 12: INTERCOMPANY TRANSACTIONS In an agreement dated June 25, 2015 and approved by TVA, an intercompany loan was established in which the Cable Division owes a note payable to the Electric Division totaling $2,600,000. Annual principal payments of $173,333 began on December 1, The applicable interest rate is the highest interest rate then being earned on the invested Electric Division funds. The intercompany loan balance at June 30, 2018 was $2,080,

43 Notes to Financial Statements NOTE 12: INTERCOMPANY TRANSACTIONS (CONTINUED) Rent is paid to the Electric Division by two other Divisions of the plant board for office space and cable services. The amounts of rent paid to the Electric Division from the Cable and LAN Divisions for the year ended June 30, 2018 are as follows: For the year ended June 30, 2018 LAN $ 113,471 CATV 284,087 Total $ 397,558 These intercompany transactions have been eliminated in the accompanying financial statements. -38-

44 -39- Glasgow Electric Plant Board Schedule of Utility s Proportionate Share of the Net Pension Liability and Schedule of Utility s Contributions County Employees Retirement System Schedule of Utility's Proportionate Share of the Net Pension Liability - CERS As of June 30, Utility's proportion of the net pension liability % % % % Utility's proportionate share of the net pension liability $ 8,939,464 $ 7,340,819 $ 6,253,000 $ 4,787,000 Utility's covered - employee payroll $ 3,825,878 $ 3,657,705 $ 3,605,875 $ 3,618,815 Utility's proportionate share of the net pension liability as a percentage of its covered-employee payroll % % % % Plan fiduciary net position as a percentage of the total pension liability 53.30% 55.50% 59.97% 66.80% Schedule of Utility Contributions - CERS For the years ended June 30, Contractually required contribution $ 549,471 $ 533,710 $ 454,287 $ 434,205 Contributions in relation to the contractually required contribution (549,471) (533,710) (454,287) (434,205) Contribution deficiency (excess) $ - $ - $ - $ - Utility's covered-employee payroll $ 3,794,694 $ 3,825,878 $ 3,657,705 $ 3,605,875 Contributions as a percentage of covered-employee payroll 14.48% 13.95% 12.42% 12.04%

45 Schedule of Utility s Proportionate Share of the Net Pension Liability and Schedule of Utility s Contributions County Employees Retirement System Changes of Benefit Terms The following changes were made by the Kentucky Legislature and reflected in the valuation performed as of June 30 listed below: 2018: No changes in benefit terms. 2017: No changes in benefit terms. 2016: No changes in benefit terms. Changes of Assumptions The following changes were made by the Kentucky Legislature and reflected in the valuation performed as of June 30 listed below: 2018: There was no legislation enacted during the 2017 legislative session that had a material change in benefit provisions for CERS. However, subsequent to the actual valuation date (June 30, 2016), but prior to the measurement date (June 30, 2017), the KRS Board of Trustees adopted updated actuarial assumptions which will be used in performing the actuarial valuation as of June 30, Specifically, the Total Pension Liability as of June 30, 2017 is determined using a 2.30% price inflation assumption for the non-hazardous system and the assumed rate of return is 6.25% for the non-hazardous system. 2017: There was no legislation enacted during the 2017 legislative session that had a material change in benefit provisions for CERS. However, subsequent to the actual valuation date (June 30, 2016), but prior to the measurement date (June 30, 2017), the KRS Board of Trustees adopted updated actuarial assumptions which will be used in performing the actuarial valuation as of June 30, Specifically, the Total Pension Liability as of June 30, 2017 is determined using a 2.30% price inflation assumption for the non-hazardous system and the assumed rate of return is 6.25% for the non-hazardous system. 2016: No changes in assumptions. -40-

