United States
SECURITIES ANDAND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
[X]☒ QuarterlyReport Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended:
SeptemberJune 30, 20182019
[ ]☐ TransitionReport Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the transition period from _______________ to _______________
Commission File No. | Name of Registrant, State of Incorporation, Address of Principal Executive Offices, and Telephone No. | IRS Employer Identification No. | ||
000-49965 | MGE Energy, Inc. (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin53788 (608) 252-7000 | mgeenergy.com | 39-2040501 | ||
000-1125 | Madison Gas and Electric Company (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin53788 (608) 252-7000 | mge.com | 39-0444025 |
Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant wasregistrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days:
MGE Energy, Inc.Yes [X]☒ No [ ]☐Madison Gas and Electric Company Yes ☒ No ☐
Indicate by check mark whether the registrants have submitted electronically and posted on their corporate Web sites, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files):
MGE Energy, Inc.Yes [X]☒ No [ ]☐Madison Gas and Electric Company Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer | Accelerated Filer | Non-accelerated Filer | Smaller Reporting Company | Emerging Growth Company | |
MGE Energy, Inc. |
| ☐ | ☐ | ☐ | ☐ |
Madison Gas and Electric Company | ☐ | ☐ |
| ☐ | ☐ |
If an emerging growth company, indicate by check mark if the registrant hasregistrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. [ ]
MGE Energy, Inc. ☐Madison Gas and Electric Company ☐
Indicate by check mark whether the registrant is aregistrants are shell companycompanies (as defined in Rule 12b-2 of the Exchange Act):
MGE Energy, Inc. and Yes ☐ No ☒Madison Gas and Electric Company:Company Yes [ ]☐ No [X]☒
Title of each class | Trading symbol(s) | Name of each exchange on which registered | ||
Common Stock, $1 Par Value Per Share | MGEE | The Nasdaq Stock Market |
Number of Shares Outstanding of Each Class of Common Stock as of | ||
MGE Energy, Inc. | Common stock, $1.00 par value, 34,668,370 shares outstanding. | |
Madison Gas and Electric Company | Common stock, $1.00 par value, 17,347,894 shares outstanding (all of which are owned beneficially and of record by MGE Energy, Inc.). | |
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Table of Contents
PART I. FINANCIAL INFORMATION.INFORMATION3
Where to Find More Information3
Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report4
Item 1. Financial Statements.Statements.6
Consolidated Statements of Income (unaudited)6
Consolidated Statements of Comprehensive Income (unaudited)
Consolidated Statements of Cash Flows (unaudited)7
Consolidated Balance Sheets (unaudited)8
Consolidated Statements of Common Equity (unaudited)9
Madison Gas and Electric Company10
Consolidated Statements of Income (unaudited)10
Consolidated Statements of Comprehensive Income (unaudited)
Consolidated Statements of Cash Flows (unaudited)11
Consolidated Balance Sheets (unaudited)12
Consolidated Statements of Equity (unaudited)13
MGE Energy, Inc., and Madison Gas and Electric Company14
Notes to Consolidated Financial Statements (unaudited)14
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.Operations.36
Item 3. Quantitative and Qualitative Disclosures About Market Risk.Risk.52
Item 4. Controls and Procedures.Procedures.54
PART II. OTHER INFORMATION.INFORMATION.55
Item 1. Legal Proceedings.Proceedings.55
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.Proceeds.55
Item 4. Mine Safety Disclosures.Disclosures.55
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PART I. FINANCIAL INFORMATION.
Filing Format
This combined Form 10-Q is being filed separately by MGE Energy, Inc. (MGE Energy) and Madison Gas and Electric Company (MGE). MGE is a wholly owned subsidiary of MGE Energy and represents a majority of its assets, liabilities, revenues, expenses, and operations. Thus, all information contained in this report relates to, and is filed by, MGE Energy. Information that is specifically identified in this report as relating solely to MGE Energy, such as its financial statements and information relating to its nonregulated business, does not relate to, and is not filed by, MGE. MGE makes no representation as to that information. The terms "we" and "our," as used in this report, refer to MGE Energy and its consolidated subsidiaries unless otherwise indicated.
Forward-Looking Statements
This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to economic conditions, future load growth, revenues, expenses, capital expenditures, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," "will," and other similar words generally identify forward-looking statements. Both MGE Energy and MGE caution investors that these forward-looking statements are subject to known and unknown risks and uncertainties that may cause actual results to differ materially from those projected, expressed, or implied.
The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant include: (a) those factors discussed in the registrants' 20172018 Annual Report on Form 10-K:10-K: Item 1A. Risk Factors, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, as updated by Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations in this report, and Item 8. Financial Statements and Supplementary Data – Note 17, as updated by Part I, Item 1. Financial Statements – Note 9 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.
Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this report. MGE Energy and MGE assume no obligation to release publicly any revision to these forward-looking statements to reflect events or circumstances after the date of this report, except as required by law.
Where to Find More Information
The public may read and copy any reports or other information that MGE Energy and MGE file with the SEC at the SEC's public reference room at 100 F Street, NE, Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. These documents also are available to the public from commercial document retrieval services, the website maintained by the SEC atsec.gov, MGE Energy's website atmgeenergy.com, and MGE's website atmge.com. Copies may be obtained from our websites free of charge. Information contained on MGE Energy's and MGE's websites shall not be deemed incorporated into, or to be a part of, this report.
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3
Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report
Abbreviations, acronyms, and definitions used in the text and notes of this report are defined below.
MGE Energy and Subsidiaries:
CWDCCentral Wisconsin Development Corporation
MAGAELMAGAEL, LLC
MGEMadison Gas and Electric Company
MGE EnergyMGE Energy, Inc.
MGE PowerMGE Power, LLC
MGE Power Elm RoadMGE Power Elm Road, LLC
MGE Power West CampusMGE Power West Campus, LLC
MGE ServicesMGE Services, LLC
MGE State Energy ServicesMGE State Energy Services, LLC
MGE TranscoMGE Transco Investment, LLC
MGEE TranscoMGEE Transco, LLC
North MendotaNorth Mendota Energy & Technology Park, LLC
Other Defined Terms:
ACEAffordable Clean Energy
AFUDCAllowance for Funds Used During Construction
AROAsset Retirement Obligation
ATCAmerican Transmission Company LLC
ATC HoldcoATC Holdco, LLC
BARTBest Available Retrofit Technology
BlountBlount Station
BSERBest System of Emissions Reductions
CAAClean Air Act
CAVRClean Air Visibility Rule
CCRCoal Combustion Residual
codificationFinancial Accounting Standards Board Accounting Standards Codification
ColumbiaColumbia Energy Center
cooling degree daysMeasure of the extent to which the average daily temperature is above 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide cooling
CPPClean Power Plan
CSAPRCross-State Air Pollution Rule
DthDekatherms, a quantity measure used in respect of natural gas
EGUsElectric Generating Units
electric marginElectric revenues less fuel for electric generation and purchase power costs, a non-GAAP measure
Elm Road UnitsElm Road Generating Station
EPAUnited States Environmental Protection Agency
FASBFinancial Accounting Standards Board
FERCFederal Energy Regulatory Commission
Forward WindForward Wind Energy Center
FTRFinancial Transmission Rights
GAAPGenerally Accepted Accounting Principles
gas marginGas revenues less cost of gas sold, a non-GAAP measure
GHGGreenhouse Gas
heating degree days (HDD)Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRSInternal Revenue Service
kWhKilowatt-hour, a measure of electric energy produced
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MISOMidcontinent Independent System Operator (a regional transmission organization)
MWMegawatt, a measure of electric energy generating capacity
MWhMegawatt-hour, a measure of electric energy produced
NAAQSNational Ambient Air Quality Standards
NOxNitrogen Oxides
PGAPurchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PPAPurchased Power Agreement
PSCWPublic Service Commission of Wisconsin
RiversideRiverside Energy Center
ROEReturn on Equity
SaratogaSaratoga Wind Farm
SCRSelective Catalytic Reduction
SECSecurities and Exchange Commission
SO2Sulfur Dioxide
Stock PlanDirect Stock Purchase and Dividend Reinvestment Plan of MGE Energy
Tax ActTax Cuts and Jobs Act
UWUniversity of Wisconsin at Madison
VIEVariable Interest Entity
WCCFWest Campus Cogeneration Facility
WEPCOWisconsin Electric Power Company, a subsidiary of WEC Energy Group, Inc.
working capitalCurrent assets less current liabilities
WPLWisconsin Power and Light Company, a subsidiary of Alliant Energy Corporation
XBRLeXtensible Business Reporting Language
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Item 1. Financial Statements.
MGE Energy, Inc.
Consolidated Statements of Income (unaudited)
(In thousands, except per share amounts)
|
| Three Months Ended |
| Six Months Ended | ||||
|
| June 30, |
| June 30, | ||||
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| 2019 |
| 2018 |
| 2019 |
| 2018 |
Operating Revenues: |
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Electric revenues | $ | 97,077 | $ | 99,282 | $ | 194,546 | $ | 194,149 |
Gas revenues |
| 25,070 |
| 24,980 |
| 95,170 |
| 87,745 |
Total Operating Revenues |
| 122,147 |
| 124,262 |
| 289,716 |
| 281,894 |
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Operating Expenses: |
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Fuel for electric generation |
| 10,403 |
| 15,251 |
| 24,320 |
| 27,151 |
Purchased power |
| 11,036 |
| 12,979 |
| 21,887 |
| 30,012 |
Cost of gas sold |
| 8,875 |
| 9,562 |
| 52,128 |
| 49,188 |
Other operations and maintenance |
| 48,974 |
| 43,453 |
| 95,910 |
| 87,846 |
Depreciation and amortization |
| 18,091 |
| 13,872 |
| 35,230 |
| 27,495 |
Other general taxes |
| 4,985 |
| 4,914 |
| 9,948 |
| 9,783 |
Total Operating Expenses |
| 102,364 |
| 100,031 |
| 239,423 |
| 231,475 |
Operating Income |
| 19,783 |
| 24,231 |
| 50,293 |
| 50,419 |
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Other income, net |
| 5,019 |
| 4,731 |
| 9,870 |
| 9,650 |
Interest expense, net |
| (5,749) |
| (4,783) |
| (11,396) |
| (9,522) |
Income before income taxes |
| 19,053 |
| 24,179 |
| 48,767 |
| 50,547 |
Income tax provision |
| (3,505) |
| (5,828) |
| (9,213) |
| (12,195) |
Net Income | $ | 15,548 | $ | 18,351 | $ | 39,554 | $ | 38,352 |
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Earnings Per Share of Common Stock |
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(basic and diluted) | $ | 0.45 | $ | 0.53 | $ | 1.14 | $ | 1.11 |
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Dividends per share of common stock | $ | 0.338 | $ | 0.323 | $ | 0.675 | $ | 0.645 |
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Weighted Average Shares Outstanding |
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(basic and diluted) |
| 34,668 |
| 34,668 |
| 34,668 |
| 34,668 |
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The accompanying notes are an integral part of the above unaudited consolidated financial statements. | ||||||||
6
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MGE Energy, Inc.
Consolidated Statements of Cash Flows (unaudited)
(In thousands)
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| Six Months Ended |
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| June 30, |
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| 2019 |
| 2018 |
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| Operating Activities: |
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| Net income | $ | 39,554 | $ | 38,352 |
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| Items not affecting cash: |
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| Depreciation and amortization |
| 35,230 |
| 27,495 |
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| Deferred income taxes |
| 2,306 |
| (664) |
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| Provision for doubtful receivables |
| 732 |
| 354 |
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| Employee benefit plan credit |
| (1,920) |
| (1,076) |
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| Equity earnings in ATC |
| (4,515) |
| (4,441) |
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| Other items |
| (717) |
| 160 |
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| Changes in working capital items: |
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| Decrease in current assets |
| 15,349 |
| 29,120 |
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| Decrease in current liabilities |
| (951) |
| (1,333) |
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| Dividends from ATC |
| 3,745 |
| 3,905 |
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| Cash contributions to pension and other postretirement plans |
| (2,319) |
| (2,640) |
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| Other noncurrent items, net |
| (610) |
| 2,386 |
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| Cash Provided by Operating Activities |
| 85,884 |
| 91,618 |
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| Investing Activities: |
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| Capital expenditures |
| (79,092) |
| (100,389) |
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| Capital contributions to investments |
| (3,386) |
| (3,280) |
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| Other |
| (156) |
| 598 |
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| Cash Used for Investing Activities |
| (82,634) |
| (103,071) |
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| Financing Activities: |
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| Cash dividends paid on common stock |
| (23,401) |
| (22,361) |
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| Repayments of long-term debt |
| (2,263) |
| (2,213) |
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| Proceeds from short-term debt |
| 10,500 |
| 24,200 |
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| Other |
| (1,193) |
| - |
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| Cash Used for Financing Activities |
| (16,357) |
| (374) |
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| Change in cash, cash equivalents, and restricted cash |
| (13,107) |
| (11,827) |
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| Cash, cash equivalents, and restricted cash at beginning of period |
| 84,929 |
| 112,094 |
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| Cash, cash equivalents, and restricted cash at end of period | $ | 71,822 | $ | 100,267 |
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| The accompanying notes are an integral part of the unaudited consolidated financial statements. |
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7
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MGE Energy, Inc.
Consolidated Balance Sheets (unaudited)
(In thousands)
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| June 30, | December 31, | |
ASSETS |
| 2019 |
| 2018 |
Current Assets: |
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Cash and cash equivalents | $ | 69,913 | $ | 83,102 |
Accounts receivable, less reserves of $2,800 and $2,614, respectively |
| 35,606 |
| 43,593 |
Other accounts receivable, less reserves of $478 and $540, respectively |
| 7,573 |
| 6,262 |
Unbilled revenues |
| 21,759 |
| 28,243 |
Materials and supplies, at average cost |
| 25,540 |
| 24,093 |
Fuel for electric generation, at average cost |
| 8,171 |
| 6,599 |
Stored natural gas, at average cost |
| 6,871 |
| 11,303 |
Prepaid taxes |
| 15,478 |
| 16,215 |
Regulatory assets - current |
| 11,748 |
| 9,477 |
Assets held for sale |
| - |
| 3,080 |
Other current assets |
| 8,941 |
| 8,593 |
Total Current Assets |
| 211,600 |
| 240,560 |
Other long-term receivables |
| 2,319 |
| 2,709 |
Regulatory assets |
| 147,507 |
| 145,424 |
Other deferred assets and other |
| 15,232 |
| 12,488 |
Property, Plant, and Equipment: |
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Property, plant, and equipment, net |
| 1,502,475 |
| 1,367,585 |
Finance lease assets, net |
| 16,700 |
| 2,181 |
Construction work in progress |
| 47,576 |
| 139,671 |
Total Property, Plant, and Equipment |
| 1,566,751 |
| 1,509,437 |
Investments |
| 82,677 |
| 78,000 |
Total Assets | $ | 2,026,086 | $ | 1,988,618 |
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LIABILITIES AND CAPITALIZATION |
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Current Liabilities: |
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Long-term debt due within one year | $ | 4,605 | $ | 4,553 |
Short-term debt |
| 23,500 |
| 13,000 |
Accounts payable |
| 40,957 |
| 46,158 |
Accrued interest and taxes |
| 6,661 |
| 7,384 |
Accrued payroll related items |
| 10,723 |
| 13,044 |
Regulatory liabilities - current |
| 20,762 |
| 13,826 |
Derivative liabilities |
| 10,670 |
| 8,550 |
Other current liabilities |
| 10,347 |
| 14,113 |
Total Current Liabilities |
| 128,225 |
| 120,628 |
Other Credits: |
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Deferred income taxes |
| 235,984 |
| 231,952 |
Investment tax credit - deferred |
| 772 |
| 818 |
Regulatory liabilities |
| 162,564 |
| 165,638 |
Accrued pension and other postretirement benefits |
| 65,347 |
| 67,483 |
Derivative liabilities |
| 21,900 |
| 23,980 |
Finance lease liabilities |
| 17,720 |
| 1,771 |
Other deferred liabilities and other |
| 69,560 |
| 66,361 |
Total Other Credits |
| 573,847 |
| 558,003 |
Capitalization: |
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Common shareholders' equity |
| 832,797 |
| 816,644 |
Long-term debt |
| 491,217 |
| 493,343 |
Total Capitalization |
| 1,324,014 |
| 1,309,987 |
Commitments and contingencies (see Footnote 9) |
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Total Liabilities and Capitalization | $ | 2,026,086 | $ | 1,988,618 |
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The accompanying notes are an integral part of the above unaudited consolidated financial statements. | ||||
8
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MGE Energy, Inc.