46 Schedule of Utility s Proportionate Share of the Net OPEB Liability and Schedule of Utility s Contributions County Employees Retirement System Schedule of Utility's Proportionate Share of the Net OPEB Liability - CERS As of June 30, 2018 Utility's proportion of the net OPEB liability % Utility's proportionate share of the net OPEB liability $ 3,070,295 Utility's covered - employee payroll $ 3,825,878 Utility's proportionate share of the net OPEB liability as a percentage of its covered-employee payroll 80.25% Plan fiduciary net position as a percentage of the total OPEB liability 52.40% Schedule of Utility Contributions - CERS For the years ended June 30, 2018 Contractually required contribution $ 178,316 Contributions in relation to the contractually required contribution (178,316) Contribution deficiency (excess) $ - Utility's covered-employee payroll $ 3,794,694 Contributions as a percentage of covered-employee payroll 4.70% Changes of Benefit Terms The following changes were made by the Kentucky Legislature and reflected in the valuation performed as of June 30 listed below: 2018: No changes of benefit terms. -41-

47 Schedule of Utility s Proportionate Share of the Net OPEB Liability and Schedule of Utility s Contributions County Employees Retirement System Changes of Assumptions The following changes were made by the Kentucky Legislature and reflected in the valuation performed as of June 30 listed below: 2018: There was no legislation enacted during the 2017 legislative session that had a material change in benefit provisions for CERS. However, subsequent to the actual valuation date (June 30, 2016), but prior to the measurement date (June 30, 2017), the KRS Board of Trustees adopted updated actuarial assumptions which will be used in performing the actuarial valuation as of June 30, Specifically, the Total OPEB Liability as of June 30, 2017 is determined using a 2.30% price inflation assumption for the non-hazardous system and the assumed rate of return is 6.25%. -42-

48 -43- Glasgow Electric Plant Board Statement of Combining Revenues, Expenses and Changes in Net Position By Division Electric CATV LAN JMYTC For the year ended June 30, 2018 Division Division Division Division Total Operating Revenues $ 28,906,598 $ 5,226,489 $ 2,983,150 $ 55,275 $ 37,171,512 Operating Expenses Cost of sales and services 21,334,851 4,495, ,874-26,102,515 Operations expense 4,040,414 1,522, ,696-6,354,457 Maintenance expense 738,099 5,539 2, ,348 Provision for depreciation 1,572, , ,464-2,200,699 Amortization of goodwill - 63, ,053 Total operating expenses 27,686,217 6,512,111 1,268,744-35,467,072 Operating income 1,220,381 (1,285,622) 1,714,406 55,275 1,704,440 Nonoperating Revenue (Expenses) Interest and other income 89, ,270 Interest and other expense (631,516) (66,936) (11,861) - (710,313) Amortization debt discount (814) (5,708) - - (6,522) TVA SET project revenues 59, ,060 TVA SET project expenses (90,261) (90,261) Total nonoperating revenue (expenses) (573,569) (72,395) (11,802) - (657,766) Income before transfers 646,812 (1,358,017) 1,702,604 55,275 1,046,674 Transfers Transfers out - tax equivalents (373,247) (373,247) Change in net position $ 273,565 $ (1,358,017) $ 1,702,604 $ 55,275 $ 673,427

49 Schedule of Operating Revenue and Expense Electric Division For the year ended June 30, 2018 Amount Percent Operating Revenue Sales of Electric Energy Residential sales $ 7,776, % Commercial and industrial sales Commercial sales 3,698, % Industrial sales 16,058, % Street and outdoor lighting sales 569, % Forfeited discounts 99, % Total commercial and industrial sales 20,425, % Total sales of electric energy 28,202, % Other Revenue Miscellaneous service 220, % Rent from electric property 482, % Other electric revenue 1, % Total other revenue 704, % Total operating revenue 28,906, % Operating Expenses Cost of sales and service Purchased power 21,334, % Total cost of sales and service 21,334, % Operations Expense Distribution Expense Supervision and engineering 24, % Load dispatching 161, % Station expense 54, % Overhead line expense 150, % Street lighting 9, % Meters 174, % Consumer installation 4, % Miscellaneous expense 171, % Total distribution expense 750, % -44-

50 Schedule of Operating Revenue and Expense Electric Division For the year ended June 30, 2018 Amount Percent Customer Accounts Expense Supervision 24, % Customer records and collection 261, % Uncollectible accounts 22, % Total customer accounts expense 308, % Sales Expense Supervision 93, % Customer assistance expense 115, % Informational and instructional advertising 55, % Total sales expense 264, % Administrative and General Expense Salaries 525, % Office supplies 132, % Outside service 28, % Property insurance 53, % Injuries and damages 71, % Employee pensions and benefits 1,712, % Miscellaneous 38, % Taxes 155, % Total administrative and general expense 2,716, % Total operations expense 4,040, % Maintenance expense Supervision and engineering 24, % Maintenance of station equipment 49, % Maintenance of overhead lines 575, % Maintenance of street lighting and signal system 4, % Maintenance of meters 73, % Maintenance of miscellaneous distribution plant 5, % Maintenance of general plant 7, % Total maintenance expense 738, % Provision for depreciation 1,572, % Total operating expense 27,686, % -45-

51 Schedule of Operating Revenue and Expense Electric Division For the year ended June 30, 2018 Amount Percent Nonoperating Revenue (Expenses) Interest and other income 89, % Interest and other expense (631,516) % Amortization debt discount (814) 0.14% TVA SET Project revenues 59, % TVA SET Project expenses (90,261) 15.74% Total nonoperating revenue (expenses) (573,569) % Transfers (373,247) % Change in net position $ 273, % -46-

52 Schedule of Operating Revenue and Expense CATV Division For the year ended June 30, 2018 Amount Percent Operating Revenue Economy service $ 1,574, % Essential service 2,077, % Premier service 268, % Premier HD service 142, % Premium service 117, % Pay-per-view 19, % Equipment rental 490, % Commercial insertion 208, % Miscellaneous one time charge 35, % Local origination income 20, % Miscellaneous service revenue 93, % Wire maintenance plan 163, % Commission 12, % Total operating revenue 5,226, % Operating Expenses Cost of sales and service Programming 4,495, % Total cost of sales and service 4,495, % Operations expense Customer records and collections 105, % Selling expense 88, % Customer information and service 53, % Customer information 32, % Customer incentives 23, % Supervision and engineering 81, % Customer installation 353, % Uncollectible accounts 8, % Employee benefits 167, % Outside services 4, % Administrative and general salaries 56, % Office supplies and expenses 78, % Taxes 49, % Rent 284, % Local origination expense 13, % -47-

53 Schedule of Operating Revenue and Expense CATV Division For the year ended June 30, 2018 Amount Percent Property insurance 37, % General and administration % Miscellaneous operating expenses 81, % Injuries and damages 1, % Total operations expense 1,522, % Maintenance Expense Maintenance 5, % Provision for Depreciation and Amortization Depreciation 425, % Amortization of goodwill 63, % Total provision for depreciation and amortization 488, % Total operating expense 6,512, % Nonoperating Revenue (Expenses) Other income % Amortization of debt discount (5,708) 7.88% Interest on long-term debt (66,936) 92.46% Total nonoperating revenue (expenses) (72,395) % Change in net position $ (1,358,017) % -48-

54 Schedule of Operating Revenue and Expense LAN Division For the year ended June 30, 2018 Amount Percent Operating Revenue Data service $ 2,544, % LAN bulk 94, % LAN installation income 26, % Additional addresses 6, % LAN equipment 35, % Rental of web space 4, % LAN one time charge 32, % Fiber ethernet circuit 136, % Fiber lease 87, % Muninet 13, % Total operating revenue 2,983, % Operating Expense Cost of sales and services Internet access cost 271, % Total cost of sales and services 271, % Operations expense Operation supervision 33, % Distribution expenses 148, % Rent 167, % Customer assistance 143, % Uncollectible accounts 5, % Customer installation 4, % Customer incentives 3, % Administrative and general salaries 75, % Office supplies and expenses 54, % Outside services 4, % Property insurance 27, % Injuries and damages 1, % Employee benefits 99, % Other expenses 1, % Taxes 19, % Total operations expense 791, % -49-

55 Schedule of Operating Revenue and Expense LAN Division For the year ended June 30, 2018 Amount Percent Maintenance Expense Maintenance of data plant 2, % Provision for Depreciation Depreciation 202, % Total operating expense 1,268, % Nonoperating Revenue (Expenses) Interest expense (11,861) % Other income % Total nonoperating revenue (expenses) (11,802) -0.50% Change in net position $ 1,702, % -50-