Consolidated Statements of Common Equity (unaudited)
(In thousands, except per share amounts)
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| Accumulated |
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| Additional |
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| Other |
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| Common Stock |
| Paid-in |
| Retained |
| Comprehensive |
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| Shares |
| Value |
| Capital |
| Earnings |
| Income/(Loss) |
| Total |
|
| Three Months Ended June 30, 2018 |
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| Beginning Balance | 34,668 | $ | 34,668 | $ | 316,268 | $ | 436,071 | $ | - | $ | 787,007 |
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| Net income |
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| 18,351 |
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| 18,351 |
|
| Common stock dividends declared |
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| ($0.323 per share) |
|
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|
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| (11,180) |
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| (11,180) |
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| Ending balance - June 30, 2018 | 34,668 | $ | 34,668 | $ | 316,268 | $ | 443,242 | $ | - | $ | 794,178 |
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| Three Months Ended June 30, 2019 |
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| Beginning Balance | 34,668 | $ | 34,668 | $ | 316,268 | $ | 478,014 | $ | - | $ | 828,950 |
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| Net income |
|
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| 15,548 |
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| 15,548 |
|
| Common stock dividends declared |
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| ($0.338 per share) |
|
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|
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| (11,701) |
|
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| (11,701) |
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| Ending balance - June 30, 2019 | 34,668 | $ | 34,668 | $ | 316,268 | $ | 481,861 | $ | - | $ | 832,797 |
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| Six Months Ended June 30, 2018 |
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| Beginning Balance | 34,668 | $ | 34,668 | $ | 316,268 | $ | 426,874 | $ | 377 | $ | 778,187 |
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| Cumulative effect of new accounting principle |
|
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| 377 |
| (377) |
| - |
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| Beginning balance - adjusted |
|
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| 427,251 |
| - |
| 778,187 |
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| Net income |
|
|
|
|
|
| 38,352 |
|
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| 38,352 |
|
| Common stock dividends declared |
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| ($0.645 per share) |
|
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| (22,361) |
|
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| (22,361) |
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| Ending balance - June 30, 2018 | 34,668 | $ | 34,668 | $ | 316,268 | $ | 443,242 | $ | - | $ | 794,178 |
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| Six Months Ended June 30, 2019 |
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| Beginning Balance | 34,668 | $ | 34,668 | $ | 316,268 | $ | 465,708 | $ | - | $ | 816,644 |
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| Net income |
|
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| 39,554 |
|
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| 39,554 |
|
| Common stock dividends declared |
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| ($0.675 per share) |
|
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| (23,401) |
|
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| (23,401) |
|
| Ending balance - June 30, 2019 | 34,668 | $ | 34,668 | $ | 316,268 | $ | 481,861 | $ | - | $ | 832,797 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| The accompanying notes are an integral part of the above unaudited consolidated financial statements. |
| |||||||||||
9
|
Madison Gas and Electric Company
Consolidated Statements of Income (unaudited)
(In thousands)
|
|
|
|
|
|
|
|
|
|
| Three Months Ended |
| Six Months Ended | ||||
|
| June 30, |
| June 30, | ||||
|
| 2019 |
| 2018 |
| 2019 |
| 2018 |
Operating Revenues: |
|
|
|
|
|
|
|
|
Electric revenues | $ | 97,077 | $ | 99,282 | $ | 194,546 | $ | 194,149 |
Gas revenues |
| 25,070 |
| 24,980 |
| 95,170 |
| 87,745 |
Total Operating Revenues |
| 122,147 |
| 124,262 |
| 289,716 |
| 281,894 |
|
|
|
|
|
|
|
|
|
Operating Expenses: |
|
|
|
|
|
|
|
|
Fuel for electric generation |
| 10,403 |
| 15,251 |
| 24,320 |
| 27,151 |
Purchased power |
| 11,036 |
| 12,979 |
| 21,887 |
| 30,012 |
Cost of gas sold |
| 8,875 |
| 9,562 |
| 52,128 |
| 49,188 |
Other operations and maintenance |
| 48,673 |
| 43,001 |
| 95,335 |
| 87,188 |
Depreciation and amortization |
| 18,091 |
| 13,872 |
| 35,230 |
| 27,495 |
Other general taxes |
| 4,985 |
| 4,914 |
| 9,948 |
| 9,783 |
Total Operating Expenses |
| 102,063 |
| 99,579 |
| 238,848 |
| 230,817 |
Operating Income |
| 20,084 |
| 24,683 |
| 50,868 |
| 51,077 |
|
|
|
|
|
|
|
|
|
Other income, net |
| 2,958 |
| 2,314 |
| 5,165 |
| 4,811 |
Interest expense, net |
| (6,133) |
| (5,173) |
| (12,128) |
| (10,227) |
Income before income taxes |
| 16,909 |
| 21,824 |
| 43,905 |
| 45,661 |
Income tax provision |
| (2,966) |
| (5,221) |
| (7,892) |
| (10,802) |
Net Income | $ | 13,943 | $ | 16,603 | $ | 36,013 | $ | 34,859 |
Less: Net Income Attributable to Noncontrolling |
|
|
|
|
|
|
|
|
Interest, net of tax |
| (5,621) |
| (5,505) |
| (11,111) |
| (11,311) |
Net Income Attributable to MGE | $ | 8,322 | $ | 11,098 | $ | 24,902 | $ | 23,548 |
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of the above unaudited consolidated financial statements. | ||||||||
10
|
Madison Gas and Electric Company
Consolidated Statements of Cash Flow (unaudited)
(In thousands)
|
|
|
|
|
|
|
|
|
| Six Months Ended |
| ||
|
|
| June 30, |
| ||
|
|
| 2019 |
| 2018 |
|
| Operating Activities: |
|
|
|
|
|
| Net income | $ | 36,013 | $ | 34,859 |
|
| Items not affecting cash: |
|
|
|
|
|
| Depreciation and amortization |
| 35,230 |
| 27,495 |
|
| Deferred income taxes |
| 1,231 |
| (2,574) |
|
| Provision for doubtful receivables |
| 732 |
| 354 |
|
| Employee benefit plan credit |
| (1,920) |
| (1,076) |
|
| Other items |
| (181) |
| 707 |
|
| Changes in working capital items: |
|
|
|
|
|
| Decrease in current assets |
| 15,845 |
| 28,686 |
|
| Increase in current liabilities |
| 1,096 |
| 1,943 |
|
| Cash contributions to pension and other postretirement plans |
| (2,319) |
| (2,640) |
|
| Other noncurrent items, net |
| (441) |
| 2,293 |
|
| Cash Provided by Operating Activities |
| 85,286 |
| 90,047 |
|
|
|
|
|
|
|
|
| Investing Activities: |
|
|
|
|
|
| Capital expenditures |
| (79,092) |
| (100,389) |
|
| Other |
| (271) |
| (422) |
|
| Cash Used for Investing Activities |
| (79,363) |
| (100,811) |
|
|
|
|
|
|
|
|
| Financing Activities: |
|
|
|
|
|
| Distributions to parent from noncontrolling interest |
| (11,500) |
| (13,500) |
|
| Repayments of long-term debt |
| (2,263) |
| (2,213) |
|
| Proceeds from short-term debt |
| 10,500 |
| 24,200 |
|
| Other |
| (1,038) |
| - |
|
| Cash (Used for) Provided by Financing Activities |
| (4,301) |
| 8,487 |
|
|
|
|
|
|
|
|
| Change in cash, cash equivalents, and restricted cash |
| 1,622 |
| (2,277) |
|
| Cash, cash equivalents, and restricted cash at beginning of period |
| 6,670 |
| 10,093 |
|
| Cash, cash equivalents, and restricted cash at end of period | $ | 8,292 | $ | 7,816 |
|
|
|
|
|
|
|
|
| The accompanying notes are an integral part of the unaudited consolidated financial statements. |
| ||||
|
|
|
|
|
|
|
11
|
Madison Gas and Electric Company
Consolidated Balance Sheets (unaudited)
(In thousands)
|
| June 30, | December 31, | |
ASSETS |
| 2019 |
| 2018 |
Current Assets: |
|
|
|
|
Cash and cash equivalents | $ | 6,383 | $ | 4,843 |
Accounts receivable, less reserves of $2,800 and $2,614, respectively |
| 35,606 |
| 43,593 |
Affiliate receivables |
| 542 |
| 621 |
Other accounts receivable, less reserves of $478 and $540, respectively |
| 7,511 |
| 6,111 |
Unbilled revenues |
| 21,759 |
| 28,243 |
Materials and supplies, at average cost |
| 25,540 |
| 24,093 |
Fuel for electric generation, at average cost |
| 8,171 |
| 6,599 |
Stored natural gas, at average cost |
| 6,871 |
| 11,303 |
Prepaid taxes |
| 14,586 |
| 15,790 |
Regulatory assets - current |
| 11,748 |
| 9,477 |
Assets held for sale |
| - |
| 3,080 |
Other current assets |
| 8,906 |
| 8,541 |
Total Current Assets |
| 147,623 |
| 162,294 |
Affiliate receivable long-term |
| 2,912 |
| 3,177 |
Regulatory assets |
| 147,507 |
| 145,424 |
Other deferred assets and other |
| 16,311 |
| 14,142 |
Property, Plant, and Equipment: |
|
|
|
|
Property, plant, and equipment, net |
| 1,502,504 |
| 1,367,614 |
Finance lease assets, net |
| 16,700 |
| 2,181 |
Construction work in progress |
| 47,576 |
| 139,671 |
Total Property, Plant, and Equipment |
| 1,566,780 |
| 1,509,466 |
Investments |
| 533 |
| 388 |
Total Assets | $ | 1,881,666 | $ | 1,834,891 |
|
|
|
|
|
LIABILITIES AND CAPITALIZATION |
|
|
|
|
Current Liabilities: |
|
|
|
|
Long-term debt due within one year | $ | 4,605 | $ | 4,553 |
Short-term debt |
| 23,500 |
| 13,000 |
Accounts payable |
| 40,935 |
| 46,165 |
Accrued interest and taxes |
| 9,171 |
| 10,319 |
Accrued payroll related items |
| 10,723 |
| 13,044 |
Regulatory liabilities - current |
| 20,762 |
| 13,826 |
Derivative liabilities |
| 10,670 |
| 8,550 |
Other current liabilities |
| 10,347 |
| 11,614 |
Total Current Liabilities |
| 130,713 |
| 121,071 |
Other Credits: |
|
|
|
|
Deferred income taxes |
| 207,575 |
| 204,616 |
Investment tax credit - deferred |
| 772 |
| 818 |
Regulatory liabilities |
| 162,564 |
| 165,638 |
Accrued pension and other postretirement benefits |
| 65,347 |
| 67,483 |
Derivative liabilities |
| 21,900 |
| 23,980 |
Finance lease liabilities |
| 17,720 |
| 1,771 |
Other deferred liabilities and other |
| 69,535 |
| 66,361 |
Total Other Credits |
| 545,413 |
| 530,667 |
Capitalization: |
|
|
|
|
Common shareholder's equity |
| 573,258 |
| 548,356 |
Noncontrolling interest |
| 141,065 |
| 141,454 |
Total Equity |
| 714,323 |
| 689,810 |
Long-term debt |
| 491,217 |
| 493,343 |
Total Capitalization |
| 1,205,540 |
| 1,183,153 |
Commitments and contingencies (see Footnote 9) |
|
|
|
|
Total Liabilities and Capitalization | $ | 1,881,666 | $ | 1,834,891 |
|
|
|
| |
The accompanying notes are an integral part of the above unaudited consolidated financial statements. | ||||
12
|
Madison Gas and Electric Company
Consolidated Statements of Equity (unaudited)
(In thousands)
|
|
|
|
|
|
|
| Accumulated |
|
|
| ||
|
|
|
|
| Additional |
|
|
| Other |
| Non- |
|
|
| Common Stock |
| Paid-in |
| Retained | Comprehensive | Controlling |
|
| ||||
| Shares |
| Value |
| Capital |
| Earnings | Income/(Loss) | Interest |
| Total | ||
Three Months Ended June 30, 2018 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Beginning balance | 17,348 | $ | 17,348 | $ | 192,417 | $ | 294,557 | $ | - | $ | 139,208 | $ | 643,530 |
Net income |
|
|
|
|
|
| 11,098 |
|
|
| 5,505 |
| 16,603 |
Distributions to parent from |
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest |
|
|
|
|
|
|
|
|
|
| (6,000) |
| (6,000) |
Ending balance - June 30, 2018 | 17,348 | $ | 17,348 | $ | 192,417 | $ | 305,655 | $ | - | $ | 138,713 | $ | 654,133 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2019 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Beginning balance | 17,348 | $ | 17,348 | $ | 192,417 | $ | 355,171 | $ | - | $ | 139,444 | $ | 704,380 |
Net income |
|
|
|
|
|
| 8,322 |
|
|
| 5,621 |
| 13,943 |
Distributions to parent from |
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest |
|
|
|
|
|
|
|
|
|
| (4,000) |
| (4,000) |
Ending balance - June 30, 2019 | 17,348 | $ | 17,348 | $ | 192,417 | $ | 363,493 | $ | - | $ | 141,065 | $ | 714,323 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2018 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Beginning balance | 17,348 | $ | 17,348 | $ | 192,417 | $ | 282,135 | $ | (28) | $ | 140,902 | $ | 632,774 |
Cumulative effect of new accounting principle |
|
|
|
|
|
| (28) |
| 28 |
|
|
| - |
Beginning balance - adjusted |
|
|
|
|
|
| 282,107 |
| - |
|
|
| 632,774 |
Net income |
|
|
|
|
|
| 23,548 |
|
|
| 11,311 |
| 34,859 |
Distributions to parent from |
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest |
|
|
|
|
|
|
|
|
|
| (13,500) |
| (13,500) |
Ending balance - June 30, 2018 | 17,348 | $ | 17,348 | $ | 192,417 | $ | 305,655 | $ | - | $ | 138,713 | $ | 654,133 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2019 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Beginning balance | 17,348 | $ | 17,348 | $ | 192,417 | $ | 338,591 | $ | - | $ | 141,454 | $ | 689,810 |
Net income |
|
|
|
|
|
| 24,902 |
|
|
| 11,111 |
| 36,013 |
Distributions to parent from |
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest |
|
|
|
|
|
|
|
|
|
| (11,500) |
| (11,500) |
Ending balance - June 30, 2019 | 17,348 | $ | 17,348 | $ | 192,417 | $ | 363,493 | $ | - | $ | 141,065 | $ | 714,323 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of the above unaudited consolidated financial statements. | |||||||||||||
13
|
MGE Energy, Inc., and Madison Gas and Electric Company
Notes to Consolidated Financial Statements (unaudited)
SeptemberJune 30, 20182019
Summary of Significant Accounting Policies.
a.
Basis of Presentation - MGE Energy and MGE.
This report is a combined report of MGE Energy and MGE. References in this report to "MGE Energy" are to MGE Energy, Inc. and its subsidiaries. References in this report to "MGE" are to Madison Gas and Electric Company.
MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative accounting guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 23 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 20172018 Annual Report on Form 10-K (the 20172018 Annual Report on Form 10-K).
The accompanying consolidated financial statements as of SeptemberJune 30, 2018,2019, and for the three and ninesix months ended, are unaudited but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in the 20172018 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 5462 through 103106 of the 20172018 Annual Report on Form 10-K.
b.
b.Cash, Cash Equivalents, and Restricted Cash – MGE Energy and MGE.
The following table presents the components of total cash, cash equivalents, and restricted cash on the consolidated balance sheets.
|
|
| MGE Energy |
| MGE |
| ||||
|
|
| September 30, |
| December 31, |
| September 30, |
| December 31, |
|
| (In thousands) |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Cash and cash equivalents | $ | 133,855 | $ | 107,952 | $ | 47,264 | $ | 5,951 |
|
| Restricted cash |
| 406 |
| 1,635 |
| 406 |
| 1,635 |
|
| Receivable - margin account |
| 780 |
| 2,507 |
| 780 |
| 2,507 |
|
| Cash, cash equivalents, and restricted cash | $ | 135,041 | $ | 112,094 | $ | 48,450 | $ | 10,093 |
|
Cash Equivalents
MGE Energy and MGE consider all highly liquid investments purchased with an original maturity of three months or less to be cash equivalents.
|
|
| MGE Energy |
| MGE |
| ||||
|
|
| June 30, |
| December 31, |
| June 30, |
| December 31, |
|
| (In thousands) |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Cash and cash equivalents | $ | 69,913 | $ | 83,102 | $ | 6,383 | $ | 4,843 |
|
| Restricted cash |
| 605 |
| 634 |
| 605 |
| 634 |
|
| Receivable - margin account |
| 1,304 |
| 1,193 |
| 1,304 |
| 1,193 |
|
| Cash, cash equivalents, and restricted cash | $ | 71,822 | $ | 84,929 | $ | 8,292 | $ | 6,670 |
|
Restricted Cash2.
MGE has certain cash accounts that are restricted to uses other than current operations and designated for a specific purpose. MGE's restricted cash accounts include cash held by trustees for certain employee benefits and cash deposits held by third parties. These are included in "Other current assets" on the consolidated balance sheets.
Receivable – Margin Account
Cash amounts held by counterparties as margin collateral for certain financial transactions are recorded as Receivable – margin account in "Other current assets" on the consolidated balance sheets. The costs being hedged are fuel for electric generation, purchased power, and cost of gas sold.
|
The following table presents the retrospective adjustments to cash flow amounts on MGE Energy's and MGE's consolidated statements of cash flows in accordance with the adoption ofASU 2016-18, Restricted Cash.
|
|
| Nine Months Ended |
|
| (In thousands) |
| September 30, 2017 |
|
| Cash provided by operating activities | $ | (2,870) |
|
| Cash used for investing activities |
| 525 |
|
| Change in cash, cash equivalents, and restricted cash |
| (2,345) |
|
| Cash, cash equivalents, and restricted cash at beginning of period |
| 5,674 |
|
| Cash, cash equivalents, and restricted cash at end of period | $ | 3,329 |
|
c.
Capitalized Software Assets – Hosting Arrangements – MGE Energy and MGE.
The FASB issued authoritative guidance of accounting for software in a hosted arrangement. MGE Energy and MGE adopted the authoritative guidance as of September 30, 2018. See Footnote 2.a. for further information.
As of September 30, 2018, and December 31, 2017, the net book value of capitalized costs of internal use software incurred in a hosting arrangement was $6.2 million and $0.5 million, respectively. As of September 30, 2018, accumulated amortization expense is less than $0.1 million. As of December 31, 2017, there was no accumulated amortization expense. Capitalized software assets for hosted arrangements and the related accumulated amortization expense are recorded in "Other deferred assets and other" on the consolidated balance sheets of MGE Energy and MGE.
For the three and nine months ended September 30, 2018, MGE recorded less than $0.1 million of amortization expense related to software assets for hosted arrangements. For the three and nine months ended September 30, 2017, no amortization expense was recorded. These costs are recognized in "Other operations and maintenance" expense in the consolidated statements of income of MGE Energy and MGE and are amortized on a straight-line basis over the estimated useful lives of the assets. Software assets for hosted arrangements have useful lives ranging from five to fifteen years.
New Accounting Standards - MGE Energy and MGE.
a.
Recently Adopted
Revenue from Contracts with Customers.Leases.
The FASB issued authoritative guidance within the codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. The new standard establishes a five-step model for recognizing and measuring revenue from contracts with customers and replaces existing guidance on revenue recognition. The underlying principle is that an entity will recognize revenue to present the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services.
This authoritative guidance became effective January 1, 2018, and MGE Energy and MGE adopted the standard upon the effective date. Adoption of this standard is permitted under one of two methods: the full retrospective method or the modified retrospective method. MGE Energy and MGE implemented the standard using the modified retrospective method. The cumulative impact of this guidance on our financial statements is not material, except for additional footnote disclosures. See Footnote 3 for further information.
Financial Instruments.
In January 2016, the FASB issued authoritative guidance within the codification's Financial Instruments topic that provides guidance on the recognition and measurement of financial instruments. This authoritative guidance became effective January 1, 2018, and required equity investments to be measured at fair value with changes in fair value recognized in net income rather than in other comprehensive income. As a result of this guidance, MGE Energy and MGE will no longer have other comprehensive
|
income related to equity investments. This standard was applied using a modified retrospective approach, with a cumulative effect adjustment recorded to opening retained earnings as of the beginning of the fiscal year of adoption. As of January 1, 2018, MGE Energy recorded a $0.4 million increase in retained earnings and a corresponding decrease in accumulated other comprehensive income related to equity investments within the scope of this standard. As of January 1, 2018, MGE recorded less than a $0.1 million decrease in retained earnings and a corresponding increase in accumulated other comprehensive income related to equity investments within the scope of this standard.
Restricted Cash.
In November 2016, the FASB issued authoritative guidance within the codification's Statement of Cash Flows topic that provides guidance on the classification and presentation of changes in restricted cash within the statement of cash flows. Under the new guidance, reporting entities are required to explain the changes in the total of restricted and unrestricted cash and cash equivalents when reconciling the beginning and ending balances on the statement of cash flows. Prior to the authoritative guidance, changes in restricted cash were presented as either cash flows from operating, investing, or financing activities within the statement of cash flows based on the nature of the restriction. Reporting entities are now also required to provide a reconciliation from the balance sheet to the statement of cash flows and disclose the nature of the restrictions of cash. This authoritative guidance became effective January 1, 2018. Upon the effective date, MGE Energy and MGE changed the presentation of restricted cash on the consolidated statements of cash flows to reflect the new accounting guidance retrospectively for all periods presented. See Footnote 1.b. for further information.
Pension and Other Postretirement Benefits.
In March 2017, the FASB issued authoritative guidance within the codification's Compensation – Retirement Benefits topic that provides guidance on the presentation of net periodic pension cost and net periodic postretirement benefit cost (together, net benefit cost). This authoritative guidance became effective January 1, 2018. Under the new guidance, the service cost component of net benefit cost is required to be recorded in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside of income from operations. A practical expedient within the standard permits an employer to use the amounts disclosed in its pension and other postretirement benefit plan footnote for prior comparative periods as the estimation basis for applying the retrospective presentation requirements. MGE Energy and MGE have elected to apply the practical expedient. Upon the effective date, MGE Energy and MGE changed the presentation of net benefit cost on the consolidated statements of income to reflect the new accounting guidance retrospectively to all periods presented. For both MGE Energy and MGE, "Other operations and maintenance expense" increased and "Other income, net" increased $1.0 million and $3.0 million for the three and nine months ended September 30, 2017, respectively. The standard also only allows the service cost component to be eligible for capitalization prospectively from the effective date of the pronouncement (whereas under previous GAAP all components of net benefit cost were eligible for capitalization). See Footnote 6 for further information.
Internal-Use Software – Hosting Arrangements.
In August 2018, the FASB issued amended authoritative guidance within the codification's Intangibles – Goodwill and Other – Internal-Use Software topic. The amended authoritative guidance aligns the requirements for capitalizing implementation costs incurred in a cloud computing arrangement (hosting arrangement) that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangement that include an internal-use software license). Costs for implementation activities in the development stage are capitalized depending on the nature of the costs and presented in the same line item on the balance sheet as amounts prepaid for the hosted service. Costs incurred during the preliminary and postimplementation stages are expensed as the activities are performed. The costs capitalized as part of implementation stage should be expensed over the term of the hosting contract, which includes any renewable option periods, and presented in the same line on the income statement as the fees for the associated hosted service.
This amended authoritative guidance will become effective January 1, 2020. Early adoption of the amendment is permitted, including adoption in any interim period. Entities can choose to adopt the new guidance either prospectively, for eligible costs incurred on or after the date this guidance is first applied,
|
or retrospectively. MGE Energy and MGE early adopted these amendments retrospectively as of September 30, 2018. The cumulative impact of this guidance on our financial statement was not material, except for additional footnote disclosures. See Footnote 1.c. for further information.
b.
Recently Issued
Leases.
In February 2016, the FASB issued authoritative guidance within the codification's Leases topic that provides guidance on the classification, recognition, measurement, and disclosure of leases. The new leasing standard establishes that a lease conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Under the new guidance, lessees will beare required to recognize all leases with terms greater than one year, including operating leases, on the balance sheet by recording a right-of-use asset and lease liability. Prior to the authoritative guidance, only capital leases were recognized on the balance sheet by lessees. The new accounting guidance, as applied by lessors, is materially consistent with current GAAP. In January 2018, the FASB issued authoritative guidance which
14
provided an optional practical expedient to grandfather the accounting for existing and expired land easements not accounted for as a lease under the new authoritative guidance. MGE Energy and MGE plan to adoptadopted this practical expedient.
Management has begun utilizing a bottoms-up approach to analyze the impact of the standard on ourThe lease portfolio.authoritative guidance became effective January 1, 2019. MGE Energy and MGE have been reviewing current accounting policies and procedures to identify potential differences in accounting treatment that would result from applying the requirements of the new standard to our existing lease portfolio. In addition, we are identifying appropriate changes to our business processes, systems, and controls to support recognition and disclosure requirements under the new standard. This authoritative guidance will become effective January 1, 2019, with early adoption permitted. MGE Energy and MGE anticipate adoptingadopted the standard upon the effective date. The new leasing standard requires entities to recognize and measure leases at the beginning of the earliest comparative period presented using a modified retrospective approach.In compliance with authorized transition guidance, MGE Energy and MGE expectbegan applying the new standard on January 1, 2019, but will continue to recognize additional lease assets and liabilities for their operating leases underpresent periods prior to that date according to the previous authoritative standard. MGE Energy and MGE are continuing to evaluate the impact of this pronouncement; however, we do not expect that it will have aThere was no material impact on ourthe consolidated net income or cash flows. See Footnote 3 for further lease information.
3.
Leases - MGE Energy and MGE.
As part of its regular operations, MGE enters into various contracts related to IT equipment, substations, cell towers, land, wind easements, and other property in use for operations. A contract is or contains a lease if the contract conveys the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. Determination as to whether an arrangement is or contains a lease is completed at inception. Leases with an initial term of 12 months or less are not recorded on the consolidated balance sheets; lease expense for these leases are recognized on a straight-line basis over the lease term. Leases with initial terms in excess of 12 months are recorded as operating or financing leases on the consolidated balance sheets.
Operating lease assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. For leases that do not provide an implicit rate, a collateralized incremental borrowing rate based on the information available at commencement date, including lease term, is used in determining the present value of future payments. The operating lease asset also includes any lease payments made and excludes lease incentives and initial direct costs incurred. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the option will be exercised. Operating lease expense is recognized on a straight-line basis over the lease term. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net lease costs are recorded and when costs are recognized. As of June 30, 2019, MGE has no significant leases not yet commenced that would create significant future rights and obligations.
The following table shows lease expense for the three and six months ended June 30, 2019:
| (In thousands) |
| Three Months Ended |
| Six Months Ended |
| Income Statement Location |
|
| Finance lease expense: |
|
|
|
|
|
|
|
| Amortization of leased assets | $ | 437 | $ | 870 |
| Depreciation and amortization |
|
| Interest on lease liabilities |
| 200 |
| 398 |
| Interest expense, net |
|
| Operating lease expense |
| 33 |
| 60 |
| Other operations and maintenance |
|
| Total lease expense | $ | 670 | $ | 1,328 |
|
|
|
The following table shows the lease assets and liabilities on the consolidated balance sheet as of June 30, 2019:
15
| (In thousands) |
|
|
| Balance Sheet Location |
|
| Lease assets: |
|
|
|
|
|
| Finance lease assets | $ | 16,700 |
| Finance lease assets |
|
| Operating lease assets |
| 216 |
| Other deferred assets and other |
|
| Total lease assets | $ | 16,916 |
|
|
|
| Lease liabilities: |
|
|
|
|
|
| Finance lease liabilities - current | $ | 1,007 |
| Other current liabilities |
|
| Finance lease liabilities - long-term |
| 17,720 |
| Finance lease liabilities |
|
| Operating lease liabilities - current |
| 104 |
| Other current liabilities |
|
| Operating lease liabilities - long-term |
| 144 |
| Other deferred liabilities and other |
|
| Total lease liabilities | $ | 18,975 |
|
|
|
The following table shows other financial lease information for the six months ended June 30, 2019:
| (In thousands) |
|
|
|
| Cash paid for amounts included in the measurement of lease liabilities: |
|
|
|
| Finance leases - Financing cash flows | $ | 643 |
|
| Finance leases - Operating cash flows |
| 398 |
|
| Operating leases - Operating cash flows |
| 71 |
|
| Lease assets obtained in exchange for lease liabilities: |
|
|
|
| Finance leases |
| 12,081 |
|
| Operating leases |
| 125 |
|
The following table shows the weighted average remaining lease terms and discounts as of June 30, 2019:
Weighted-average remaining lease terms (in years): | |||||
Finance leases | 38 | ||||
Operating leases | 6 | ||||
Weighted-average discount rates: | |||||
Finance leases | 4.36 | % | |||
Operating leases | 3.97 | % |
The following table shows maturities of lease liabilities as of June 30, 2019:
| (In thousands) |
| Finance |
| Operating |
|
| 2019 | $ | 876 | $ | 54 |
|
| 2020 |
| 1,644 |
| 113 |
|
| 2021 |
| 1,428 |
| 46 |
|
| 2022 |
| 1,309 |
| 13 |
|
| 2023 |
| 1,228 |
| 2 |
|
| Thereafter |
| 41,316 |
| 52 |
|
| Subtotal |
| 47,801 |
| 280 |
|
| Less: Present value discount |
| (29,074) |
| (32) |
|
| Lease Liability | $ | 18,727 | $ | 248 |
|
Future minimum rental payments as of December 31, 2018, under agreements classified as operating leases with noncancelable terms in excess of one year are as follows:
| (In thousands) |
| 2019 |
| 2020 |
| 2021 |
| 2022 |
| 2023 |
| Thereafter |
|
| Minimum lease payments | $ | 1,646 | $ | 1,371 | $ | 1,095 | $ | 989 | $ | 975 | $ | 22,707 |
|
4.