56 Schedule of Operating Revenue and Expense JMYTC Division For the year ended June 30,2018 Amount Percent Operating Revenue Colocation service $ 55, % Total operating income 55, % Change in net position $ 55, % -51-

57 For the year ended June 30, 2018 Glasgow Electric Plant Board Summary of Statistical Information Electric Division Revenue Residential $ 7,776,177 Commercial 3,698,539 Industrial 16,058,183 Street and outdoor lighting 569,859 Forfeited discounts 99,264 Other operating 704,576 Interest and other income 89,962 Total revenue 28,996,560 Expense Cost of sales and service 21,334,851 Operations expense 4,040,414 Maintenance expense 730,979 Administrative and general expense 7,120 Provision for depreciation 1,572,853 Amortization of debt discount 814 Transfer out 373,247 Interest and other expense 662,717 Total expense 28,722,995 Change in net position $ 273,565 Financial Plant in service (at original cost) $ 54,094,983 Bonds and notes outstanding $ 16,845,000 Power in use - KWH Residential 64,596,748 Commercial 28,324,827 Industrial 184,423,629 Street lighting 2,105,805 Security lighting 1,417,250 Total 280,868,

58 For the year ended June 30, 2018 Glasgow Electric Plant Board Summary of Statistical Information Electric Division Number of customers Residential 5,557 Commercial 1,644 Industrial 220 Street lighting 15 Security lighting 562 Total 7,

59 Carr, Riggs & Ingram, LLC Independent Auditors Report on Internal Control over Financial Reporting and on Compliance and Other Matters Based on an Audit of Financial Statements Performed in Accordance with Government Auditing Standards 922 State Street Bowling Green, Kentucky PO Box 104 Bowling Green, Kentucky (270) (270) (fax) 167 South Main Street Russellville, Kentucky (270) (270) (fax) Members of the Board Glasgow Electric Plant Board Glasgow, Kentucky We have audited, in accordance with the auditing standards generally accepted in the United States of America and the standards applicable to financial audits contained in Government Auditing Standards issued by the Comptroller General of the United States, the financial statements of the Glasgow Electric Plant Board (the Utility ), a component unit of the City of Glasgow, Kentucky, as of and for the year ended June 30, 2018, and the related notes to the financial statements, which collectively comprise the Utility s basic financial statements, and have issued our report thereon dated October 18, Internal Control Over Financial Reporting In planning and performing our audit of the financial statements, we considered the Utility s internal control over financial reporting (internal control) to determine the audit procedures that are appropriate in the circumstances for the purpose of expressing our opinion on the financial statements, but not for the purpose of expressing an opinion on the effectiveness of the Utility s internal control. Accordingly, we do not express an opinion on the effectiveness of the Utility s internal control. A deficiency in internal control exists when the design or operation of a control does not allow management or employees, in the normal course of performing their assigned functions, to prevent, or detect and correct, misstatements on a timely basis. A material weakness is a deficiency, or a combination of deficiencies, in internal control, such that there is a reasonable possibility that a material misstatement of the entity s financial statements will not be prevented, or detected and corrected on a timely basis. A significant deficiency is a deficiency, or a combination of deficiencies, in internal control that is less severe than a material weakness, yet important enough to merit attention by those charged with governance. Our consideration of internal control was for the limited purpose described in the first paragraph of this section and was not designed to identify all deficiencies in internal control that might be material weaknesses or significant deficiencies, and therefore, material weaknesses or significant deficiencies may exist that have not been identified. Given these limitations, during our audit we did not identify any deficiencies in internal control that we consider to be material weaknesses. We did identify certain deficiencies in internal control, described in the accompanying schedule of -54-

60 Board of Directors Glasgow Electric Plant Board comments and recommendations, that we consider to be significant deficiencies as item numbers , , and Compliance and Other Matters As part of obtaining reasonable assurance about whether the Utility's financial statements are free from material misstatement, we performed tests of its compliance with certain provisions of laws, regulations, contracts, and grant agreements, noncompliance with which could have a direct and material effect on the determination of financial statement amounts. However, providing an opinion on compliance with those provisions was not an objective of our audit and, accordingly, we do not express such an opinion. The results of our tests disclosed no instances of noncompliance or other matters that are required to be reported under Government Auditing Standards. Glasgow Electric Plant Board s Response to Findings The Utility s response to the findings identified in our audit is described in the accompanying schedule of comments and recommendations. The Utility s response was not subjected to the auditing procedures applied in the audit of the financial statements and, accordingly, we express no opinion on it. Purpose of this Report The purpose of this report is solely to describe the scope of our testing of internal control and compliance and the results of that testing, and not to provide an opinion on the effectiveness of the entity s internal control or on compliance. This report is an integral part of an audit performed in accordance with Government Auditing Standards in considering the entity s internal control and compliance. Accordingly, this communication is not suitable for any other purpose. CARR, RIGGS & INGRAM, LLC Bowling Green, Kentucky October 18,

61 Schedule of Comments and Recommendations SEGREGATION OF DUTIES Criteria and Condition: A system of internal controls provides for the proper segregation of accounting functions. There is improper segregation of duties in relation to the cash disbursements. Cause: The Finance Manager has the authority to approve invoices, sign checks, access the general ledger, and process electronic payments with limited, if any, review. The Accounting Manager has the authority to sign checks, access the general ledger, process electronic payments, and reconcile bank statements with limited, if any, review. Effect: Misappropriations could occur and not be detected by the Utility s internal controls. Recommendation: We recommend management consider the costs and benefits of separating duties to strengthen internal control in relation to cash disbursements (i.e., remove check signing authority from individuals with access to the general ledger). Views of Responsible Officials and Planned Corrective Actions: Management will determine the cost/benefit of the segregation of certain accounting functions. With the department staff being small, this may present a problem in which other personnel may need to be utilized to affect this change. Also, compensating controls will be put into place to reduce control risks INVENTORY MANAGEMENT Criteria and Condition: Materials and supplies inventories represent significant transactions of the Utility. Certain internal controls were not in place to safeguard these assets from theft, loss, and/or misappropriation during the course of the year. Cause: During our inventory observation procedures, we noted the following areas of concern: Employees have unlimited access to the materials and supplies inventory without utilizing a requisition process. The security gate was unlocked and open at an off-site inventory location. In addition, inventory items at this location were laying on the ground amongst overgrown vegetation and without any protection from the elements. Effect: Materials and supplies perpetual inventory balances recorded on the general ledger could be materially incorrect during the course of the year without being detected by management until the year-end inventory count procedures. Recommendation: The Utility should establish and implement an inventory control system to ensure materials and supplies inventory are properly reported throughout the year. This includes policies and procedures restricting the ability to access inventory stores to approved personnel, establishing a system for the daily requisition of required materials and supplies, as well as returned materials and supplies. In addition, inventory items at all locations should remain secured at all times behind locked gates and be protected from the elements to ensure items remain in good working condition. -56-

62 INVENTORY MANAGEMENT (CONTINUED) Glasgow Electric Plant Board Schedule of Comments and Recommendations Views of Responsible Officials and Planned Corrective Actions: The Facilities/Stores Technician will conduct daily debriefings with the Foremen to accurately record inventory transactions. Further, the Superintendent will make better recording of inventory transactions an area of emphasis on upcoming performance evaluations for all personnel involved in the work order processes. Periodic inventory observations will be conducted to more closely monitor possible inventory variations in order to provide metrics to measure the accomplishments of the emphasis. Also, a complete evaluation of all inventory processes will be completed. Inventory currently housed off-site will either be moved to a more secure location or junked, if obsolete LACK OF WRITTEN FRAUD POLICY Criteria and Condition: The Utility does not have a written fraud policy. Cause: Management has not defined, in written form, a policy addressing fraud issues for the Utility. Effect: Utility personnel will not understand management s expectations regarding fraud and will be unfamiliar with the appropriate steps to report fraudulent activity within the Utility. Recommendation: The Utility should provide a written fraud policy to all personnel addressing management s expectations regarding fraud issues and the reporting of fraudulent activity. Views of Responsible Officials and Planned Corrective Actions: Management will draft a fraud policy to be approved by the Board and included with all company policies. -57-

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