Investment in ATC and ATC Holdco - MGE Energy and MGE.
ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which, since December 1, 2016,
16
is owned by MGE Energy. ATC Holdco was formed by several members of ATC, including MGE Energy, to pursue electric transmission development and investments outside of Wisconsin. The ownership interest in ATC Holdco is held by MGEE Transco, a wholly-owned subsidiary of MGE Energy.
MGE Transco and MGEE Transco have accounted for their investments in ATC and ATC Holdco, respectively, under the equity method of accounting. Equity earnings from investments are recorded as "Other income" on the consolidated statements of income of MGE Energy. MGE Transco recorded the following:
|
|
| Three Months Ended |
| Six Months Ended |
| ||||
|
|
| June 30, |
| June 30, |
| ||||
| (In thousands) |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Equity earnings from investment in ATC | $ | 2,297 | $ | 1,990 | $ | 4,515 | $ | 4,441 |
|
| Dividends from ATC(a) |
| 1,733 |
| 2,959 |
| 3,745 |
| 2,959 |
|
| Capital contributions to ATC |
| 1,065 |
| 1,065 |
| 1,243 |
| 1,775 |
|
(a)MGE Transco recorded a $2.3 million dividend receivable from ATC as of December 31, 2017. A cash dividend was received in January of the proceeding year. MGE Transco recorded a $1.4 million dividend receivable from ATC as of June 30, 2018. A cash dividend was received in July 2018.
ATC Holdco was formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational.
In July 2019, MGE Transco made a $0.9 million capital contribution to ATC.
ATC's summarized financial data is as follows:
|
|
| Three Months Ended |
| Six Months Ended |
| ||||
|
|
| June 30, |
| June 30, |
| ||||
| (In thousands) |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Operating revenues | $ | 182,212 | $ | 165,506 | $ | 359,927 | $ | 330,935 |
|
| Operating expenses |
| (93,573) |
| (91,474) |
| (183,960) |
| (176,367) |
|
| Other income, net |
| 287 |
| 1,520 |
| 547 |
| 1,631 |
|
| Interest expense, net |
| (28,838) |
| (26,895) |
| (57,956) |
| (54,657) |
|
| Earnings before members' income taxes | $ | 60,088 | $ | 48,657 | $ | 118,558 | $ | 101,542 |
|
MGE receives transmission and other related services from ATC. During the three and six months ended June 30, 2019, MGE recorded $7.6 million and $15.2 million, respectively, for transmission services received compared to $7.2 million and $14.4 million for the comparable periods in 2018. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of June 30, 2019, and December 31, 2018, MGE had a receivable due from ATC of $0.6 million and $0.1 million, respectively.
5.
Taxes - MGE Energy and MGE.
Effective Tax Rate.
The consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:
17
|
| MGE Energy |
| MGE |
| ||||
| Three Months Ended June 30, | 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Statutory federal income tax rate | 21.0% |
| 21.0% |
| 21.0% |
| 21.0% |
|
| State income taxes, net of federal benefit | 6.3% |
| 6.3% |
| 6.2% |
| 6.2% |
|
| Amortized investment tax credits | (0.1%) |
| (0.1%) |
| (0.1%) |
| (0.1%) |
|
| Credit for electricity from wind energy(a) | (6.2%) |
| (0.4%) |
| (6.8%) |
| (0.4%) |
|
| AFUDC equity, net | (0.2%) |
| (1.1%) |
| (0.2%) |
| (1.1%) |
|
| Amortization of utility excess deferred tax - tax reform(b) | (2.4%) |
| (1.9%) |
| (2.6%) |
| (1.9%) |
|
| Other, net, individually insignificant | -% |
| 0.3% |
| 0.1% |
| 0.2% |
|
| Effective income tax rate | 18.4% |
| 24.1% |
| 17.6% |
| 23.9% |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE Energy |
| MGE |
| ||||
| Six Months Ended June 30, | 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Statutory federal income tax rate | 21.0% |
| 21.0% |
| 21.0% |
| 21.0% |
|
| State income taxes, net of federal benefit | 6.3% |
| 6.3% |
| 6.2% |
| 6.2% |
|
| Amortized investment tax credits | (0.1%) |
| (0.1%) |
| (0.1%) |
| (0.1%) |
|
| Credit for electricity from wind energy(a) | (6.1%) |
| (0.3%) |
| (6.7%) |
| (0.3%) |
|
| AFUDC equity, net | (0.2%) |
| (0.9%) |
| (0.2%) |
| (1.0%) |
|
| Amortization of utility excess deferred tax - tax reform(b) | (2.4%) |
| (1.9%) |
| (2.6%) |
| (2.1%) |
|
| Other, net, individually insignificant | 0.4% |
| -% |
| 0.4% |
| -% |
|
| Effective income tax rate | 18.9% |
| 24.1% |
| 18.0% |
| 23.7% |
|
(a)Saratoga Wind Farm became operational in February 2019.
(b)Included are impacts of the Tax Cuts and Jobs Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting. For the three and six months ended June 30, 2019, MGE recognized $0.5 million and $1.1 million, respectively, compared to $0.4 million and $0.9 million for the comparable periods in 2018. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, determined by the PSCW.
6.
Pension and Other Postretirement Plans - MGE Energy and MGE.
MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.
The components of net periodic benefit cost, other than the service cost component, are recorded in "Other income, net" on the consolidated statements of income. The service cost component is recorded in "Other operations and maintenance" on the consolidated statements of income. The service cost component of net periodic benefit cost is eligible for capitalization within the consolidated balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net periodic benefit costs are recovered and when costs are recognized.
The following table presents the components of net periodic benefit costs recognized.
18
|
|
| Three Months Ended |
| Six Months Ended |
| ||||
|
|
| June 30, |
| June 30, |
| ||||
| (In thousands) |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Pension Benefits |
|
|
|
|
|
|
|
|
|
| Components of net periodic benefit cost: |
|
|
|
|
|
|
|
|
|
| Service cost | $ | 1,221 | $ | 1,404 | $ | 2,362 | $ | 2,861 |
|
| Interest cost |
| 3,742 |
| 3,222 |
| 7,194 |
| 6,430 |
|
| Expected return on assets |
| (5,922) |
| (6,552) |
| (11,469) |
| (13,120) |
|
| Amortization of: |
|
|
|
|
|
|
|
|
|
| Prior service credit |
| (31) |
| (11) |
| (59) |
| (22) |
|
| Actuarial loss |
| 1,985 |
| 1,341 |
| 3,714 |
| 2,639 |
|
| Net periodic benefit (credit) cost | $ | 995 | $ | (596) | $ | 1,742 | $ | (1,212) |
|
|
|
|
|
|
|
|
|
|
|
|
| Postretirement Benefits |
|
|
|
|
|
|
|
|
|
| Components of net periodic benefit cost: |
|
|
|
|
|
|
|
|
|
| Service cost | $ | 334 | $ | 310 | $ | 553 | $ | 642 |
|
| Interest cost |
| 865 |
| 648 |
| 1,442 |
| 1,306 |
|
| Expected return on assets |
| (676) |
| (814) |
| (1,357) |
| (1,616) |
|
| Amortization of: |
|
|
|
|
|
|
|
|
|
| Transition obligation |
| 1 |
| - |
| 2 |
| 1 |
|
| Prior service credit |
| (662) |
| (667) |
| (1,330) |
| (1,334) |
|
| Actuarial loss |
| 94 |
| 116 |
| 200 |
| 244 |
|
| Net periodic benefit (credit) cost | $ | (44) | $ | (407) | $ | (490) | $ | (757) |
|
As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In July 2019, the PSCW approved MGE’s request to defer the difference between estimated pension and other postretirement costs included in the 2019 and 2020 rate settlement and actual expense incurred up to $5.9 million. MGE expects that the deferred cost for employee benefit plans will be factored into future rate actions starting in 2021. For the three and six months ended June 30, 2019, MGE has deferred approximately $3million of pension and other postretirement costs. This amount is not reflected in the table above.
7.
Equity and Financing Arrangements - MGE Energy.
a.Common Stock.
MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the three and six months ended June 30, 2019 and 2018, MGE Energy didnotissueany new shares of common stock under the Stock Plan.
b.Dilutive Shares Calculation.
MGE Energy does not have any stock option or stock award programs or any dilutive securities.
8.
Share-Based Compensation - MGE Energy and MGE.
Under MGE Energy's Director Incentive Plan and its Performance Unit Plan, non-employee directors and eligible employees, respectively, may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the performance period set in the award.
In 2019, 5,175 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule, and 17,022 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of June 30, 2019, as
required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.
For nonretirement eligible employees under the Performance Unit Plan, stock-based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon as retirement eligibility accelerates vesting.
During the three and six months ended June 30, 2019, MGE recorded $0.7 million and $1.9 million, respectively, in compensation expense as a result of awards under the plans compared to $0.8 million and $1.0 million for the comparable periods in 2018. In January 2019, cash payments of $1.5 million were distributed relating to awards that were granted in a prior year under the plans. Noforfeitures of unitsoccurredduring the three and six months ended June 30, 2019 and 2018. As of June 30, 2019, $5.7 million of outstanding awards are vested. Of this amount, no cash settlements have occurred as cash payments are only made at the end of the period covered by the awards.
9.
Commitments and Contingencies.
a.Environmental - MGE Energy and MGE.
MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules have the potential to have a material effect on capital expenditures and operating costs. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects. These initiatives, proposed rules, and court challenges include:
•The EPA's published water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants, such as the coal-burning plants at Columbia and the Elm Road Units. The operators of the Columbia and the Elm Road Units have indicated that equipment upgrades may be necessary to comply with the new discharge standards. Management believes that any compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects.
•The EPA's cooling water intake rules, which require cooling water intake structures at electric power plants, such as our Blount and Columbia plants, to meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced. MGE expects that the rule will not have a material effect on its existing plants.
•Greenhouse Gas (GHG) reduction guidelines and approval criteria established under the Clean Air Act (CAA) for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs).
In 2015, the EPA finalized the Clean Power Plan (CPP), which directed states to submit plans to reduce GHG emissions from the electric generation sector. The CPP applies the statutory requirements for the "best system of emission reduction" (BSER) broadly so as to encompass GHG emission reduction strategies that extend "beyond the fenceline" of existing EGUs and requires a shift in the energy generation mix at the grid level. In February 2016, the U.S. Supreme Court stayed implementation of the CPP while the United States Court of Appeals for the D.C. Circuit reviews the rule. The D.C. Circuit agreed to hold its review of the CPP in abeyance while the EPA reconsidered the CPP. The stay and abeyance
19
order remain in effect. If ultimately upheld, the CPP could have a material effect on MGE’s operations.
In July 2019, the EPA published a final rule repealing the CPP and creating the replacement Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing EGUs. The ACE rule applies to EGUs greater than 25 MW. Based upon these criteria, the ACE rule will likely apply to Columbia and the Elm Road Units. EGUs that burn fossil fuels other than coal, such as Blount, WCCF, and smaller natural gas- and diesel-fueled units are not subject to the ACE rule.
In contrast to the CPP, the ACE rule limits BSER to only "inside the fenceline" heat rate improvement technologies or systems that can be applied at an affected coal fired EGU. Under ACE, states have the primary role in developing standards of performance that result from the application of BSER. The EPA has not provided a standard of performance that it will deem presumptively acceptable in a state plan, but urges states to provide full justification for each component of their plans so that the EPA can evaluate BSER on a unit-by-unit basis.
States will have three years to develop and submit compliance plans to the EPA. The EPA will have a year to review and approve the plans. The states are given 24 months from the approval date to implement the rule and can extend the compliance schedule for units that meet progress milestones. EGU’s compliance with the ACE rule may not be required until 2024 or later. MGE is currently evaluating how this rule may impact operations. Until the State of Wisconsin develops a plan that is accepted by the EPA, MGE will not be able to determine the final impact of the rule. MGE will continue to evaluate the rule and monitor ongoing and potential legal proceedings associated with the CPP and ACE rules.
•The EPA's rule to regulate ambient levels of ozone through the 2015 Ozone National Ambient Air Quality Standards (NAAQS). In May 2018, the EPA issued a final rule which designated the northeast portion of Milwaukee County as being in nonattainment with this NAAQS. The Elm Road Units are located in Milwaukee County, outside the designated nonattainment area. In August 2018, several environmental groups, the City of Chicago, and the State of Illinois filed federal lawsuits challenging several of the EPA's attainment designation decisions, including the partial Milwaukee County designation as being too narrow and not sufficiently protective. MGE is monitoring the outcome of this lawsuit and how it may affect our Elm Road Units in Milwaukee County. At this time, MGE expects that the 2015 Ozone NAAQS will not have a material effect on its existing plants based on final designations.
•Rules regulating nitrogen oxide (NOx) and sulfur dioxide (SO2) emissions, including the Cross State Air Pollution Rule (CSAPR) and Clean Air Visibility Rule (CAVR).
MGE has met our CSAPR obligations in 2018 and 2017 through a combination of reduced emissions through pollution control (e.g. SCR installation at Columbia), as well as owned, received, and purchased allowances. There remains uncertainty around CSAPR due to legal challenges, however, MGE expects that we will meet ongoing CSAPR obligations for the foreseeable future. MGE will continue to monitor developments and litigation to this rule.
Columbia is subject to the best available retrofit technology (BART) regulations, a subsection of the EPA's CAVR, which may require pollution control retrofits. Columbia's existing pollution control upgrades, and the EPA's stance that compliance with the CSAPR equals compliance with BART, should mean that Columbia will not need to do additional work to meet BART requirements. At this time, however, the BART regulatory obligations, compliance strategies, and costs remain uncertain in Wisconsin due to the continued legal challenges surrounding CSAPR and CAVR. MGE will continue to monitor developments to this rule.
20
•The EPA's Coal Combustion Residuals Rule (CCR), which regulates coal ash from burning coal for the purpose of generating electricity as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation.
Review of the Elm Road Units has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has completed a review of their system and has determined that an onsite ash pond will need to be closed and replaced with a dry ash handling system. The dry ash handling system installation is planned for 2020-2021.
In July 2018, the EPA published a final rule that included amendments to the CCR (which include the allowance of alternative performance standards for landfills and surface impoundments, revised risk-based groundwater protection standards, and an extension of the deadline by which certain facilities must cease the placement of waste in CCR units). In August 2018, the Court of Appeals for the D.C. Circuit vacated parts of the CCR for not being sufficiently protective of the environment. It is unclear how the EPA will respond to that decision. MGE will continue to monitor potential rule modifications to assess potential impacts on operations.
b.Legal Matters - MGE Energy and MGE.
MGE is involved in various legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements. MGE does not expect the resolution of these matters to have a material adverse effect on its consolidated results of operations, financial condition, or cash flows.
c.Purchase Contracts - MGE Energy and MGE.
MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. The following table shows future commitments related to purchase contracts as of June 30, 2019:
| (In thousands) |
| 2019 |
| 2020 |
| 2021 |
| 2022 |
| 2023 |
| Thereafter |
|
| Natural gas |
|
|
|
|
|
|
|
|
|
|
|
|
|
| Transportation and storage(a) |
| 10,102 |
| 21,700 |
| 21,432 |
| 21,432 |
| 21,432 |
| 54,663 |
|
| Supply(b) |
| 8,822 |
| 10,280 |
| - |
| - |
| - |
| - |
|
| Solar farms(c) |
| 74 |
| 147 |
| 2,572 |
| 156 |
| 160 |
| 10,474 |
|
| Other |
| 92 |
| 928 |
| 929 |
| 97 |
| 99 |
| 1,079 |
|
|
| $ | 19,090 | $ | 33,055 | $ | 24,933 | $ | 21,685 | $ | 21,691 | $ | 66,216 |
|
(a) MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.
(b)These commitments include market-based pricing.
(c) In July 2019 MGE entered into additional commitments related to operations of the Badger Hollow Solar Farm. The total of these commitments by year are as follows: $0.5 million in 2019, $0.2 million in 2020, $0.5 million in 2021, $0.6 million in 2022, $0.6 million in 2023, and $22.0 million thereafter.
d.Capital Purchase Commitments - MGE Energy and MGE.
Various contractual obligations contain minimum future commitments related to capital expenditures for certain construction projects, including the Two Creeks solar project and the Badger Hollow Solar Farm. As of June 30, 2019, the Two Creeks future minimum construction commitment is $52.8 million. In July 2019 MGE entered into an additional future minimum construction commitment of $59.9 million
related to Badger Hollow. See Footnote 14 for more information.
10.
Rate Matters - MGE Energy and MGE.
a.Rate Proceedings.
In December 2018, the PSCW approved the settlement agreement between MGE and intervening parties in the rate case. The settlement decreases electric rates by 2.24%, or $9.2 million, in 2019. MGE will maintain this rate level for 2020, with the exception that MGE will file a 2020 Fuel Cost Plan in 2019 and MGE's electric rates will be adjusted accordingly. The decrease reflects the ongoing tax impacts of the Tax Act. Lower fuel costs and increase in rate base from renewable generation assets are additional items impacting the rate change. The settlement agreement increases gas rates by 1.06%, or $1.7million, in 2019 and 1.46%, or $2.4million, in 2020. The gas increase covers infrastructure costs. It also reflects the impacts of the Tax Act. The return on common stock equity for 2019 and 2020 is 9.8% based on a capital structure consisting of
56.6% common equity in 2019
and 56.1% common equity in 2020.
MGE did not file a base rate case for 2018.
b.Fuel Rules.
Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over/under recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order. These costs will be subject to the PSCW's annual review of fuel costs completed in the year following the deferral.
In December 2017, the PSCW approved a surcharge for 2018 electric fuel-related costs. The surcharge increased electric retail revenue in 2018 by $0.5 million, or 0.13%.
In July 2019, the PSCW issued a final decision in the 2018 fuel rules proceedings for MGE to refund additional fuel savings incurred to its retail electric customers over a one-month period. MGE will return $9.5 million plus accrued interest in October 2019. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred in the previous year.
As of June 30, 2019, MGE had no 2019 fuel savings deferred. As of December 31, 2018, MGE had deferred $9.5 million of 2018 fuel savings.
11.
Derivative and Hedging Instruments - MGE Energy and MGE.
a.Purpose.
As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, the derivatives are recognized in the consolidated balance sheets at fair value. MGE's financial commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a
21
net loss or net gain position, respectively. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.
b.Notional Amounts.
The gross notional volume of open derivatives is as follows:
June 30, 2019 | December 31, 2018 | ||||
Commodity derivative contracts | 507,720 MWh | 386,440 MWh | |||
Commodity derivative contracts | 7,140,000 Dth | 5,260,000 Dth | |||
FTRs | 5,853 MW | 2,252 MW | |||
PPA | 1,750 MW | 2,050 MW |
c.Financial Statement Presentation.
MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market,MGE holdsfinancial transmission rights (FTRs). An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. As of June 30, 2019, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $0.9 million. As of December 31, 2018, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by and $0.7 million.
MGE is a party to a purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of June 30, 2019, and December 31, 2018, reflects a loss position of $32.6 million and $32.5 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.
The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. As of June 30, 2019, and December 31, 2018, the receivable margin account balance of $1.3 million and $1.2 million, respectively, is shown net of any collateral posted against derivative positions.
22
|
|
| Derivative |
| Derivative |
|
|
|
| (In thousands) |
| Assets |
| Liabilities |
| Balance Sheet Location |
|
| June 30, 2019 |
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 578 | $ | 1,322 |
| Other current assets(a) |
|
| Commodity derivative contracts |
| 81 |
| 713 |
| Other deferred charges(a) |
|
| FTRs |
| 430 |
| - |
| Other current assets |
|
| PPA |
| N/A |
| 10,670 |
| Derivative liability (current) |
|
| PPA |
| N/A |
| 21,900 |
| Derivative liability (long-term) |
|
|
|
|
|
|
|
|
|
|
| December 31, 2018 |
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 727 | $ | 270 |
| Other current assets |
|
| Commodity derivative contracts |
| 74 |
| 72 |
| Other deferred charges |
|
| FTRs |
| 241 |
| - |
| Other current assets |
|
| PPA |
| N/A |
| 8,550 |
| Derivative liability (current) |
|
| PPA |
| N/A |
| 23,980 |
| Derivative liability (long-term) |
|
(a)As of June 30, 2019, collateral of $0 million was posted against and netted with derivative liability positions on the consolidated balance sheets. No collateral was posted against derivative positions as of December 31, 2018.
The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the consolidated balance sheets.
| Offsetting of Derivative Assets |
| ||||||||
| (In thousands) |
| Gross Amounts |
| Gross Amounts Offset in Balance Sheets |
| Collateral Posted Against Derivative Positions |
| Net Amount Presented in Balance Sheets |
|
| June 30, 2019 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 659 | $ | (343) | $ | - | $ | 316 |
|
| FTRs |
| 430 |
| - |
| - |
| 430 |
|
|
|
|
|
|
|
|
|
|
|
|
| December 31, 2018 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 801 | $ | (342) | $ | - | $ | 459 |
|
| FTRs |
| 241 |
| - |
| - |
| 241 |
|
| Offsetting of Derivative Liabilities |
| ||||||||
| (In thousands) |
| Gross Amounts |
| Gross Amounts Offset in Balance Sheets |
| Collateral Posted Against Derivative Positions |
| Net Amount Presented in Balance Sheets |
|
| June 30, 2019 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 2,035 | $ | (343) | $ | (1,692) | $ | - |
|
| PPA |
| 32,570 |
| - |
| - |
| 32,570 |
|
|
|
|
|
|
|
|
|
|
|
|
| December 31, 2018 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 342 | $ | (342) | $ | - | $ | - |
|
| PPA |
| 32,530 |
| - |
| - |
| 32,530 |
|
The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheets and the consolidated statements of income.
23
|
| 2019 |
|
| 2018 | ||||
(In thousands) |
| Current and Long-Term Regulatory Asset |
| Other Current Assets |
|
| Current and Long-Term Regulatory Asset |
| Other Current Assets |
Three Months Ended June 30: |
|
|
|
|
|
|
|
|
|
Balance at April 1, | $ | 31,023 | $ | 259 |
| $ | 41,241 | $ | 319 |
Unrealized gain |
| 3,228 |
| - |
|
| (4,027) |
| - |
Realized (loss) gain reclassified to a deferred account |
| (731) |
| 731 |
|
| (363) |
| 363 |
Realized (loss) gain reclassified to income statement |
| (4) |
| (112) |
|
| 73 |
| (42) |
Balance as of June 30, | $ | 33,516 | $ | 878 |
| $ | 36,924 | $ | 640 |
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30: |
|
|
|
|
|
|
|
|
|
Balance at January 1, | $ | 31,830 | $ | 377 |
| $ | 41,958 | $ | 806 |
Unrealized gain |
| 2,306 |
| - |
|
| (3,899) |
| - |
Realized (loss) gain reclassified to a deferred account |
| (991) |
| 991 |
|
| (521) |
| 521 |
Realized (loss) gain reclassified to income statement |
| 371 |
| (490) |
|
| (614) |
| (687) |
Balance as of June 30, | $ | 33,516 | $ | 878 |
| $ | 36,924 | $ | 640 |
|
| Realized Losses (Gains) | |||||||
|
| 2019 |
|
| 2018 | ||||
(In thousands) |
| Fuel for Electric Generation/ Purchased Power |
| Cost of Gas Sold |
|
| Fuel for Electric Generation/ Purchased Power |
| Cost of Gas Sold |
Three Months Ended June 30: |
|
|
|
|
|
|
|
|
|
Commodity derivative contracts | $ | 299 | $ | 99 |
| $ | (190) | $ | 22 |
FTRs |
| 61 |
| - |
|
| (300) |
| - |
PPA |
| (343) |
| - |
|
| 437 |
| - |
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30: |
|
|
|
|
|
|
|
|
|
Commodity derivative contracts | $ | 568 | $ | 377 |
| $ | 184 | $ | 637 |
FTRs |
| (74) |
| - |
|
| (475) |
| - |
PPA |
| (752) |
| - |
|
| 955 |
| - |
MGE's commodity derivative contracts, FTRs, and PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheets and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.
The PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of June 30, 2019, no collateral is required to be, or has been, posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. Nocounterparties were in a net liability position as of June 30, 2019 and December 31, 2018.
Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of June 30, 2019, no counterparties have defaulted.
12.
Fair Value of Financial Instruments - MGE Energy and MGE.
Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The accounting standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or
liability including assumptions about risk. The standard also establishes a three-level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:
Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.
Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.
Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.
a.Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount.
The carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of long-term debt is based on quoted market prices for similar financial instruments. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of financial instruments are as follows:
|
|
| June 30, 2019 |
| December 31, 2018 |
| ||||
| (In thousands) |
| Carrying Amount |
| Fair Value |
| Carrying Amount |
| Fair Value |
|
| MGE Energy |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Cash and cash equivalents | $ | 69,913 | $ | 69,913 | $ | 83,102 | $ | 83,102 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Short-term debt - commercial paper |
| 23,500 |
| 23,500 |
| 13,000 |
| 13,000 |
|
| Long-term debt(a) |
| 500,168 |
| 562,969 |
| 502,431 |
| 518,811 |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Cash and cash equivalents | $ | 6,383 | $ | 6,383 | $ | 4,843 | $ | 4,843 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Short-term debt - commercial paper |
| 23,500 |
| 23,500 |
| 13,000 |
| 13,000 |
|
| Long-term debt(a) |
| 500,168 |
| 562,969 |
| 502,431 |
| 518,811 |
|
(a) Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.3million and $4.5million as of June 30, 2019, and December 31, 2018, respectively.
b.Recurring Fair Value Measurements.
The following table presents the balances of assets and liabilities measured at fair value on a recurring basis.
24
|
|
| Fair Value as of June 30, 2019 |
| ||||||
| (In thousands) |
| Total |
| Level 1 |
| Level 2 |
| Level 3 |
|
| MGE Energy |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net(b) | $ | 1,089 | $ | 342 | $ | - | $ | 747 |
|
| Exchange-traded investments |
| 1,079 |
| 1,079 |
| - |
| - |
|
| Total Assets | $ | 2,168 | $ | 1,421 | $ | - | $ | 747 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 34,605 | $ | 521 | $ | - | $ | 34,084 |
|
| Deferred compensation |
| 3,131 |
| - |
| 3,131 |
| - |
|
| Total Liabilities | $ | 37,736 | $ | 521 | $ | 3,131 | $ | 34,084 |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net(b) | $ | 1,089 | $ | 342 | $ | - | $ | 747 |
|
| Exchange-traded investments |
| 189 |
| 189 |
| - |
| - |
|
| Total Assets | $ | 1,278 | $ | 531 | $ | - | $ | 747 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 34,605 | $ | 521 | $ | - | $ | 34,084 |
|
| Deferred compensation |
| 3,131 |
| - |
| 3,131 |
| - |
|
| Total Liabilities | $ | 37,736 | $ | 521 | $ | 3,131 | $ | 34,084 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Fair Value as of December 31, 2018 |
| ||||||
| (In thousands) |
| Total |
| Level 1 |
| Level 2 |
| Level 3 |
|
| MGE Energy |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 1,042 | $ | 296 | $ | - | $ | 746 |
|
| Exchange-traded investments |
| 848 |
| 848 |
| - |
| - |
|
| Total Assets | $ | 1,890 | $ | 1,144 | $ | - | $ | 746 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 32,872 | $ | 124 | $ | - | $ | 32,748 |
|
| Deferred compensation |
| 3,078 |
| - |
| 3,078 |
| - |
|
| Total Liabilities | $ | 35,950 | $ | 124 | $ | 3,078 | $ | 32,748 |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 1,042 | $ | 296 | $ | - | $ | 746 |
|
| Exchange-traded investments |
| 43 |
| 43 |
| - |
| - |
|
| Total Assets | $ | 1,085 | $ | 339 | $ | - | $ | 746 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 32,872 | $ | 124 | $ | - | $ | 32,748 |
|
| Deferred compensation |
| 3,078 |
| - |
| 3,078 |
| - |
|
| Total Liabilities | $ | 35,950 | $ | 124 | $ | 3,078 | $ | 32,748 |
|
|
|
|
|
|
|
|
|
|
|
|
(b) These amounts are shown gross and exclude $0 million of collateral that was posted against derivative positions with counterparties as of June 30, 2019.
No transfers were made in or out of Level 1 or Level 2 for the six months ended June 30, 2019.
Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.
Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange-traded
25
transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.
The purchased power agreement (see Footnote 11) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.
The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility, and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.
The following table presents the significant unobservable inputs used in the pricing model.
|
|
| Model Input | ||
| Significant Unobservable Inputs |
| June 30, 2019 |
| December 31, 2018 |
| Basis adjustment: |
|
|
|
|
| On peak |
| 92.2% |
| 92.1% |
| Off peak |
| 92.7% |
| 92.8% |
| Counterparty fuel mix: |
|
|
|
|
| Internal generation |
| 40.0% - 60.0% |
| 50.0% - 75.0% |
| Purchased power |
| 60.0% - 40.0% |
| 50.0% - 25.0% |
The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26-week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.
The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis.
26
|
| Three Months Ended |
| Six Months Ended | ||||
|
| June 30, |
| June 30, | ||||
(In thousands) |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
Beginning balance | $ | (31,283) | $ | (41,463) | $ | (32,002) | $ | (42,026) |
Realized and unrealized gains (losses): |
|
|
|
|
|
|
|
|
Included in regulatory assets |
| (2,054) |
| 4,130 |
| (1,335) |
| 4,693 |
Included in other comprehensive income |
| - |
| - |
| - |
| - |
Included in earnings |
| (792) |
| 82 |
| (1,436) |
| (460) |
Included in current assets |
| (376) |
| (297) |
| (203) |
| (470) |
Purchases |
| 5,858 |
| 6,032 |
| 11,623 |
| 11,866 |
Sales |
| - |
| - |
| - |
| - |
Issuances |
| - |
| - |
| - |
| - |
Settlements |
| (4,690) |
| (5,816) |
| (9,984) |
| (10,935) |
Transfers in and/or out of Level 3 |
| - |
| - |
| - |
| - |
Balance as of June 30, | $ | (33,337) | $ | (37,332) | $ | (33,337) | $ | (37,332) |
Total gains (losses) included in earnings attributed to |
|
|
|
|
|
|
|
|
the change in unrealized gains (losses) related to |
|
|
|
|
|
|
|
|
assets and liabilities held at June 30,(c) | $ | - | $ | - | $ | - | $ | - |
The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis (c).
|
|
| Three Months Ended |
| Six Months Ended |
| ||||
|
|
| June 30, |
| June 30, |
| ||||
| (In thousands) |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Purchased Power Expense | $ | (693) | $ | 60 | $ | (1,249) | $ | (663) |
|
| Cost of Gas Sold Expense |
| (99) |
| 22 |
| (187) |
| 203 |
|
| Total | $ | (792) | $ | 82 | $ | (1,436) | $ | (460) |
|
(c) MGE's exchange-traded derivative contracts, over-the-counter party transactions, purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements with a corresponding regulatory asset or liability.
13.
Asset Retirement Obligation - MGE Energy and MGE.
A liability for the fair value of an asset retirement obligation (ARO) is recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life.As of June 30, 2019, MGE recorded an obligation of $1.5 million for the fair value of its legal liability for an ARO associated with the Saratoga Wind Farm. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when those costs would actually be recognized.
14.
Joint Plant Ownership - MGE Energy and MGE.
a. Two Creeks.
In May
2019,
MGE acquired a 33% ownership interest in a 150 MW solar generation array in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewanee Counties, Wisconsin. MGE’s sole principal asset will be the 33% undivided ownership interest in the solar generation facility, which is being constructed.The estimated share of capital costs for MGE’s ownership interest is approximately $65 million (excluding capitalized interest).
As of June 30, 2019, $16.5 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.
27
b. Badger Hollow.
In July
2019,
MGE acquired a 33% ownership interest in a 150 MW solar generation array in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. MGE’s sole principal asset will be the 33% undivided ownership interest in the solar generation facility which is being constructed.The estimated share of capital costs for MGE’s ownership interest is approximately $65 million (excluding capitalized interest).
As of June 30, 2019, $1.0 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.
15.
Revenue - MGE Energy and MGE.
Revenues disaggregated by revenue source were as follows:
|
|
| Three Months Ended |
| Nine Months Ended |
| ||||
| (In thousands) |
| September 30, |
| September 30, |
| ||||
| Electric revenues |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Residential | $ | 42,371 | $ | 39,905 | $ | 107,847 | $ | 104,892 |
|
| Commercial(a) |
| 61,638 |
| 64,036 |
| 159,264 |
| 168,921 |
|
| Industrial |
| 3,668 |
| 4,555 |
| 11,193 |
| 13,286 |
|
| Other-retail/municipal |
| 9,431 |
| 10,459 |
| 26,245 |
| 29,141 |
|
| Total retail |
| 117,108 |
| 118,955 |
| 304,549 |
| 316,240 |
|
| Sales to the market |
| 1,505 |
| 1,068 |
| 6,334 |
| 3,090 |
|
| Other revenues |
| 482 |
| 445 |
| 1,406 |
| 1,436 |
|
| Adjustments to revenues |
| 80 |
| 181 |
| 344 |
| 513 |
|
| Total electric revenues |
| 119,175 |
| 120,649 |
| 312,633 |
| 321,279 |
|
|
|
|
|
|
|
|
|
|
|
|
| Gas revenues |
|
|
|
|
|
|
|
|
|
| Residential |
| 11,916 |
| 12,121 |
| 64,087 |
| 61,164 |
|
| Commercial/Industrial(a) |
| 5,570 |
| 5,622 |
| 38,728 |
| 36,512 |
|
| Total retail |
| 17,486 |
| 17,743 |
| 102,815 |
| 97,676 |
|
| Gas transportation |
| 829 |
| 944 |
| 3,018 |
| 3,285 |
|
| Other revenues |
| 92 |
| 91 |
| 319 |
| 324 |
|
| Total gas revenues |
| 18,407 |
| 18,778 |
| 106,152 |
| 101,285 |
|
|
|
|
|
|
|
|
|
|
|
|
| Non-regulated energy revenues |
| 213 |
| 112 |
| 904 |
| 261 |
|
| Total Operating Revenue(a) | $ | 137,795 | $ | 139,539 |
| 419,689 | $ | 422,825 |
|
(a)
In 2017, MGE had less than $0.1 million of revenues related to CNG vehicle fuel servicing. No revenue was recognized for fuel servicing by MGE Energy in 2017.
|
|
| Three Months Ended |
| Six Months Ended |
| ||||
| (In thousands) |
| June 30, |
| June 30, |
| ||||
| Electric revenues |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Residential | $ | 30,749 | $ | 32,217 | $ | 65,330 | $ | 65,476 |
|
| Commercial |
| 52,762 |
| 50,174 |
| 102,015 |
| 97,626 |
|
| Industrial |
| 3,322 |
| 4,630 |
| 6,253 |
| 7,525 |
|
| Other-retail/municipal |
| 8,946 |
| 8,527 |
| 17,185 |
| 16,814 |
|
| Total retail |
| 95,779 |
| 95,548 |
| 190,783 |
| 187,441 |
|
| Sales to the market |
| 790 |
| 2,795 |
| 2,751 |
| 4,829 |
|
| Other revenues |
| 294 |
| 724 |
| 745 |
| 1,188 |
|
| Total electric revenues |
| 96,863 |
| 99,067 |
| 194,279 |
| 193,458 |
|
|
|
|
|
|
|
|
|
|
|
|
| Gas revenues |
|
|
|
|
|
|
|
|
|
| Residential |
| 16,000 |
| 15,620 |
| 56,317 |
| 52,171 |
|
| Commercial/Industrial |
| 7,883 |
| 8,206 |
| 36,008 |
| 33,158 |
|
| Total retail |
| 23,883 |
| 23,826 |
| 92,325 |
| 85,329 |
|
| Gas transportation |
| 1,094 |
| 1,053 |
| 2,630 |
| 2,189 |
|
| Other revenues |
| 93 |
| 101 |
| 215 |
| 227 |
|
| Total gas revenues |
| 25,070 |
| 24,980 |
| 95,170 |
| 87,745 |
|
|
|
|
|
|
|
|
|
|
|
|
| Non-regulated energy revenues |
| 214 |
| 215 |
| 267 |
| 691 |
|
| Total Operating Revenue | $ | 122,147 | $ | 124,262 |
| 289,716 | $ | 281,894 |
|
|
Performance Obligations
A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account. A contract's transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The majority of MGE Energy's and MGE's contracts have a single performance obligation.
Retail Revenue (Residential, Commercial, Industrial, and Other Retail/Municipal)
Retail revenue of electric and gas utility service represent MGE's core business activities. Tariffs are approved by the PSCW through a rate order and provide MGE's customers with the standard terms and conditions, including pricing terms. The performance obligation to deliver electricity or gas is satisfied over time as the customer simultaneously receives and consumes the commodities provided by MGE. MGE recognizes revenues as the commodity is delivered to customers. Meters are read on a systematic basis throughout the month based on established meter-reading schedules and the customer is subsequently billed for their services. At the end of the month, MGE accrues an estimate for the unbilled amount of commodities delivered to customers. The unbilled revenue estimate is based on daily system demand volumes, weather factors, estimated line losses, estimated customer usage by class, and applicable customer rates.
Utility Cost Recovery Mechanisms
MGE's tariff rates include a provision for fuel cost recovery. The PSCW allows Wisconsin utilities to defer
28
electric fuel-related costs, less excess revenues, that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs in a given year is determined in the following year and is then reflected in future billings to electric retail customers. Over-collection of fuel-related costs that are outside the approved range will be recognized as a reduction of revenue. Prior to adoption of the new revenue recognition guidance, effective January 1, 2018, over-collected fuel-related costs were reflected in "Purchased power" expense. Under-collection of these costs will continue to be recognized in "Purchased power" expense in the consolidated statements of income of MGE Energy and MGE.income. The cumulative effects of these deferred amounts will be recorded in "Regulatory assets" or "Regulatory liabilities" on the consolidated balance sheets of MGE Energy and MGE until they are reflected in future billings to customers. See Footnote 10.b. for further information.
MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates during 2018 as a result of the Tax Cuts and Jobs Act (the Tax Act) reduction in the income tax rate to 21 percent. See Footnote 5 for further information.
MGE has other cost recovery mechanisms. For example, any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.
Sales to the Market
Sales to the market include energy charges, capacity or demand charges, and ancillary charges represented by wholesale sales of electricity made to third parties who are not ultimate users of the electricity. Most of these sales are spot market transactions on the markets operated by MISO. Each transaction is considered a performance obligation and revenue is recognized in the period in which energy charges, capacity or demand charges, and ancillary services are sold into MISO. MGE reports, on a net basis, transactions on the MISO markets in which it buys and sells power within the same hour to meet electric energy delivery requirements.
Transportation of Gas
MGE has contracts under which MGE provides gas transportation services to customers who have elected to purchase gas from a third party and have the gas delivered via pipelines within MGE's service territory. Revenue is recognized as service is rendered or gas is delivered to customers. Tariffs are approved by the PSCW through a rate order and provide gas transportation customers with the standard terms and conditions, including pricing terms.
4.16.
Investment in ATC and ATC Holdco - MGE Energy and MGE.
ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which, since December 1, 2016, is owned by MGE Energy. ATC Holdco was formed by several members of ATC, including MGE Energy, to pursue electric transmission development and investments outside of Wisconsin. The ownership interest in ATC Holdco is held by MGEE Transco, a wholly-owned subsidiary of MGE Energy.
|
As of September 30, 2018, and December 31, 2017, MGE Transco held a 3.6% ownership interest in ATC. As of September 30, 2018, and December 31, 2017, MGEE Transco held a 4.4% ownership interest in ATC Holdco.
MGE Transco and MGEE Transco have accounted for their investments in ATC and ATC Holdco, respectively, under the equity method of accounting. Equity earnings from investments are recorded as "Other income" on the consolidated statements of income of MGE Energy. For the three and nine months ended September 30, 2018 and 2017, MGE Transco recorded the following:
|
|
| Three Months Ended |
| Nine Months Ended |
| ||||
|
|
| September 30, |
| September 30, |
| ||||
| (In thousands) |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Equity earnings from investment in ATC | $ | 1,672 | $ | 2,338 | $ | 6,113 | $ | 7,432 |
|
| Dividends from ATC(a) |
| 1,581 |
| 2,070 |
| 4,540 |
| 4,070 |
|
| Capital contributions to ATC |
| 533 |
| 710 |
| 2,308 |
| 3,018 |
|
MGE Transco recorded a $2.3 million and $2.1 million dividend receivable from ATC as of December 31, 2017 and 2016, respectively. A cash dividend was received in January of each of the proceeding years. MGE Transco recorded a $1.6 million dividend receivable from ATC as of September 30, 2018. A cash dividend was received in October 2018.
ATC Holdco was formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational. During the three and nine months ended September 30, 2018, MGEE Transco recorded capital contributions of $0.1 million and $0.3 million, respectively, to ATC Holdco. During the nine months ended September 30, 2017, MGEE Transco recorded capital contributions of $0.7 million to ATC Holdco. During the three months ended September 30, 2017, MGEE Transco recorded no capital contributions to ATC Holdco.
In October 2018, MGE Transco made a $0.5 million capital contribution to ATC and MGEE Transco made a $0.1 million contribution to ATC Holdco.
ATC's summarized financial data for the three and nine months ended September 30, 2018 and 2017, is as follows:
|
|
| Three Months Ended |
| Nine Months Ended |
| ||||
|
|
| September 30, |
| September 30, |
| ||||
| (In thousands) |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Operating revenues | $ | 170,341 | $ | 171,123 | $ | 501,276 | $ | 522,402 |
|
| Operating expenses |
| (87,959) |
| (85,372) |
| (264,326) |
| (251,042) |
|
| Other income, net |
| 439 |
| 1,272 |
| 2,070 |
| 3,043 |
|
| Interest expense, net |
| (27,754) |
| (28,440) |
| (82,411) |
| (81,690) |
|
| Earnings before members' income taxes | $ | 55,067 | $ | 58,583 | $ | 156,609 | $ | 192,713 |
|
MGE receives transmission and other related services from ATC. During the three and nine months ended September 30, 2018, MGE recorded $7.2 million and $21.7 million, respectively, for transmission services received compared to $7.3 million and $21.9 million for the comparable periods in 2017. MGE also provides a variety of operational, maintenance, and project management services for ATC, which is reimbursed by ATC. As of September 30, 2018, and December 31, 2017, MGE had a receivable due from ATC of $0.1 million and $0.2 million, respectively.
Taxes - MGE Energy and MGE.
Effective Tax Rate.
On December 22, 2017, the U.S. government enacted comprehensive tax legislation commonly referred to as the Tax Cuts and Jobs Act. The Tax Act makes broad and complex changes to the U.S. tax code, including the reduction in the U.S. federal corporate tax rate from 35 to 21 percent, effective January 1, 2018. MGE Energy and MGE recorded a provisional decrease in deferred tax assets and deferred tax liabilities as of December 31, 2017. In accordance with Staff Accounting Bulletin 118, any subsequent adjustment to these amounts will be recorded in the fourth quarter of 2018 when the analysis is complete. No adjustments have been recorded during 2018. Beginning January 1, 2018, MGE began amortizing the regulated utility excess
deferred taxes recognized using a normalization method of accounting. For the three and nine months ended
|
September 30, 2018, MGE recognized $0.7 million and $1.9 million, respectively, of excess deferred taxes as a reduction of revenue and a corresponding increase in a regulatory liability. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, which will be determined by the PSCW.
Customer rates approved for 2018 reflect an income tax rate of 35 percent. In January 2018, the PSCW issued an order directing Wisconsin investor-owned utilities to defer the over-collection of income tax expense as a result of the decrease in tax rate to 21 percent. The PSCW issued an order in May 2018 to return to customers the estimated 2018 over-collection of income tax expense. The decision includes a one-time bill credit on customer bills to reflect the estimate of the over-collection for January through June 2018, along with a monthly volumetric bill credit which began in July 2018 and continues through the remainder of 2018 for the estimated remaining annual amount. As of September 30, 2018, MGE returned $5.9 million to customers through bill credits. Any over/under recovery of the actual costs will be subject to the PSCW's review in a future rate case. As ofSeptember 30, 2018, MGE has deferred $2.6 million as a regulatory liability and recorded a corresponding reduction in operating revenues for over-collection of income tax expense (net of customer bill credits).
The consolidated income tax provision differs from the amount computed by applying the statutory federal income tax rate to income before income taxes, as follows:
|
| MGE Energy |
| MGE |
| ||||
| Three Months Ended September 30, | 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Statutory federal income tax rate | 21.0 % |
| 35.0 % |
| 21.0 % |
| 35.0 % |
|
| State income taxes, net of federal benefit | 6.3 % |
| 5.2 % |
| 6.2 % |
| 5.1 % |
|
| Amortized investment tax credits | (0.1)% |
| (0.3)% |
| (0.1)% |
| (0.4)% |
|
| Credit for electricity from wind energy | (0.3)% |
| (1.1)% |
| (0.2)% |
| (1.1)% |
|
| Domestic manufacturing deduction | -% |
| (1.5)% |
| -% |
| (1.4)% |
|
| AFUDC equity, net | (0.6)% |
| (0.1)% |
| (0.6)% |
| (0.1)% |
|
| Amortization of utility excess deferred tax - tax reform(a) | (1.8)% |
| -% |
| (1.8)% |
| -% |
|
| Other, net, individually insignificant | -% |
| (0.3)% |
| 0.1 % |
| (0.4)% |
|
| Effective income tax rate | 24.5 % |
| 36.9 % |
| 24.6 % |
| 36.7 % |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE Energy |
| MGE |
| ||||
| Nine Months Ended September 30, | 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Statutory federal income tax rate | 21.0 % |
| 35.0 % |
| 21.0 % |
| 35.0 % |
|
| State income taxes, net of federal benefit | 6.3 % |
| 5.2 % |
| 6.2 % |
| 5.1 % |
|
| Amortized investment tax credits | (0.1)% |
| (0.3)% |
| (0.1)% |
| (0.4)% |
|
| Credit for electricity from wind energy | (0.3)% |
| (1.3)% |
| (0.3)% |
| (1.4)% |
|
| Domestic manufacturing deduction | -% |
| (1.6)% |
| -% |
| (1.7)% |
|
| AFUDC equity, net | (0.8)% |
| (0.2)% |
| (0.8)% |
| (0.2)% |
|
| Amortization of utility excess deferred tax - tax reform(a) | (1.8)% |
| -% |
| (2.0)% |
| -% |
|
| Other, net, individually insignificant | -% |
| (0.2)% |
| 0.1 % |
| (0.1)% |
|
| Effective income tax rate | 24.3 % |
| 36.6 % |
| 24.1 % |
| 36.3 % |
|
Included are impacts of the Tax Act for the regulated utility for excess deferred taxes recognized using a normalization method of accounting.
Pension and Other Postretirement Plans - MGE Energy and MGE.
MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.
The components of net periodic benefit cost, other than the service cost component, are recorded in "Other income, net" on the consolidated statements of income. The service cost component is recorded in "Other operations and maintenance" on the consolidated statements of income. Prior to January 1, 2018, a portion of all net periodic benefit cost components were capitalized within the consolidated balance sheets. The FASB issued authoritative guidance within the codification's Compensation-Retirement Benefits topic that, beginning January 1, 2018, only allows the service cost component of net periodic benefit cost to be eligible for capitalization within the consolidated balance sheets. MGE has regulatory treatment and recognizes regulatory assets or liabilities for timing differences between when net periodic benefit costs are recovered and when costs are recognized.
|
The following table presents the components of net periodic benefit costs recognized for the three and nine months ended September 30, 2018 and 2017.
|
|
| Three Months Ended |
| Nine Months Ended |
| ||||
|
|
| September 30, |
| September 30, |
| ||||
| (In thousands) |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Pension Benefits |
|
|
|
|
|
|
|
|
|
| Components of net periodic benefit cost: |
|
|
|
|
|
|
|
|
|
| Service cost | $ | 1,431 | $ | 1,351 | $ | 4,292 | $ | 4,043 |
|
| Interest cost |
| 3,215 |
| 3,168 |
| 9,645 |
| 9,481 |
|
| Expected return on assets |
| (6,560) |
| (5,762) |
| (19,680) |
| (17,244) |
|
| Amortization of: |
|
|
|
|
|
|
|
|
|
| Prior service credit |
| (11) |
| (4) |
| (33) |
| (12) |
|
| Actuarial loss |
| 1,319 |
| 1,594 |
| 3,958 |
| 4,769 |
|
| Net periodic benefit (credit) cost | $ | (606) | $ | 347 | $ | (1,818) | $ | 1,037 |
|
|
|
|
|
|
|
|
|
|
|
|
| Postretirement Benefits |
|
|
|
|
|
|
|
|
|
| Components of net periodic benefit cost: |
|
|
|
|
|
|
|
|
|
| Service cost | $ | 320 | $ | 315 | $ | 962 | $ | 944 |
|
| Interest cost |
| 653 |
| 678 |
| 1,959 |
| 2,034 |
|
| Expected return on assets |
| (808) |
| (722) |
| (2,424) |
| (2,165) |
|
| Amortization of: |
|
|
|
|
|
|
|
|
|
| Transition obligation |
| 1 |
| 1 |
| 2 |
| 2 |
|
| Prior service credit |
| (667) |
| (667) |
| (2,001) |
| (2,001) |
|
| Actuarial loss |
| 122 |
| 190 |
| 366 |
| 570 |
|
| Net periodic benefit (credit) cost | $ | (379) | $ | (205) | $ | (1,136) | $ | (616) |
|
Equity and Financing Arrangements - MGE Energy.
a.
Common Stock.
MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the Stock Plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the three and nine months ended September 30, 2018 and 2017, MGE Energy did not issue any new shares of common stock under the Stock Plan.
b.
Dilutive Shares Calculation.
MGE Energy does not have any stock option or stock award programs or any dilutive securities.
c.
Long-term Debt - MGE Energy and MGE.
In July 2018, MGE issued $20 million of new long-term unsecured debt carrying an interest rate of 4.24% per annum over its 35-year term and $20 million of new long-term unsecured debt carrying an interest rate of 4.34% per annum over its 40-year term. In September 2018, MGE issued $60 million of new long-term unsecured debt carrying an interest rate of 4.19% per annum over its 30-year term. MGE used the net proceeds from these debt financings to assist with financing capital expenditures, such as the Saratoga Wind Farm, and to refinance $20 million of long-term debt which matured in September 2018. The covenants of the new long-term unsecured debt are substantially consistent with MGE's existing unsecured long-term debt.
Share-Based Compensation - MGE Energy and MGE.
Under MGE Energy's Director Incentive Plan and its Performance Unit Plan, non-employee directors and eligible employees, respectively, may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the performance period set in the award.
|
In 2018, 5,810 units were granted under the Director Incentive Plan and are subject to a three-year graded vesting schedule, and 17,830 units were granted under the Performance Unit Plan and are subject to a five-year graded vesting schedule. On the grant date, the cost of the director or employee services received in exchange for a performance unit award is measured based on the current market value of MGE Energy common stock. The fair value of the awards is remeasured quarterly, including as of September 30, 2018, as required by applicable accounting standards. Changes in fair value as well as the original grant are recognized as compensation cost. Since this amount is remeasured throughout the vesting period, the compensation cost is subject to variability.
For nonretirement eligible employees under the Performance Unit Plan, stock-based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon as retirement eligibility accelerates vesting.
During the three and nine months ended September 30, 2018, MGE recorded $0.3 million and $1.3 million, respectively, in compensation expense as a result of awards under the plans compared to $0.3 million and $1.0 million for the comparable periods in 2017. In January 2018, cash payments of $1.6 million were distributed relating to awards that were granted under the plans. No forfeitures of units occurred during the three and nine months ended September 30, 2018 and 2017. As of September 30, 2018, $5.5 million of outstanding awards are vested. Of this amount, no cash settlements have occurred as cash payments are only made at the end of the period covered by the awards.
Commitments and Contingencies.
a.
Environmental - MGE Energy and MGE.
MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Regulatory initiatives, proposed rules, and court challenges to adopted rules have the potential to have a material effect on our capital expenditures and operating costs. Management believes compliance costs will be recovered in future rates based on previous treatment of environmental compliance projects. These initiatives, proposed rules, and court challenges include:
•
The EPA's published water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants, such as the coal-burning plants at Columbia and the Elm Road Units.
•
The EPA's cooling water intake rules, which require cooling water intake structures at electric power plants, such as our WCCF, Blount, and Columbia plants, to meet best available technology standards so that mortality from entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) are reduced.
•
Greenhouse Gas (GHG) reduction guidelines and approval criteria established under the Clean Air Act for states to use in developing plans to control GHG emissions from existing fossil fuel-fired electric generating units (EGUs). In 2015, the EPA finalized the Clean Power Plan (CPP) which directed states to submit plans to reduce GHG emissions from the electric generation sector. In February 2016, the U.S. Supreme Court stayed implementation of the CPP and the stay remains in effect. In October 2017, the EPA issued a proposed rule to repeal the CPP. In August 2018, the EPA proposed the Affordable Clean Energy (ACE) rule which would replace the CPP, if successfully implemented. The ACE proposal directs states to submit plans to the EPA for approval that implement standards of performance (called Best System of Emissions Reductions, or BSER) for individual EGUs over 25 MW. ACE defines BSER as on-site, heat-rate efficiency improvements, whereas theCPP defines BSERs using carbon dioxide emission performance rates. Simple cycle units such as our smaller combustion units, and combined cycle units such as our WCCF are exempt from the proposed rule. If a state fails to prepare a plan, or their plan is not approved by the EPA a federal implementation plan (FIP) will be issued for that state. The proposed ACE as it is currently written has the potential to impact our Blount Generating Station, Columbia, and Elm Road Units.
|
MGE cannot yet determine with any certainty the impact of the proposed ACE rule on our operations. MGE previously determined that if the CPP were to be implemented in its present form, it would have a material impact on MGE. MGE will continue to monitor developments with the proposed ACE rule and the CPP rule and litigation.
•
The EPA's rule to regulate ambient levels of ozone through the 2015 Ozone National Ambient Air Quality Standards (NAAQS). On May 1, 2018, EPA issued a final rule which designated the northeast portion of Milwaukee County as being in nonattainment with this NAAQS. The Elm Road Units are located in Milwaukee County, yet outside the designated nonattainment area. In August 2018, several environmental groups, the City of Chicago and the State of Illinois filed federal lawsuits challenging the EPA's attainment designation decisions, including the partial Milwaukee County designation as being too narrow and not sufficiently protective. MGE is monitoring the outcome of this lawsuit and how it may affect our Elm Road Units in Milwaukee County. At this time MGE expects that the 2015 Ozone NAAQS will not have a material effect on its existing plants based on final designations.
The State of Wisconsin has joined a lawsuit filed by several states challenging the EPA's 2015 Ozone NAAQS, alleging that the new standard is not attainable and the EPA is not properly considering background levels in setting its ozone attainment levels. The lawsuit is ongoing; however, the significance of the challenge, as it might relate to MGE, is now diminished with the final ozone attainment designations.
•
Rules regulating nitrogen oxide (NOx) and sulfur dioxide (SO2) emissions, including the Cross State Air Pollution Rule (CSAPR), CSAPR Update Rule and Clean Air Visibility Rule (CAVR). At this time, regulatory obligations, compliance strategies, and costs remain unclear due to uncertainties surrounding the ongoing implementation of Phase II of CSAPR and the continued legal challenges surrounding CSAPR, the CSAPR Update Rule and CAVR.
•
The EPA's Coal Combustion Residuals Rule (CCR), which regulates coal ash from burning coal for the purpose of generating electricity as a solid waste, and defines what ash use activities would be considered generally exempt beneficial reuse of coal ash. The CCR rule also regulates landfills, ash ponds, and other surface impoundments used for coal combustion residuals by regulating their design, location, monitoring, and operation. Review of our Elm Road Units has indicated that the costs to comply with this rule are not expected to be significant. Columbia's operator has completed a review of their system and has determined that an onsite ash pond will need to be closed and replaced with a dry ash handling system. The dry ash handling system installation is planned for 2020-2021. In July 2018, the EPA published a final rule that included amendments to the CCR (which include the allowance of alternative performance standards for landfills and surface impoundments, revised risk-based groundwater protection standards, and an extension of the deadline by which certain facilities must cease the placement of waste in CCR units). In August 2018, the Court of Appeals for the D.C. Circuit vacated parts of the CCR for not being sufficiently protective of the environment. It is unclear how the EPA will respond to that decision. MGE will continue to monitor potential rule modifications to assess potential impacts on our operations.
In 2015, MGE recorded an asset retirement obligation for its share of the legal liability associated with the effect of the CCR. Actual costs of compliance may be different than the amount recorded due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes.
b.
Legal Matters - MGE Energy and MGE.
MGE is involved in various legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements. MGE does not expect the resolution of these matters to have a material adverse effect on its consolidated results of operations, financial condition, or cash flows.
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c.
Purchase Contracts - MGE Energy and MGE.
MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. Management expects to recover these costs in future customer rates. The following table shows future commitments related to purchase contracts as of September 30, 2018:
| (In thousands) |
| 2018 |
| 2019 |
| 2020 |
| 2021 |
| 2022 |
| Thereafter |
|
| Coal(a) | $ | 6,716 | $ | 21,188 | $ | 8,434 | $ | 828 | $ | - | $ | - |
|
| Natural gas supply(b) |
| 12,245 |
| 13,287 |
| - |
| - |
| - |
| - |
|
| Saratoga wind(c) |
| 1,006 |
| 858 |
| 2,266 |
| 1,775 |
| 1,784 |
| 4,459 |
|
| Other |
| 1,772 |
| 502 |
| 502 |
| 502 |
| 502 |
| 502 |
|
|
| $ | 21,739 | $ | 35,835 | $ | 11,202 | $ | 3,105 | $ | 2,286 | $ | 4,961 |
|
Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units is handled by WPL and WEPCO, respectively, who are the operators of those facilities.
These commitments include market-based pricing.
In December 2017, the PSCW authorized construction of a 66MW wind farm, consisting of 33 turbines, located near Saratoga, Iowa. MGE received specific approval to recover 100% AFUDC on the project. As of September 30, 2018, MGE has incurred $66.5 million of capital expenditures. After tax, MGE has recognized $0.6 million and $1.3 million, respectively, in AFUDC equity related to this project for the three and nine months ended September 30, 2018. Construction of the project is expected to be completed by early 2019, with an estimated capital cost of $108 million.
d.
Other Commitments - MGE Energy.
In September 2018, MGE Energy entered into two subscription agreements to invest in nonpublic venture capital funds. From time to time, these funds make capital calls to their investors. MGE Energy has committed to contribute $2.3 million in capital for such capital calls. The timing of these capital calls is dependent on the needs of the funds and is therefore uncertain at this time.
Rate Matters - MGE Energy and MGE.
a.
Rate Proceedings.
In July 2018, MGE filed an application with the PSCW to adjust electric and gas rates for 2019 and 2020. MGE filed its application through a settlement agreement between MGE and intervening parties in the rate case, subject to PSCW approval. The settlement proposal would decrease electric rates by 1.94% in 2019. This amount is subject to change based on the final outcome of MGE's 2019 Fuel Cost Plan. MGE will maintain this rate level for 2020, with the exception that MGE will file a 2020 Fuel Cost Plan in 2019 and MGE's electric rates will be adjusted accordingly. The decrease reflects the ongoing tax impacts of the Tax Act and the addition of lower-cost renewable generation capacity. The settlement agreement increases gas rates by 1.06% in 2019 and 1.46% in 2020. The requested gas increase covers infrastructure costs. It also reflects the impacts of the Tax Act. The return on common stock equity for 2019 and 2020 will be 9.8% based on a capital structure consisting of56.6% common equity in 2019 and 56.1% common equity in 2020.
In December 2016, the PSCW authorized MGE, effective January 1, 2017, to decrease 2017 rates for retail electric customers by 0.8% or $3.3 million on an annual basis and to increase rates for retail gas customers by 1.9% or $3.1 million on an annual basis. The decrease in retail electric rates was attributable to declining fuel and purchased power costs. The increase in retail gas rates covers costs associated with MGE's natural gas system infrastructure improvements. The authorized return on common stock equity for 2017 was 9.8% based on a capital structure consisting of 57.2% common equity.
b.
Fuel Rules.
Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its annual fuel proceedings. Any over/under recovery of the actual costs is determined in the following year and is then reflected in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%.
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Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.
In July 2017, the PSCW issued a final order in the fuel rules proceedings requiring MGE to refund additional fuel savings realized during 2015 and 2016 to its retail electric customers over a one-month period. In October 2017, MGE returned $6.2 million to customers through bill credits.
In December 2017, the PSCW approved a surcharge for 2018 electric fuel-related costs. The surcharge will increase electric retail revenue in 2018 by $0.5 million or 0.1%.
In August 2018, the PSCW issued a final decision in the fuel rules proceedings for MGE to refund $4.2 million of additional fuel savings realized during 2017 to its retail electric customers over a one-month period in October 2018. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred as of December 31, 2017.
As of September 30, 2018, MGE has deferred $7.2 million of 2018 fuel savings. The 2018 fuel savings will be subject to the PSCW's annual review of 2018 fuel costs, expected to be completed in 2019. As of December 31, 2017, MGE had deferred $4.2 million of 2017 fuel savings.
Derivative and Hedging Instruments - MGE Energy and MGE.
a.
Purpose.
As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, the derivatives are recognized in the consolidated balance sheets at fair value. MGE's financial commodity derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability depending on whether the derivative is in a net loss or net gain position, respectively. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.
b.
Notional Amounts.
The gross notional volume of open derivatives is as follows:
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c.
Financial Statement Presentation.
MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds financial transmission rights (FTRs). An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a
|
net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. As of September 30, 2018, and December 31, 2017, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $1.6 million and $0.2 million, respectively.
MGE is a party to a purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of September 30, 2018, and December 31, 2017, reflects a loss position of $36.3 million and $42.2 million, respectively. The actual cost will be recognized in purchased power expense in the month of purchase.
The following table summarizes the fair value of the derivative instruments on the consolidated balance sheets.All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, instruments are netted with the same counterparty under a master netting agreement as well as the netting of collateral. As of September 30, 2018, and December 31, 2017, the receivable margin account balance of $0.8 million and $2.5 million, respectively, is shown net of any collateral posted against derivative positions.
|
|
| Derivative |
| Derivative |
|
|
|
| (In thousands) |
| Assets |
| Liabilities |
| Balance Sheet Location |
|
| September 30, 2018 |
|
|
|
|
|
|
|
| Commodity derivative contracts(a) | $ | 1,363 | $ | 232 |
| Other current assets |
|
| Commodity derivative contracts(a) |
| 86 |
| 55 |
| Other deferred charges |
|
| FTRs |
| 478 |
| - |
| Other current assets |
|
| PPA |
| N/A |
| 9,350 |
| Derivative liability (current) |
|
| PPA |
| N/A |
| 26,920 |
| Derivative liability (long-term) |
|
|
|
|
|
|
|
|
|
|
| December 31, 2017 |
|
|
|
|
|
|
|
| Commodity derivative contracts(a) | $ | 566 | $ | 603 |
| Derivative liability (current)(b) |
|
| Commodity derivative contracts(a) |
| 110 |
| 190 |
| Derivative liability (long-term) |
|
| FTRs |
| 329 |
| - |
| Other current assets |
|
| PPA |
| N/A |
| 8,180 |
| Derivative liability (current) |
|
| PPA |
| N/A |
| 33,990 |
| Derivative liability (long-term) |
|
As of December 31, 2017, collateral of $0.1 million was posted against and netted with derivative liability positions on the consolidated balance sheets. No collateral was posted against derivative positions as of September 30, 2018.
As of December 31, 2017, MGE presented $0.1 million as other current assets on the consolidated balance sheets.
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The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the consolidated balance sheets.
| Offsetting of Derivative Assets |
| ||||||||
| (In thousands) |
| Gross Amounts |
| Gross Amounts Offset in Balance Sheets |
| Collateral Posted Against Derivative Positions |
| Net Amount Presented in Balance Sheets |
|
| September 30, 2018 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 1,449 | $ | (287) | $ | - | $ | 1,162 |
|
| FTRs |
| 478 |
| - |
| - |
| 478 |
|
|
|
|
|
|
|
|
|
|
|
|
| December 31, 2017 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 676 | $ | (654) | $ | - | $ | 22 |
|
| FTRs |
| 329 |
| - |
| - |
| 329 |
|
| Offsetting of Derivative Liabilities |
| ||||||||
| (In thousands) |
| Gross Amounts |
| Gross Amounts Offset in Balance Sheets |
| Collateral Posted Against Derivative Positions |
| Net Amount Presented in Balance Sheets |
|
| September 30, 2018 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 287 | $ | (287) | $ | - | $ | - |
|
| PPA |
| 36,270 |
| - |
| - |
| 36,270 |
|
|
|
|
|
|
|
|
|
|
|
|
| December 31, 2017 |
|
|
|
|
|
|
|
|
|
| Commodity derivative contracts | $ | 793 | $ | (654) | $ | (139) | $ | - |
|
| PPA |
| 42,170 |
| - |
| - |
| 42,170 |
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The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheets as of September 30, 2018 and 2017, and the consolidated statements of income for the three and nine months ended September 30, 2018 and 2017.
|
| 2018 |
|
| 2017 | ||||
(In thousands) |
| Current and Long-Term Regulatory Asset |
| Other Current Assets |
|
| Current and Long-Term Regulatory Asset |
| Other Current Assets |
Three Months Ended September 30: |
|
|
|
|
|
|
|
|
|
Balance at July 1, | $ | 36,924 | $ | 640 |
| $ | 45,316 | $ | 618 |
Unrealized gain |
| (2,007) |
| - |
|
| (1,277) |
| - |
Realized (loss) gain reclassified to a deferred account |
| (316) |
| 316 |
|
| (313) |
| 313 |
Realized gain (loss) reclassified to income statement |
| 29 |
| (62) |
|
| (1,450) |
| (57) |
Balance at September 30, | $ | 34,630 | $ | 894 |
| $ | 42,276 | $ | 874 |
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30: |
|
|
|
|
|
|
|
|
|
Balance at January 1, | $ | 41,958 | $ | 806 |
| $ | 49,281 | $ | 230 |
Unrealized gain |
| (5,906) |
| - |
|
| (3,698) |
| - |
Realized (loss) gain reclassified to a deferred account |
| (837) |
| 837 |
|
| (935) |
| 935 |
Realized loss reclassified to income statement |
| (585) |
| (749) |
|
| (2,372) |
| (291) |
Balance at September 30, | $ | 34,630 | $ | 894 |
| $ | 42,276 | $ | 874 |
|
|
| Realized Losses (Gains) | |||||||
|
| 2018 |
|
| 2017 | ||||
(In thousands) |
| Fuel for Electric Generation/ Purchased Power |
| Cost of Gas Sold |
|
| Fuel for Electric Generation/ Purchased Power |
| Cost of Gas Sold |
Three Months Ended September 30: |
|
|
|
|
|
|
|
|
|
Commodity derivative contracts | $ | (145) | $ | - |
| $ | 362 | $ | 18 |
FTRs |
| (150) |
| - |
|
| (224) |
| - |
PPA |
| 328 |
| - |
|
| 1,351 |
| - |
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30: |
|
|
|
|
|
|
|
|
|
Commodity derivative contracts | $ | 39 | $ | 637 |
| $ | 764 | $ | 227 |
FTRs |
| (625) |
| - |
|
| (1,349) |
| - |
PPA |
| 1,283 |
| - |
|
| 3,021 |
| - |
MGE's commodity derivative contracts, FTRs, and PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheets and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.
The PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of September 30, 2018, no collateral is required to be, or has been, posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of September 30, 2018, no counterparties were in a net liability position. As of December 31, 2017, certain counterparties were in a net liability position of $0.1 million.
Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of September 30, 2018, no counterparties have defaulted.
Fair Value of Financial Instruments - MGE Energy and MGE.
Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The accounting standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three-level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:
Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.
Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.
Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.
a.
Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount.
The carrying amount of cash, cash equivalents, and outstanding commercial paper approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of long-term debt is based on quoted market prices for similar financial instruments. Since long-term debt is not traded in an active market, it is classified as Level 2.
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The estimated fair market value of financial instruments are as follows:
|
|
| September 30, 2018 |
| December 31, 2017 |
| ||||
| (In thousands) |
| Carrying Amount |
| Fair Value |
| Carrying Amount |
| Fair Value |
|
| MGE Energy |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Cash and cash equivalents | $ | 133,855 | $ | 133,855 | $ | 107,952 | $ | 107,952 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Short-term debt - commercial paper |
| - |
| - |
| 4,000 |
| 4,000 |
|
| Long-term debt(a) |
| 503,553 |
| 523,075 |
| 426,883 |
| 475,282 |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Cash and cash equivalents | $ | 47,264 | $ | 47,264 | $ | 5,951 | $ | 5,951 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Short-term debt - commercial paper |
| - |
| - |
| 4,000 |
| 4,000 |
|
| Long-term debt(a) |
| 503,553 |
| 523,075 |
| 426,883 |
| 475,282 |
|
(a)
Includes long-term debt due within one year. Excludes debt issuance costs and unamortized discount of $4.6 million and $4.3 million as of September 30, 2018, and December 31, 2017, respectively.
b.
Recurring Fair Value Measurements.
The following table presents the balances of assets and liabilities measured at fair value on a recurring basis.
|
|
| Fair Value as of September 30, 2018 |
| ||||||
| (In thousands) |
| Total |
| Level 1 |
| Level 2 |
| Level 3 |
|
| MGE Energy |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 1,927 | $ | 824 | $ | - | $ | 1,103 |
|
| Exchange-traded investments |
| 1,005 |
| 1,005 |
| - |
| - |
|
| Total Assets | $ | 2,932 | $ | 1,829 | $ | - | $ | 1,103 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 36,557 | $ | 140 | $ | - | $ | 36,417 |
|
| Deferred compensation |
| 2,985 |
| - |
| 2,985 |
| - |
|
| Total Liabilities | $ | 39,542 | $ | 140 | $ | 2,985 | $ | 36,417 |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 1,927 | $ | 824 | $ | - | $ | 1,103 |
|
| Exchange-traded investments |
| 70 |
| 70 |
| - |
| - |
|
| Total Assets | $ | 1,997 | $ | 894 | $ | - | $ | 1,103 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 36,557 | $ | 140 | $ | - | $ | 36,417 |
|
| Deferred compensation |
| 2,985 |
| - |
| 2,985 |
| - |
|
| Total Liabilities | $ | 39,542 | $ | 140 | $ | 2,985 | $ | 36,417 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Fair Value as of December 31, 2017 |
| ||||||
| (In thousands) |
| Total |
| Level 1 |
| Level 2 |
| Level 3 |
|
| MGE Energy |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 1,005 | $ | 278 | $ | - | $ | 727 |
|
| Exchange-traded investments |
| 792 |
| 792 |
| - |
| - |
|
| Total Assets | $ | 1,797 | $ | 1,070 | $ | - | $ | 727 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net(b) | $ | 42,963 | $ | 210 | $ | - | $ | 42,753 |
|
| Deferred compensation |
| 3,065 |
| - |
| 3,065 |
| - |
|
| Total Liabilities | $ | 46,028 | $ | 210 | $ | 3,065 | $ | 42,753 |
|
|
|
|
|
|
|
|
|
|
|
|
| MGE |
|
|
|
|
|
|
|
|
|
| Assets: |
|
|
|
|
|
|
|
|
|
| Derivatives, net | $ | 1,005 | $ | 278 | $ | - | $ | 727 |
|
| Exchange-traded investments |
| 64 |
| 64 |
| - |
| - |
|
| Total Assets | $ | 1,069 | $ | 342 | $ | - | $ | 727 |
|
| Liabilities: |
|
|
|
|
|
|
|
|
|
| Derivatives, net(b) | $ | 42,963 | $ | 210 | $ | - | $ | 42,753 |
|
| Deferred compensation |
| 3,065 |
| - |
| 3,065 |
| - |
|
| Total Liabilities | $ | 46,028 | $ | 210 | $ | 3,065 | $ | 42,753 |
|
(b)
These amounts are shown gross and exclude $0.1 million of collateral that was posted against derivative positions with counterparties as of December 31, 2017.
No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2018.
Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.
Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore considered unobservable and classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange-traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.
The purchased power agreement (see Footnote 11) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off-peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease, and if the basis adjustment is increased, the fair value measurement will increase.
The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility, and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.
|
The following table presents the significant unobservable inputs used in the pricing model.
|
|
| Model Input | ||
| Significant Unobservable Inputs |
| September 30, 2018 |
| December 31, 2017 |
| Basis adjustment: |
|
|
|
|
| On peak |
| 91.9% |
| 92.3% |
| Off peak |
| 93.2% |
| 94.1% |
| Counterparty fuel mix: |
|
|
|
|
| Internal generation |
| 50% - 75% |
| 55% - 75% |
| Purchased power |
| 50% - 25% |
| 45% - 25% |
The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26-week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.
The following table summarizes the changes in Level 3 commodity derivative assets and liabilities measured at fair value on a recurring basis.
|
| Three Months Ended |
| Nine Months Ended | ||||
|
| September 30, |
| September 30, | ||||
(In thousands) |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
Beginning balance | $ | (37,332) | $ | (45,605) | $ | (42,026) | $ | (50,305) |
Realized and unrealized gains (losses): |
|
|
|
|
|
|
|
|
Included in regulatory assets |
| 2,018 |
| 2,846 |
| 6,711 |
| 7,547 |
Included in other comprehensive income |
| - |
| - |
| - |
| - |
Included in earnings |
| 26 |
| (1,478) |
| (434) |
| (2,614) |
Included in current assets |
| (25) |
| (14) |
| (496) |
| (111) |
Purchases |
| 5,736 |
| 6,299 |
| 17,602 |
| 18,481 |
Sales |
| - |
| - |
| - |
| - |
Issuances |
| - |
| - |
| - |
| - |
Settlements |
| (5,737) |
| (4,807) |
| (16,671) |
| (15,757) |
Transfers in and/or out of Level 3 |
| - |
| - |
| - |
| - |
Balance as of September 30, | $ | (35,314) | $ | (42,759) | $ | (35,314) | $ | (42,759) |
Total gains (losses) included in earnings attributed to |
|
|
|
|
|
|
|
|
the change in unrealized gains (losses) related to |
|
|
|
|
|
|
|
|
assets and liabilities held at September 30,(c) | $ | - | $ | - | $ | - | $ | - |
The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis(c).
|
|
| Three Months Ended |
| Nine Months Ended |
| ||||
|
|
| September 30, |
| September 30, |
| ||||
| (In thousands) |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Purchased Power Expense | $ | 26 | $ | (1,460) | $ | (637) | $ | (2,377) |
|
| Cost of Gas Sold Expense |
| - |
| (18) |
| 203 |
| (237) |
|
| Total | $ | 26 | $ | (1,478) | $ | (434) | $ | (2,614) |
|
MGE's exchange-traded derivative contracts, over-the-counter party transactions, purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements with a corresponding regulatory asset or liability.
|
Joint Plant Ownership - MGE Energy and MGE.
a.
Columbia.
In 2016, MGE and WPL negotiated an amendment to the existing Columbia joint operating agreement that has been approved by the PSCW. Under the terms of the amendments, MGE has reduced its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. On January 1 of each year from 2017 through 2019 and then on June 1, 2020, the ownership percentage is adjusted through a partial sale based on the amount of capital expenditures foregone. In June 2017, the FERC approved the ownership transfer in Columbia, effective January 1, 2017.
During 2017, MGE accrued $8.8 million of 2017 foregone capital expenditures as part of the ownership transfer agreement with WPL. As of December 31, 2017, MGE classified $8.8 million of Columbia assets as held-for-sale on the consolidated balance sheets. In January 2018, MGE reduced its ownership interest in Columbia from 20.4% to 19.4% as a result of the partial sale of plant assets to WPL.
During the three and nine months ended September 30, 2018, MGE accrued $0.4 million and $1.8 million, respectively, of 2018 foregone capital expenditures as part of the ownership transfer agreement. As of September 30, 2018, MGE classified $1.8 million of Columbia assets as held-for-sale on the consolidated balance sheets. The assets recognized as held-for-sale are covered by the ownership transfer agreement relating to the sale of plant assets to WPL, and are expected to be sold and transferred in January 2019.
b.
Forward Wind.
In April 2018, MGE, along with two other utilities, purchased the Forward Wind Energy Center (Forward Wind), which consists of 86 wind turbines located in Wisconsin with a total capacity of 129 MWs. The aggregate purchase price was approximately $174 million, of which MGE's proportionate share is 12.8%, or approximately $23 million. The purchase of Forward Wind replaced an existing purchase power agreement, under which MGE purchased 12.8% of the facility's energy output.
MGE Energy and MGE are required to record a liability for the fair value of an asset retirement obligation (ARO) to be recognized in the period in which it is incurred if it can be reasonably estimated. The offsetting associated asset retirement costs are capitalized as a long-lived asset and depreciated over the asset's useful life. As of September 30, 2018, MGE recorded an obligation of $1.6 million for the fair value of its legal liability for AROs associated with Forward Wind. MGE has regulatory treatment and recognizes regulatory assets or liabilities for the timing differences between when we recover legal AROs in rates and when those costs would actually be recognized.
Segment Information - MGE Energy and MGE.
MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See the 20172018 Annual Report on Form 10-K for additional discussion of each of these segments.
|
The following tables show segment information for MGE Energy's operations for the indicated periods:
(a)
Reflects retrospective application of new accounting pronouncement related to pension and other postretirement benefits, see Footnote 2 for further information.
29
|
(In thousands) MGE Energy |
| Electric |
| Gas |
| Non-regulated Energy |
| Transmission Investment |
| All Others |
| Consolidation/ Elimination Entries |
| Consolidated Total |
Three Months Ended June 30, 2019 |
|
|
|
|
|
|
|
|
|
|
|
| ||
Operating revenues | $ | 96,863 | $ | 25,070 | $ | 214 | $ | - | $ | - | $ | - | $ | 122,147 |
Interdepartmental revenues |
| 198 |
| 1,929 |
| 9,995 |
| - |
| - |
| (12,122) |
| - |
Total operating revenues |
| 97,061 |
| 26,999 |
| 10,209 |
| - |
| - |
| (12,122) |
| 122,147 |
Depreciation and amortization |
| (13,379) |
| (2,843) |
| (1,869) |
| - |
| - |
| - |
| (18,091) |
Other operating expenses |
| (73,130) |
| (22,931) |
| (33) |
| - |
| (301) |
| 12,122 |
| (84,273) |
Operating income (loss) |
| 10,552 |
| 1,225 |
| 8,307 |
| - |
| (301) |
| - |
| 19,783 |
Other income (deductions), net |
| 1,788 |
| 1,170 |
| - |
| 2,267 |
| (206) |
| - |
| 5,019 |
Interest (expense) income, net |
| (3,826) |
| (1,032) |
| (1,275) |
| - |
| 384 |
| - |
| (5,749) |
Income (loss) before taxes |
| 8,514 |
| 1,363 |
| 7,032 |
| 2,267 |
| (123) |
| - |
| 19,053 |
Income tax (provision) benefit |
| (638) |
| (412) |
| (1,916) |
| (619) |
| 80 |
| - |
| (3,505) |
Net income (loss) | $ | 7,876 | $ | 951 | $ | 5,116 | $ | 1,648 | $ | (43) | $ | - | $ | 15,548 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2018 |
|
|
|
|
|
|
|
|
|
|
|
| ||
Operating revenues | $ | 99,067 | $ | 24,980 | $ | 215 | $ | - | $ | - | $ | - | $ | 124,262 |
Interdepartmental revenues |
| (245) |
| 3,493 |
| 9,847 |
| - |
| - |
| (13,095) |
| - |
Total operating revenues |
| 98,822 |
| 28,473 |
| 10,062 |
| - |
| - |
| (13,095) |
| 124,262 |
Depreciation and amortization |
| (9,575) |
| (2,445) |
| (1,852) |
| - |
| - |
| - |
| (13,872) |
Other operating expenses |
| (74,535) |
| (24,232) |
| (34) |
| (5) |
| (448) |
| 13,095 |
| (86,159) |
Operating income (loss) |
| 14,712 |
| 1,796 |
| 8,176 |
| (5) |
| (448) |
| - |
| 24,231 |
Other income, net |
| 1,562 |
| 752 |
| - |
| 1,916 |
| 501 |
| - |
| 4,731 |
Interest (expense) income, net |
| (2,952) |
| (887) |
| (1,334) |
| - |
| 390 |
| - |
| (4,783) |
Income before taxes |
| 13,322 |
| 1,661 |
| 6,842 |
| 1,911 |
| 443 |
| - |
| 24,179 |
Income tax provision |
| (2,986) |
| (372) |
| (1,864) |
| (522) |
| (84) |
| - |
| (5,828) |
Net income | $ | 10,336 | $ | 1,289 | $ | 4,978 | $ | 1,389 | $ | 359 | $ | - | $ | 18,351 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2019 |
|
|
|
|
|
|
|
|
|
|
|
| ||
Operating revenues | $ | 194,279 | $ | 95,170 | $ | 267 | $ | - | $ | - | $ | - | $ | 289,716 |
Interdepartmental revenues |
| 397 |
| 6,891 |
| 19,968 |
| - |
| - |
| (27,256) |
| - |
Total operating revenues |
| 194,676 |
| 102,061 |
| 20,235 |
| - |
| - |
| (27,256) |
| 289,716 |
Depreciation and amortization |
| (25,888) |
| (5,603) |
| (3,739) |
| - |
| - |
| - |
| (35,230) |
Other operating expenses |
| (146,424) |
| (84,369) |
| (81) |
| - |
| (575) |
| 27,256 |
| (204,193) |
Operating income (loss) |
| 22,364 |
| 12,089 |
| 16,415 |
| - |
| (575) |
| - |
| 50,293 |
Other income, net |
| 3,441 |
| 1,724 |
| - |
| 4,436 |
| 269 |
| - |
| 9,870 |
Interest (expense) income, net |
| (7,491) |
| (2,072) |
| (2,565) |
| - |
| 732 |
| - |
| (11,396) |
Income before taxes |
| 18,314 |
| 11,741 |
| 13,850 |
| 4,436 |
| 426 |
| - |
| 48,767 |
Income tax provision |
| (1,088) |
| (3,031) |
| (3,773) |
| (1,210) |
| (111) |
| - |
| (9,213) |
Net income | $ | 17,226 | $ | 8,710 | $ | 10,077 | $ | 3,226 | $ | 315 | $ | - | $ | 39,554 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended June 30, 2018 |
|
|
|
|
|
|
|
|
|
|
|
| ||
Operating revenues | $ | 193,458 | $ | 87,745 | $ | 691 | $ | - | $ | - | $ | - | $ | 281,894 |
Interdepartmental revenues |
| (214) |
| 7,840 |
| 19,667 |
| - |
| - |
| (27,293) |
| - |
Total operating revenues |
| 193,244 |
| 95,585 |
| 20,358 |
| - |
| - |
| (27,293) |
| 281,894 |
Depreciation and amortization |
| (18,953) |
| (4,840) |
| (3,702) |
| - |
| - |
| - |
| (27,495) |
Other operating expenses |
| (151,110) |
| (79,427) |
| (77) |
| (8) |
| (651) |
| 27,293 |
| (203,980) |
Operating income (loss) |
| 23,181 |
| 11,318 |
| 16,579 |
| (8) |
| (651) |
| - |
| 50,419 |
Other income, net |
| 3,292 |
| 1,518 |
| - |
| 4,288 |
| 552 |
| - |
| 9,650 |
Interest (expense) income, net |
| (5,819) |
| (1,726) |
| (2,682) |
| - |
| 705 |
| - |
| (9,522) |
Income before taxes |
| 20,654 |
| 11,110 |
| 13,897 |
| 4,280 |
| 606 |
| - |
| 50,547 |
Income tax provision |
| (4,186) |
| (2,830) |
| (3,786) |
| (1,170) |
| (223) |
| - |
| (12,195) |
Net income | $ | 16,468 | $ | 8,280 | $ | 10,111 | $ | 3,110 | $ | 383 | $ | - | $ | 38,352 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
30
The following tables show segment information for MGE's operations for the indicated periods:
(In thousands) MGE |
| Electric |
| Gas |
| Nonregulated Energy |
| Consolidation/ Elimination Entries |
| Consolidated Total |
|
| Electric |
| Gas |
| Non-regulated Energy |
| Consolidation/ Elimination Entries |
| Consolidated Total |
|
Three Months Ended September 30, 2018 |
|
|
|
|
|
|
|
|
|
| ||||||||||||
Three Months Ended June 30, 2019 | Three Months Ended June 30, 2019 |
|
|
|
|
|
|
|
|
|
| |||||||||||
Operating revenues | $ | 119,175 | $ | 18,407 | $ | 213 | $ | - | $ | 137,795 |
| $ | 96,863 | $ | 25,070 | $ | 214 | $ | - | $ | 122,147 |
|
Interdepartmental revenues |
| (20) |
| 4,219 |
| 9,912 |
| (14,111) |
| - |
|
| 198 |
| 1,929 |
| 9,995 |
| (12,122) |
| - |
|
Total operating revenues |
| 119,155 |
| 22,626 |
| 10,125 |
| (14,111) |
| 137,795 |
|
| 97,061 |
| 26,999 |
| 10,209 |
| (12,122) |
| 122,147 |
|
Depreciation and amortization |
| (9,864) |
| (2,534) |
| (1,861) |
| - |
| (14,259) |
|
| (13,379) |
| (2,843) |
| (1,869) |
| - |
| (18,091) |
|
Other operating expenses(b) |
| (85,127) |
| (19,739) |
| (1,888) |
| 14,111 |
| (92,643) |
| |||||||||||
Operating income(b) |
| 24,164 |
| 353 |
| 6,376 |
| - |
| 30,893 |
| |||||||||||
Other income, net(b) |
| 1,737 |
| 786 |
| - |
| - |
| 2,523 |
| |||||||||||
Other operating expenses |
| (73,130) |
| (22,931) |
| (33) |
| 12,122 |
| (83,972) |
| |||||||||||
Operating income |
| 10,552 |
| 1,225 |
| 8,307 |
| - |
| 20,084 |
| |||||||||||
Other income, net |
| 1,788 |
| 1,170 |
| - |
| - |
| 2,958 |
| |||||||||||
Interest expense, net |
| (3,217) |
| (963) |
| (1,320) |
| - |
| (5,500) |
|
| (3,826) |
| (1,032) |
| (1,275) |
| - |
| (6,133) |
|
Income before taxes |
| 8,514 |
| 1,363 |
| 7,032 |
| - |
| 16,909 |
| |||||||||||
Income tax provision |
| (638) |
| (412) |
| (1,916) |
| - |
| (2,966) |
| |||||||||||
Net income |
| 22,684 |
| 176 |
| 5,056 |
| - |
| 27,916 |
|
| 7,876 |
| 951 |
| 5,116 |
| - |
| 13,943 |
|
Less: Net income attributable to |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest, net of tax |
| - |
| - |
| - |
| (5,629) |
| (5,629) |
|
| - |
| - |
| - |
| (5,621) |
| (5,621) |
|
Net income attributable to MGE | $ | 22,684 | $ | 176 | $ | 5,056 | $ | (5,629) | $ | 22,287 |
| $ | 7,876 | $ | 951 | $ | 5,116 | $ | (5,621) | $ | 8,322 |
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||||
Three Months Ended September 30, 2017 |
|
|
|
|
|
|
|
|
|
| ||||||||||||
Three Months Ended June 30, 2018 | Three Months Ended June 30, 2018 |
|
|
|
|
|
|
|
|
|
| |||||||||||
Operating revenues | $ | 120,648 | $ | 18,779 | $ | 112 | $ | - | $ | 139,539 |
| $ | 99,067 | $ | 24,980 | $ | 215 | $ | - | $ | 124,262 |
|
Interdepartmental revenues |
| (109) |
| 3,891 |
| 11,130 |
| (14,912) |
| - |
|
| (245) |
| 3,493 |
| 9,847 |
| (13,095) |
| - |
|
Total operating revenues |
| 120,539 |
| 22,670 |
| 11,242 |
| (14,912) |
| 139,539 |
|
| 98,822 |
| 28,473 |
| 10,062 |
| (13,095) |
| 124,262 |
|
Depreciation and amortization |
| (9,256) |
| (2,258) |
| (1,858) |
| - |
| (13,372) |
|
| (9,575) |
| (2,445) |
| (1,852) |
| - |
| (13,872) |
|
Other operating expenses(a), (b) |
| (90,164) |
| (19,529) |
| (3,246) |
| 14,912 |
| (98,027) |
| |||||||||||
Operating income(b) |
| 21,119 |
| 883 |
| 6,138 |
| - |
| 28,140 |
| |||||||||||
Other income, net(a), (b) |
| 1,543 |
| 596 |
| - |
| - |
| 2,139 |
| |||||||||||
Other operating expenses |
| (74,535) |
| (24,232) |
| (35) |
| 13,095 |
| (85,707) |
| |||||||||||
Operating income |
| 14,712 |
| 1,796 |
| 8,175 |
| - |
| 24,683 |
| |||||||||||
Other income, net |
| 1,561 |
| 753 |
| - |
| - |
| 2,314 |
| |||||||||||
Interest expense, net |
| (2,760) |
| (795) |
| (1,371) |
| - |
| (4,926) |
|
| (2,952) |
| (887) |
| (1,334) |
| - |
| (5,173) |
|
Income before taxes |
| 13,321 |
| 1,662 |
| 6,841 |
| - |
| 21,824 |
| |||||||||||
Income tax provision |
| (2,985) |
| (373) |
| (1,863) |
| - |
| (5,221) |
| |||||||||||
Net income |
| 19,902 |
| 684 |
| 4,767 |
| - |
| 25,353 |
|
| 10,336 |
| 1,289 |
| 4,978 |
| - |
| 16,603 |
|
Less: Net income attributable to |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest, net of tax |
| - |
| - |
| - |
| (5,439) |
| (5,439) |
|
| - |
| - |
| - |
| (5,505) |
| (5,505) |
|
Net income attributable to MGE | $ | 19,902 | $ | 684 | $ | 4,767 | $ | (5,439) | $ | 19,914 |
| $ | 10,336 | $ | 1,289 | $ | 4,978 | $ | (5,505) | $ | 11,098 |
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||||
Nine Months Ended September 30, 2018 |
|
|
|
|
|
|
|
|
|
| ||||||||||||
Six Months Ended June 30, 2019 | Six Months Ended June 30, 2019 |
|
|
|
|
|
|
|
|
|
| |||||||||||
Operating revenues | $ | 312,633 | $ | 106,152 | $ | 904 | $ | - | $ | 419,689 |
| $ | 194,279 | $ | 95,170 | $ | 267 | $ | - | $ | 289,716 |
|
Interdepartmental revenues |
| (234) |
| 12,059 |
| 29,579 |
| (41,404) |
| - |
|
| 397 |
| 6,891 |
| 19,968 |
| (27,256) |
| - |
|
Total operating revenues |
| 312,399 |
| 118,211 |
| 30,483 |
| (41,404) |
| 419,689 |
|
| 194,676 |
| 102,061 |
| 20,235 |
| (27,256) |
| 289,716 |
|
Depreciation and amortization |
| (28,817) |
| (7,374) |
| (5,563) |
| - |
| (41,754) |
|
| (25,888) |
| (5,603) |
| (3,739) |
| - |
| (35,230) |
|
Other operating expenses(b) |
| (240,333) |
| (101,938) |
| (5,751) |
| 41,404 |
| (306,618) |
| |||||||||||
Operating income(b) |
| 43,249 |
| 8,899 |
| 19,169 |
| - |
| 71,317 |
| |||||||||||
Other income, net(b) |
| 4,939 |
| 2,246 |
| - |
| - |
| 7,185 |
| |||||||||||
Other operating expenses |
| (146,424) |
| (84,369) |
| (81) |
| 27,256 |
| (203,618) |
| |||||||||||
Operating income |
| 22,364 |
| 12,089 |
| 16,415 |
| - |
| 50,868 |
| |||||||||||
Other income, net |
| 3,441 |
| 1,724 |
| - |
| - |
| 5,165 |
| |||||||||||
Interest expense, net |
| (9,036) |
| (2,689) |
| (4,002) |
| - |
| (15,727) |
|
| (7,491) |
| (2,072) |
| (2,565) |
| - |
| (12,128) |
|
Income before taxes |
| 18,314 |
| 11,741 |
| 13,850 |
| - |
| 43,905 |
| |||||||||||
Income tax provision |
| (1,088) |
| (3,031) |
| (3,773) |
| - |
| (7,892) |
| |||||||||||
Net income |
| 39,152 |
| 8,456 |
| 15,167 |
| - |
| 62,775 |
|
| 17,226 |
| 8,710 |
| 10,077 |
| - |
| 36,013 |
|
Less: Net income attributable to |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest, net of tax |
| - |
| - |
| - |
| (16,940) |
| (16,940) |
|
| - |
| - |
| - |
| (11,111) |
| (11,111) |
|
Net income attributable to MGE | $ | 39,152 | $ | 8,456 | $ | 15,167 | $ | (16,940) | $ | 45,835 |
| $ | 17,226 | $ | 8,710 | $ | 10,077 | $ | (11,111) | $ | 24,902 |
|
|
|
|
|
|
|
|
|
|
|
|
| |||||||||||
Nine Months Ended September 30, 2017 |
|
|
|
|
|
|
|
|
|
| ||||||||||||
Six Months Ended June 30, 2018 | Six Months Ended June 30, 2018 |
|
|
|
|
|
|
|
|
|
| |||||||||||
Operating revenues | $ | 321,282 | $ | 101,294 | $ | 261 | $ | - | $ | 422,837 |
| $ | 193,458 | $ | 87,745 | $ | 691 | $ | - | $ | 281,894 |
|
Interdepartmental revenues |
| (337) |
| 11,699 |
| 33,307 |
| (44,669) |
| - |
|
| (214) |
| 7,840 |
| 19,667 |
| (27,293) |
| - |
|
Total operating revenues |
| 320,945 |
| 112,993 |
| 33,568 |
| (44,669) |
| 422,837 |
|
| 193,244 |
| 95,585 |
| 20,358 |
| (27,293) |
| 281,894 |
|
Depreciation and amortization |
| (27,341) |
| (6,703) |
| (5,562) |
| - |
| (39,606) |
|
| (18,953) |
| (4,840) |
| (3,702) |
| - |
| (27,495) |
|
Other operating expenses(a), (b) |
| (251,879) |
| (98,227) |
| (9,658) |
| 44,669 |
| (315,095) |
| |||||||||||
Operating income(b) |
| 41,725 |
| 8,063 |
| 18,348 |
| - |
| 68,136 |
| |||||||||||
Other income, net(a), (b) |
| 3,120 |
| 1,336 |
| - |
| - |
| 4,456 |
| |||||||||||
Other operating expenses |
| (151,110) |
| (79,427) |
| (78) |
| 27,293 |
| (203,322) |
| |||||||||||
Operating income |
| 23,181 |
| 11,318 |
| 16,578 |
| - |
| 51,077 |
| |||||||||||
Other income, net |
| 3,292 |
| 1,519 |
| - |
| - |
| 4,811 |
| |||||||||||
Interest expense, net |
| (8,337) |
| (2,399) |
| (4,170) |
| - |
| (14,906) |
|
| (5,819) |
| (1,726) |
| (2,682) |
| - |
| (10,227) |
|
Income before taxes |
| 20,654 |
| 11,111 |
| 13,896 |
| - |
| 45,661 |
| |||||||||||
Income tax provision |
| (4,186) |
| (2,831) |
| (3,785) |
| - |
| (10,802) |
| |||||||||||
Net income |
| 36,508 |
| 7,000 |
| 14,178 |
| - |
| 57,686 |
|
| 16,468 |
| 8,280 |
| 10,111 |
| - |
| 34,859 |
|
Less: Net income attributable to |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
noncontrolling interest, net of tax |
| - |
| - |
| - |
| (16,224) |
| (16,224) |
|
| - |
| - |
| - |
| (11,311) |
| (11,311) |
|
Net income attributable to MGE | $ | 36,508 | $ | 7,000 | $ | 14,178 | $ | (16,224) | $ | 41,462 |
| $ | 16,468 | $ | 8,280 | $ | 10,111 | $ | (11,311) | $ | 23,548 |
|
(a)
Reflects retrospective application of new accounting pronouncement related to pension and other postretirement benefits, see Footnote 2 for further information.
(b)
Amounts are shown net of the related tax expense, consistent with the presentation on the MGE Consolidated Statements of Income.
|
The following table shows segment information for assets and capital expenditures:
31
|
| Utility |
|
| Consolidated | ||||||||||||
(In thousands) MGE Energy |
| Electric |
| Gas |
| Assets not Allocated |
|
| Non-regulated Energy |
| Transmission Investment |
| All Others |
| Consolidation/ Elimination Entries |
| Total |
Assets: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
September 30, 2018 | $ | 1,141,370 | $ | 345,349 | $ | 64,016 |
| $ | 264,735 | $ | 64,722 | $ | 472,740 | $ | (378,635) | $ | 1,974,297 |
December 31, 2017 |
| 1,043,181 |
| 344,337 |
| 26,345 |
|
| 270,384 |
| 61,783 |
| 485,548 |
| (376,396) |
| 1,855,182 |
Capital Expenditures: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nine Months Ended Sept. 30, 2018 | $ | 122,108 | $ | 22,406 | $ | - |
| $ | 4,487 | $ | - | $ | - | $ | - | $ | 149,001 |
Year ended Dec. 31, 2017 |
| 77,353 |
| 26,847 |
| - |
|
| 3,931 |
| - |
| - |
| - |
| 108,131 |
|
The following table shows segment information for assets and capital expenditures: | |||||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| Utility |
|
| Consolidated | ||||||||||
(In thousands) MGE Energy |
| Electric |
| Gas |
|
| Non-regulated Energy |
| Transmission Investment |
| All Others |
| Consolidation/ Elimination Entries |
| Total |
Assets: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30, 2019 | $ | 1,250,755 | $ | 369,467 |
| $ | 261,707 | $ | 68,350 | $ | 453,604 | $ | (377,797) | $ | 2,026,086 |
December 31, 2018 |
| 1,193,083 |
| 377,005 |
|
| 265,301 |
| 66,366 |
| 465,661 |
| (378,798) |
| 1,988,618 |
Capital Expenditures: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six months ended June 30, 2019 | $ | 62,281 | $ | 15,028 |
| $ | 1,783 | $ | - | $ | - | $ | - | $ | 79,092 |
Year ended Dec. 31, 2018 |
| 176,399 |
| 30,497 |
|
| 5,301 |
| - |
| - |
| - |
| 212,197 |
|
| Utility |
|
| Consolidated | ||||||
(In thousands) MGE |
| Electric |
| Gas |
|
| Non-regulated Energy |
| Elimination Entries |
| Total |
Assets: |
|
|
|
|
|
|
|
|
|
|
|
June 30, 2019 | $ | 1,250,755 | $ | 369,467 |
| $ | 261,657 | $ | (213) | $ | 1,881,666 |
December 31, 2018 |
| 1,193,083 |
| 377,005 |
|
| 265,251 |
| (448) |
| 1,834,891 |
Capital Expenditures: |
|
|
|
|
|
|
|
|
|
|
|
Six months ended June 30, 2019 | $ | 62,281 | $ | 15,028 |
| $ | 1,783 | $ | - | $ | 79,092 |
Year ended Dec. 31, 2018 |
| 176,399 |
| 30,497 |
|
| 5,301 |
| - |
| 212,197 |
32
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.
General
MGE Energy is an investor-owned public utility holding company operating through subsidiaries in five business segments:
·
Regulated electric utility operations, conducted through MGE,
·
Regulated gas utility operations, conducted through MGE,
·
Nonregulated energy operations, conducted through MGE Power and its subsidiaries,
·
Transmission investments, representing our equity investment in ATC and ATC Holdco, and
·
All other, which includes corporate operations and services.
Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates and distributes electricity to approximately 151,000153,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 158,000161,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.
Our nonregulated energy operations own interests in electric generating capacity that is leased to MGE. The ownership/leasing structure was adopted under applicable state regulatory guidelines for MGE's participation in these generation facilities, consisting principally of a stable return on the equity investment in the new generation facilities over the term of the related leases. The nonregulated energy operations include an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin and a partial ownership of a cogeneration project on the UW-Madison campus. A third party operates the units in Oak Creek, and MGE operates the cogeneration project. Due to the nature of MGE's participation in these facilities, the results of MGE Energy's nonregulated operations are also consolidated into MGE's consolidated financial position and results of operations under applicable accounting standards.
Executive Overview
Our primary focus today and for the foreseeable future is our core utility customers at MGE as well as creating long-term value for our shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE meets this challenge by investing in more efficient generation projects, including renewable energy sources. MGE continues to examine and pursue opportunities to reduce the proportion that coal generation represents in its generation mix, including the reduction in its ownership of Columbia and its growing ownership of renewable generation sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE maintains safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit standing consistent with financial strength in MGE as well as the parent company in order to accomplish these goals.
We earn our revenue and generate cash from operations by providing electric and natural gas utility services, including electric power generation and electric power and gas distribution. The earnings and cash flows from the utility business are sensitive to various external factors, including:
·
Weather, and its impact on customer sales,
·
Economic conditions, including current business activity and employment and their impact on customer demand,
·
Regulation and regulatory issues, and their impact on the timing and recovery of costs,
·
Energy commodity prices, including natural gas prices,
·
Equity price risk pertaining to pension related assets,
·
Credit market conditions, including interest rates and our debt credit rating,
·
Environmental laws and regulations, including adopted and pending environmental rule changes, and
·
Other factors listed in "Item 1A. Risk Factors" in our 20172018 Annual Report on Form 10-K.
33
For the three months ended SeptemberJune 30, 2018,2019, MGE Energy's earnings were $29.5$15.5 million or $0.85$0.45 per share compared to $26.6$18.4 million or $0.77$0.53 per share for the same period in the prior year. MGE's earnings for the three months ended SeptemberJune 30, 2018,2019, were $22.3$8.3 million compared to $19.9$11.1 million for the same period in the prior year.
|
For the ninesix months ended SeptemberJune 30, 2018,2019, MGE Energy's earnings were $67.9$39.6 million or $1.96$1.14 per share compared to $61.5$38.4 million or $1.77$1.11 per share for the same period in the prior year. MGE's earnings for the ninesix months ended SeptemberJune 30, 2018,2019, were $45.8$24.9 million compared to $41.5$23.5 million for the same period in the prior year.
MGE Energy's net income was derived from our business segments as follows:
|
|
| Three Months Ended |
| Nine Months Ended |
| ||||
| (In millions) |
| September 30, |
| September 30, |
| ||||
| Business Segment: |
| 2018 |
| 2017 |
| 2018 |
| 2017 |
|
| Electric Utility | $ | 22.6 | $ | 19.9 | $ | 39.1 | $ | 36.5 |
|
| Gas Utility |
| 0.2 |
| 0.7 |
| 8.5 |
| 7.0 |
|
| Nonregulated Energy |
| 5.1 |
| 4.8 |
| 15.2 |
| 14.2 |
|
| Transmission Investments |
| 1.2 |
| 1.3 |
| 4.3 |
| 4.3 |
|
| All Other |
| 0.4 |
| (0.1) |
| 0.8 |
| (0.5) |
|
| Net Income | $ | 29.5 | $ | 26.6 | $ | 67.9 | $ | 61.5 |
|
|
|
| Three Months Ended |
| Six Months Ended |
| ||||
| (In millions) |
| June 30, |
| June 30, |
| ||||
| Business Segment: |
| 2019 |
| 2018 |
| 2019 |
| 2018 |
|
| Electric Utility | $ | 7.9 | $ | 10.3 | $ | 17.2 | $ | 16.5 |
|
| Gas Utility |
| 0.9 |
| 1.3 |
| 8.7 |
| 8.3 |
|
| Nonregulated Energy |
| 5.1 |
| 5.0 |
| 10.1 |
| 10.1 |
|
| Transmission Investments |
| 1.6 |
| 1.4 |
| 3.3 |
| 3.1 |
|
| All Other |
| - |
| 0.4 |
| 0.3 |
| 0.4 |
|
| Net Income | $ | 15.5 | $ | 18.4 | $ | 39.6 | $ | 38.4 |
|
Our net income during the three and ninesix months ended SeptemberJune 30, 2018,2019, compared to the same period in the prior year primarily reflects the effects of the following factors:
Electric Utility
ForAn increase in owned generation assets included in rate base contributed to increased earnings for the three and ninesix months ended SeptemberJune 30, 2018, electric operating income increased primarily2019, as a result of more favorablethe completion of the Saratoga Wind Farm. Earnings from electric retail sales decreased reflecting lower customer demand resulting from cooler weather conditionsexperienced in June compared to the same period in the currentprior year. The average temperature in August 2018 was 72 degrees compared to 67 degrees in August 2017.
Gas Utility
For the ninethree months ended SeptemberJune 30, 2018,2019, gas operating income decreased primarily related to a decrease in gas retail sales resulting from cooler weather in April 2018. For the six months ended June 30, 2019, gas operating income increased primarily related to an increase in gas retail sales reflecting higher customer demand resulting from colder weather experienced in April 2018during the first quarter compared to the same period in the prior year and an increase in retail customers. The average temperatureHeating degree days (a measure for determining the impact of weather during the heating season) increased by 7.3% in April 2018 was 38 degreesthe first quarter compared to 50 degreesthe comparable period in April 2017. For the three months ended September 30, 2018, gas operating income was relatively flat.prior year.
During the first ninesix months of 2018,2019, the following events occurred:
2019/2020 Rate Settlement: In December 2018, the PSCW approved the settlement agreement between MGE and intervening parties in the rate case. The settlement decreases electric rates by 2.24% or $9.2 million in 2019. MGE will maintain this rate level for 2020, with the exception that MGE will file a 2020 Fuel Cost Plan in 2019 and MGE's electric rates will be adjusted accordingly. The decrease reflects the ongoing tax impacts of the Tax Reform: OnAct. Lower fuel costs and increase in rate base from renewable generation assets are additional items impacting the rate change. The settlement agreement increases gas rates by 1.06% or $1.7 million in 2019 and 1.46% or $2.4 million in 2020. The increase covers infrastructure costs. It also reflects the impacts of the Tax Act.
Pension and Other Postretirement Benefit Costs: Costs for pension and other postretirement benefits are affected by actual investment returns on the assets held for those benefits and by the discount rate, which is sensitive to interest rates, used to calculate those benefits. Volatility in interest rates and investment returns could affect the value of the pension and postretirement benefit obligations. These changes may affect benefit costs in future years. As a result of lower investment returns in the fourth quarter of 2018, pension and postretirement benefit costs increased in 2019. In July 2019, the PSCW approved MGE’s request to defer the difference between estimated pension and other postretirement costs included in the 2019 and 2020 rate settlement and actual expense incurred up to $5.9 million. MGE expects that the deferred cost for employee benefit plans will be factored into future rate actions starting in 2021. For the three and six months ended June 30, 2019, MGE has deferred approximately $3 million of pension and other postretirement costs.
34
Saratoga Wind Farm: In December 22, 2017, the U.S. government enacted comprehensivePSCW authorized construction of a 66 MW wind farm, consisting of 33 turbines, located near Saratoga, Iowa. Construction of the project was completed in February 2019 for approximately $112 million. MGE received specific approval to recover 100% AFUDC on the project. After tax, legislation commonly referredMGE has recognized $0.8 million in AFUDC equity related to asthis project for the Tax Cutsthree and Jobs Act. The Tax Act makes broadsix months ended June 30,2019.
Columbia: MGE and complex changesWPL negotiated an amendment to the U.S. tax code, including the reduction in the U.S. federal corporate tax rate from 35 to 21 percent,existing Columbia joint operating agreement, effective January 1, 2018.2017, under which MGE reduced its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. On January 1 of each year from 2017 through 2019 and then on June 1, 2020, the ownership percentage is adjusted through a partial sale based on the amount of capital expenditures foregone. As of December 31, 2018, MGE classified $3.1 million of Columbia assets as held-for-sale on the consolidated balance sheets. In January 2019, MGE reduced its ownership interest in Columbia from 19.4% to 19.1% as a result of the partial sale of plant assets to WPL.
Utility Solar – Two Creeks: In May 2019, MGE a acquired a 33% ownership interest in a 150 MW solar generation array in the Town of Two Creeks and the City of Two Rivers in Manitowoc and Kewanee Counties, Wisconsin. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility, which is being constructed. The estimated share of capital costs for that ownership interest is approximately $65 million (excluding capitalized interest). As of June 30, 2019, $16.5 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.
Utility Solar – Badger Hollow: In July 2019, MGE a acquired a 33% ownership interest in a 150 MW solar generation array in southwestern Wisconsin in Iowa County, near the villages of Montfort and Cobb. MGE's sole principal asset will be the 33% undivided ownership interest in the solar generation facility which is being constructed. The estimated share of capital costs for that ownership interest is approximately $65 million (excluding capitalized interest). As of June 30, 2019, $1.0 million (excluding capitalized interest) related to this project is reflected in "Construction work in progress" on the consolidated balance sheets. The project is anticipated to be completed by the end of 2020.
In the near term, several items may affect us, including:
2018 Annual Fuel Proceeding: In July 2019, the PSCW issued a final decision in the 2018 fuel rules proceedings for MGE to refund additional fuel savings incurred to its retail electric customers over a one-month period. MGE will return $9.5 million plus accrued interest in October 2019. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred as of December 31, 2018.
2018 Tax Reform: Customer rates approved for 2018 reflect an income tax rate of 35 percent. In January 2018, the PSCW issued an order directing Wisconsin investor-owned utilities to defer the over-collection of income tax expense as a result of the decrease in tax rate to 21 percent. The PSCW issued an order in May 2018 to return to customers the estimated 2018 over-collection of income tax expense. As of September 30, 2018, MGE returned $5.9 million to customers through bill credits. Any over/under recovery of the actual costs will be subject to the PSCW's review in a future rate case. As of September 30,December 31, 2018, MGE has deferred $2.6$3.1 million as a regulatory liability and recorded a corresponding reduction in operating revenues for over-collection of income tax expense (net of customer bill credits).
Saratoga Wind Farm: In December 2017, the PSCW authorized construction of a 66MW wind farm, consisting of 33 turbines, located near Saratoga, Iowa. MGE received specific approval The amount to recover 100% AFUDC on the project. As of September 30, 2018, MGE has incurred $66.5 million of capital expenditures. After tax, MGE has recognized $0.6 million and $1.3 million, respectively, in AFUDC equity related to this project for the three and nine months ended September 30, 2018. Construction of the project is expected to be completed by early 2019, with an estimated capital cost of $108 million.
Forward Wind: In April 2018, MGE, along with two other utilities, purchased the Forward Wind Energy Center, which consists of 86 wind turbines located in Wisconsin with a total capacity of 129 MWs. The aggregate purchase price was approximately $174 million of which MGE's proportionate share is 12.8%, or approximately $23 million. The purchase of the Forward Wind Energy Center replaced an existing purchase power agreement, under which MGE purchased 12.8% of the facility's energy output.
|
Columbia: MGE and WPL have negotiated an amendment to the existing Columbia joint operating agreement, effective January 1, 2017, under which MGE has reduced its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. On January 1 of each year from 2017 through 2019 and then on June 1, 2020, the ownership percentage is adjusted through a partial sale based on the amount of capital expenditures foregone. As of September 30, 2018, and December 31, 2017, MGE classified $1.8 million and $8.8 million, respectively, of Columbia assets as held-for-sale on the consolidated balance sheets. In January 2018, MGE reduced its ownership interest in Columbia from 20.4% to 19.4% as a result of the partial sale of plant assets to WPL.
Deferred Fuel Costs – Subject to Refund: As of September 30, 2018, MGE has deferred $7.2 million of 2018 fuel savings. These costs will be subject to the PSCW's annual review of 2018 fuel costs, expected to be completed in 2019.
Debt Issuance: MGE issued $40 million of long-term unsecured debt in July 2018 and $60 million of long-term unsecured debt in September 2018. The proceeds of these debt financings were used to assist with the financing of additional capital expenditures, such as the Saratoga Wind Farm, and refinanced $20 million of long-term debt that matured in September 2018. The covenants of these debt issues are substantially consistent with MGE's existing unsecured long-term debt.
In the near term, several items may affect us, including:
2017 Annual Fuel Proceeding: In August 2018, the PSCW issued a final decision in the fuel rules proceedings for MGE to refund $4.2 million of additional fuel savings realized during 2017 to its retail electric customers over a one-month period in October 2018. There was no change to the refund in the fuel rules proceedings from the amount MGE deferred as of December 31, 2017.
2019/2020 Rate Change Settlement: In July 2018, MGE filed an application with the PSCW to adjust electric and gas rates for 2019 and 2020. MGE filed its application through a settlement agreement between MGE and intervening parties in the rate case, subject to PSCW approval. The settlement proposal would decrease electric rates by 1.94% in 2019. This amountreturn is subject to change based on the final outcome of MGE's 2019 Fuel Cost Plan. MGE will maintain this rate level for 2020, with the exception that MGE will file a 2020 Fuel Cost PlanPSCW's review, expected to occur in 2019 and MGE's electric rates will be adjusted accordingly. The decrease reflects the ongoing tax impacts of the Tax Act and the addition of lower-cost renewable generation capacity. The settlement agreement increases gas rates by 1.06% in 2019 and 1.46% in 2020. The requested increase covers infrastructure costs. It also reflects the impacts of the Tax Act.2019.
Tax Reform: Pursuant to the Tax Act, deferred income tax balances as of December 31, 2017, were remeasured to reflect the decrease in corporate tax rate. A $130.5 million regulatory liability was recorded given that changes in income taxes are generally passed through in customer rates for the regulated utility. The amount and timing of the cash impacts will depend on the period over which certain income tax benefits are provided to customers, which will be determined by the PSCW. A portion of the regulatory liability will beis being returned to customers using a normalization method of accounting.
ATC Return on Equity: Several parties have filed complaints with the FERC seeking to reduce the ROE used by MISO transmission owners, including ATC. Any change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future. We derived approximately 6.3%8.0% and 7.2%7.5% of our net income for the ninesix months ended SeptemberJune 30, 20182019 and 2017,2018, respectively, from our investment in ATC. See "Other Matters" below for
35
additional information concerning ATC.
Environmental Initiatives: There are proposed legislative rules and initiatives involving matters related to air emissions, water effluent, hazardous materials, and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. At present, it is unclear how the changes in the Presidential and EPA administrations may affect existing, pending or new legislative or rulemaking proposals or regulatory initiatives. Such legislation and rulemaking could significantly affect the costs of owning and operating fossil-fueled generating plants, such as Columbia and the Elm Road Units, from which we derive approximately 42%43% of our electric generating capacity as of SeptemberJune 30, 2018.2019. We would expect to seek and receive recovery of any such costs in rates; however, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates, which may lag the incurrence of those costs.
|
EPA's Greenhouse Gas (GHG) Rule UnderClean Power Plan and Affordable Clean Energy Rule: In 2015, the EPA finalized the Clean Air Act:Power Plan (CPP), which directed states to submit plans to reduce GHG emissions from the electric generation sector. Implementation of the rule is currently stayed by order to the U.S. Supreme Court. If ultimately upheld, the CPP could have a material effect on MGE’s operations. In August 2018,July 2019, the EPA proposedpublished a final rule which repeals the CPP and creates the replacement Affordable Clean Energy (ACE) rule for states to use to develop plans to control GHGreduce greenhouse gas emissions from existing fossil fuel-fired electric generating units (EGUs).EGUs. The proposed rule appliesACE Rule will apply to EGUs greater than 25 MW in size with exemptions for simple cycleColumbia and combined cycle generators. It has the potential to impact our Blount Generating Station, Columbia Power Plant, and Elm Road Units. The ACE proposedMGE is currently evaluating how this rule directs states to submit implementation plans tomay impact operations. Until the EPA for approval that implement standardsState of performance (referred to as Best System of Emissions Reductions, or BSER) for individual EGUs. If a state fails to prepareWisconsin develops a plan or their planthat is not approvedaccepted by the EPA, a federal implementation plan (FIP)MGE will not be issued for that state. The ACE has been designed as a replacementable to determine the EPA's Clean Power Plan (CPP), which also regulated GHGs. The EPA finalized the CPP in 2015. In February 2016, the U.S. Supreme Court stayed implementationfinal impact of the CPP and the stay remains in effect. In October 2017, the EPA issued a proposed rule to repeal the CPP.rule. MGE will continue to evaluate the rule and monitor developmentsongoing and potential legal proceedings associated with the proposedCPP and ACE rule and CPP rule and litigation. The ACE rule is not final, and we are still evaluating the potential impacts. It is difficult to say with any certainty how the ACE will affect our operations. MGE previously determined that if the CPP were to be implemented in its present form, it would have a material impact on MGE.rules.
Columbia: MGE will reduce further its obligation to pay certain capital expenditures (other than SCR-related expenditures) at Columbia in exchange for a proportional reduction in MGE's ownership in Columbia. By June 2020, MGE's ownership in Columbia is forecasted to be approximately 19%, a decrease of 3% from the 22% ownership interest held by MGE on January 1, 2016.
Future Generation - Riverside: During the first quarter ofIn 2016, MGE entered into an agreement with WPL under which MGE may acquire up to 50 MW of capacity in a gas-fired generating plant to be constructed by WPL at its Riverside Energy Center in Beloit, Wisconsin, during the five-year period following the in-service date of the plant. The plant is expected to be completed by early 2020. MGE has not yet determined whether it will exercise its option in the Riverside plant. A determination will be made based on a variety of factors in future years.
Future Generation -– Utility Solar: In May 2018,August 2019, MGE and Wisconsin Public Service CorporationWEPCO filed a joint application with the PSCW to seekfor the approval to acquire 300150 MW of solar generating capacity from two largefor a solar projectsproject in Wisconsin.Wisconsin, Badger Hollow Solar Farm II. MGE's combined ownership share of the two projectsproject is expected to be 10050 MW. If approved by the PSCW, construction of the projectsproject is expected to begin in 2019.2020. MGE's share of the totalconstruction cost is expected to be approximately $130$65 million.
Financing Plans: MGE has regulatory authority to issue up to $50 million of new long-term debt to finance authorized utility capital expenditures, including the recently authorized solar farm projects Two Creeks and Badger Hollow.
The following discussion is based on the business segments as discussed in Footnote 1416 of the Notes to Consolidated Financial Statements in this Report.
Results of Operations
Results of operations include financial information prepared in accordance with GAAP and electric and gas margins, both which are non-GAAP measures. Electric margin (electric revenues less fuel for electric generation and purchase power costs) and gas margin (gas revenues less cost of gas sold) are non-GAAP measures because they exclude nonregulated operating revenuesitems used in the calculation of the most comparable GAAP measure, operating income;income. These exclusions consist of nonregulated operating revenues, other operations and maintenance expense, depreciation and amortization expense, and other general taxes expenseexpense. Thus, electric and thusgas margin are not measures determined in accordance with GAAP.
36
Management believes that electric and gas margins provide a meaningful basis for evaluating and managing utility operations since fuel for electric generation, purchase power costs, and cost of gas sold are passed through without mark-up to customers in current rates. As a result, management uses electric and gas margins internally when assessing the operating performance of our segments. The presentation of utility electric and gas margins herein is intended to provide supplemental information for investors regarding operating performance. These electric and gas margins may not be comparable to how other entities calculate utility electric and gas margin or similar measures. Furthermore, these measures are not intended to replace operating income as determined in accordance with GAAP as an indicator of operating performance.
|
Three Months Ended SeptemberJune 30, 20182019 and 20172018
The following table provides a calculation of electric and gas margins (non-GAAP), along with a reconciliation to the most comparable GAAP measure, operating income:
|
|
| Three Months Ended September 30, |
| ||||
| (In millions) |
| 2018 |
| 2017 |
| $ Change |
|
| Electric revenues | $ | 119.2 | $ | 120.6 | $ | (1.4) |
|
| Fuel for electric generation |
| 16.8 |
| 15.8 |
| 1.0 |
|
| Purchased power |
| 13.0 |
| 16.0 |
| (3.0) |
|
| Total Electric Margins |
| 89.4 |
| 88.8 |
| 0.6 |
|
|
|
|
|
|
|
|
|
|
| Gas revenues |
| 18.4 |
| 18.8 |
| (0.4) |
|
| Cost of gas sold |
| 4.9 |
| 5.1 |
| (0.2) |
|
| Total Gas Margins |
| 13.5 |
| 13.7 |
| (0.2) |
|
|
|
|
|
|
|
|
|
|
| Other operating revenues |
| 0.2 |
| 0.1 |
| 0.1 |
|
| Other operations and maintenance |
| 44.1 |
| 42.5 |
| 1.6 |
|
| Depreciation and amortization |
| 14.3 |
| 13.4 |
| 0.9 |
|
| Other general taxes |
| 4.9 |
| 4.7 |
| 0.2 |
|
| Operating Income | $ | 39.8 | $ | 42.0 | $ | (2.2) |
|
|
|
| Three Months Ended June 30, |
| ||||
| (In millions) |
| 2019 |
| 2018 |
| $ Change |
|
| Electric revenues | $ | 96.9 | $ | 99.1 | $ | (2.2) |
|
| Fuel for electric generation |
| (10.4) |
| (15.3) |
| 4.9 |
|
| Purchased power |
| (11.0) |
| (13.0) |
| 2.0 |
|
| Total Electric Margins |
| 75.5 |
| 70.8 |
| 4.7 |
|
|
|
|
|
|
|
|
|
|
| Gas revenues |
| 25.1 |
| 25.0 |
| 0.1 |
|
| Cost of gas sold |
| (8.9) |
| (9.6) |
| 0.7 |
|
| Total Gas Margins |
| 16.2 |
| 15.4 |
| 0.8 |
|
|
|
|
|
|
|
|
|
|
| Other operating revenues |
| 0.2 |
| 0.2 |
| - |
|
| Other operations and maintenance |
| (49.0) |
| (43.4) |
| (5.6) |
|
| Depreciation and amortization |
| (18.1) |
| (13.9) |
| (4.2) |
|
| Other general taxes |
| (5.0) |
| (4.9) |
| (0.1) |
|
| Operating Income | $ | 19.8 | $ | 24.2 | $ | (4.4) |
|
Operating income for the three months ended June 30, 2019, compared to the same period in the prior year primarily reflects the effects of the following factors:
A $2.2 million decrease in electric revenue driven by a decrease in residential sales as a result of cooler weather.
A $4.9 million decrease in fuel for electric generation driven by lower costs from the generation of Saratoga (construction was completed in February 2019) and lower internal generation as a result of timing of scheduled plant outages at Columbia and the Elm Road units.
A $2.0 million decrease in purchased power costs driven by lower costs in the market.
A $0.7 million decrease in cost of gas sold driven by decreased gas sales.
A $5.6 million increase in other operations and maintenance. See consolidated operations and maintenance expenses section below.
A $4.2 million increase in depreciation and amortization expense driven by accelerated depreciation expense for specified electric assets as discussed in the consolidated depreciation expense section below.
Electric sales and revenues
The following table compares MGE's electric revenues and electric kWh sales by customer class for each of the periods indicated:
|
| Revenues |
| Sales (kWh) | ||||||||
(In thousands, except cooling degree days) |
| Three Months Ended September 30, |
| Three Months Ended September 30, | ||||||||
| 2018 |
| 2017 |
| % Change |
| 2018 |
| 2017 |
| % Change | |
Residential | $ | 42,371 | $ | 39,905 |
| 6.2 % |
| 256,820 |
| 225,992 |
| 13.6 % |
Commercial |
| 61,638 |
| 64,036 |
| (3.7)% |
| 520,827 |
| 505,771 |
| 3.0 % |
Industrial |
| 3,668 |
| 4,555 |
| (19.5)% |
| 47,381 |
| 48,896 |
| (3.1)% |
Other-retail/municipal |
| 9,431 |
| 10,459 |
| (9.8)% |
| 106,953 |
| 119,979 |
| (10.9)% |
Total retail |
| 117,108 |
| 118,955 |
| (1.6)% |
| 931,981 |
| 900,638 |
| 3.5 % |
Sales to the market |
| 1,505 |
| 1,068 |
| 40.9 % |
| 33,090 |
| 27,581 |
| 20.0 % |
Other revenues |
| 482 |
| 445 |
| 8.3 % |
| - |
| - |
| - % |
Adjustments to revenues |
| 80 |
| 181 |
| (55.8)% |
| - |
| - |
| - % |
Total | $ | 119,175 | $ | 120,649 |
| (1.2)% |
| 965,071 |
| 928,219 |
| 4.0 % |
|
|
|
|
|
|
|
|
|
|
|
|
|
Cooling degree days (normal 487) |
|
|
|
|
|
|
| 536 |
| 398 |
| 34.7 % |
37
|
| Revenues |
| Sales (kWh) | ||||||||
(In thousands) |
| Three Months Ended June 30, |
| Three Months Ended June 30, | ||||||||
| 2019 |
| 2018 |
| % Change |
| 2019 |
| 2018 |
| % Change | |
Residential | $ | 30,749 | $ | 32,217 |
| (4.6)% |
| 173,125 |
| 200,224 |
| (13.5)% |
Commercial |
| 52,762 |
| 50,174 |
| 5.2 % |
| 445,437 |
| 470,504 |
| (5.3)% |
Industrial |
| 3,322 |
| 4,630 |
| (28.3)% |
| 44,314 |
| 46,237 |
| (4.2)% |
Other-retail/municipal |
| 8,946 |
| 8,527 |
| 4.9 % |
| 97,004 |
| 98,147 |
| (1.2)% |
Total retail |
| 95,779 |
| 95,548 |
| 0.2 % |
| 759,880 |
| 815,112 |
| (6.8)% |
Sales to the market |
| 790 |
| 2,795 |
| (71.7)% |
| 21,614 |
| 85,937 |
| (74.8)% |
Other revenues |
| 294 |
| 724 |
| (59.4)% |
| - |
| - |
| - % |
Total | $ | 96,863 | $ | 99,067 |
| (2.2)% |
| 781,494 |
| 901,049 |
| (13.3)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Cooling degree days (normal 187) |
|
|
|
|
|
|
| 118 |
| 247 |
| (52.2)% |
Electric margin, a non-GAAP measure, increased $0.6$4.7 million for the three months ended September June 30, 2018,2019, compared to the same period in 2017,2018, due to the following:
| (In millions) |
|
|
|
| Revenue subject to refund, net | $ | (4.0) |
|
| Other |
| (1.1) |
|
| Increase in volume |
| 3.7 |
|
| Decreased fuel costs |
| 2.0 |
|
| Total | $ | 0.6 |
|
| (In millions) |
|
|
|
| Revenue subject to refund, net | $ | 9.2 |
|
| Decreased fuel costs |
| 3.5 |
|
| Decrease in volume |
| (4.4) |
|
| Rate changes |
| (2.2) |
|
| Other |
| (1.4) |
|
| Total | $ | 4.7 |
|
·
Revenue subject to refund.For cost recovery mechanisms,any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.
o
Tax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. During the three months ended September 30, 2018, MGE recorded a $1.1 million reduction in retail electric revenues and recorded a corresponding regulatory liability. During the three months ended
|
SeptemberJune 30, 2018, MGE returned $1.8$3.1 million to electric customers through bill credits related to the tax credit.
o
Fuel-related costs.MGE's fuel-related costs subject to refund decreased $0.5in 2018 was $3.8 million. There were no fuel-related costs subject to refund in 2019. Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding. Beginning in 2018, over-collection of fuel-related costs outside the tolerance band are reflected as a reduction of revenue in the period incurred. Under-collection of costs outside the tolerance band is reflected as a reduction of purchase power expense in the period incurred. Any potential recovery of excess fuel costs will be recorded in the period received. Prior to adoption of the new revenue recognition guidance, effective January 1, 2018, deferred fuel-related costs were reflected in purchased power expense, with potential refunds associated with fuel savings increasing that expense and potential recovery of excess fuel costs decreasing that expense.
o
Transmission.MGE's transmission costs subject to refund increased $0.4 million.decreased revenue $0.6 million in 2019. In 2018, MGE recorded a $1.8 million reduction in retail electric revenues primarily related to a one-time refund received in June 2018.
o
Operating Costs. MGE's MGE recognized revenue for electric plant operating costs subject to refund decreased $0.9from previous years of $0.4 million in 2019. In 2018, MGE recorded a $1.4 million reduction in retail electric revenues primarily related to lower leased generation costs due to the reduction in tax rate.
·
Other.Fuel costs. Fuel costs decreased during the three months ended June 30, 2019, primarily as a result of a scheduled plant outage in 2019 and a reduction in purchased power. The commercial operation of the Saratoga Wind Farm in February 2019 decreased the need for purchased power contributing to the reduction in fuel costs in the current quarter.
Volume. During the three months ended SeptemberJune 30, 2018, other items affecting electric operating revenues decreased $1.1 million primarily attributable to a decrease in demand charges as a result of a large industrial customer relocating its operations out of state.
·
Volume.During the three months ended September 30, 2018,2019, there was a 13.6% increase13.5% decrease in residential electric sales volumes compared to the same period in the prior year driven by favorabledecreased customer demand as a result of cooler weather conditions. Duringin 2019.
Rate changes. Rates charged to retail customers during the three months ended SeptemberJune 30, 2018, there was a 3.1% decrease in industrial retail electric sales volumes compared to2019, were $2.2 million lower than those charged during the same period in the prior year as a result of a large industrial customer relocating its operations out of state.year.
38
In December 2018, the PSCW authorized MGE to decrease 2019 rates for electric retail customers by 2.24%.
·
Fuel costs.Fuel costs decreased duringOther. During the three months ended SeptemberJune 30, 2018,2019, other items affecting electric operating revenues decreased $1.4 million primarily asattributable to a result of a reductiondecrease in purchased power. The purchase of the Forward Wind Energy Center in April 2018 replaced an existing purchase power agreement that was previously recorded as purchased power expense in fuel costs.demand charges.
Gas deliveries and revenues
The following table compares MGE's gas revenues and gas therms delivered by customer class for each of the periods indicated:
|
| Revenues |
| Therms Delivered |
| Revenues |
| Therms Delivered | ||||||||||||||||
(In thousands, except HDD and average rate per therm of retail customer) |
| Three Months Ended September 30, |
| Three Months Ended September 30, |
| Three Months Ended June 30, |
| Three Months Ended June 30, | ||||||||||||||||
| 2018 |
| 2017 |
| % Change |
| 2018 |
| 2017 |
| % Change |
| 2019 |
| 2018 |
| % Change |
| 2019 |
| 2018 |
| % Change | |
Residential | $ | 11,916 | $ | 12,121 |
| (1.7)% |
| 5,694 |
| 5,841 |
| (2.5)% | $ | 16,000 | $ | 15,620 |
| 2.4 % |
| 14,804 |
| 15,344 |
| (3.5)% |
Commercial/Industrial |
| 5,570 |
| 5,622 |
| (0.9)% |
| 9,657 |
| 8,847 |
| 9.2 % |
| 7,883 |
| 8,206 |
| (3.9)% |
| 14,723 |
| 15,649 |
| (5.9)% |
Total retail |
| 17,486 |
| 17,743 |
| (1.4)% |
| 15,351 |
| 14,688 |
| 4.5 % |
| 23,883 |
| 23,826 |
| 0.2 % |
| 29,527 |
| 30,993 |
| (4.7)% |
Gas transportation |
| 829 |
| 944 |
| (12.2)% |
| 15,784 |
| 14,606 |
| 8.1 % |
| 1,094 |
| 1,053 |
| 3.9 % |
| 16,144 |
| 16,534 |
| (2.4)% |
Other revenues |
| 92 |
| 91 |
| 1.1 % |
| - |
| - |
| - % |
| 93 |
| 101 |
| (7.9)% |
| - |
| - |
| - % |
Total | $ | 18,407 | $ | 18,778 |
| (2.0)% |
| 31,135 |
| 29,294 |
| 6.3 % | $ | 25,070 | $ | 24,980 |
| 0.4 % |
| 45,671 |
| 47,527 |
| (3.9)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Heating degree days (normal 154) |
|
|
|
|
|
|
| 125 |
| 138 |
| (9.4)% | ||||||||||||
Heating degree days (normal 809) |
|
|
|
|
|
|
| 873 |
| 939 |
| (7.0)% | ||||||||||||
Average rate per therm of |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
retail customer | $ | 1.139 | $ | 1.208 |
| (5.7)% |
|
|
|
|
|
| $ | 0.809 | $ | 0.769 |
| 5.2 % |
|
|
|
|
|
|
Gas margin, a non-GAAP measure, decreased $0.2increased $0.8 million for the three months ended SeptemberJune 30, 2018,2019, compared to the same period in 2017,2018, due to the following:
| (In millions) |
|
|
|
| Increase in volume | $ | 0.2 |
|
| Other |
| 0.1 |
|
| Revenue subject to refund/tax credit |
| (0.5) |
|
| Total | $ | (0.2) |
|
| (In millions) |
|
|
|
| Revenue subject to refund, net | $ | 0.5 |
|
| Other |
| 0.3 |
|
| Rate changes |
| 0.2 |
|
| Decrease in volume |
| (0.2) |
|
| Total | $ | 0.8 |
|
|
·
Revenue subject to refund/tax creditrefund - Tax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. Any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred. ForDuring the three months ended SeptemberJune 30, 2018 MGE recorded a $0.3 million reduction in retail gas revenues and recorded a corresponding regulatory liability. During the three months ended September 30, 2018,, MGE returned $0.2$1.0 million to gas customers through bill credits related to the tax credit.
Consolidated operations and maintenance expenses
For the three months ended SeptemberJune 30, 2018,2019, operations and maintenance expenses increased $1.6$5.6 million, compared to the same period in the prior year. The following contributed to the net change:
| (In millions) |
|
|
|
| Increased distribution expenses | $ | 1.0 |
|
| Increased transmission costs |
| 0.4 |
|
| Increased other costs |
| 0.2 |
|
| Total | $ | 1.6 |
|
| (In millions) |
|
|
|
| Increased electric production expenses | $ | 1.9 |
|
| Increased transmission costs |
| 1.2 |
|
| Increased administrative and general costs |
| 0.9 |
|
| Increased gas distribution expenses |
| 0.7 |
|
| Increased customer accounts costs |
| 0.3 |
|
| Increased customer services |
| 0.3 |
|
| Increased other costs |
| 0.3 |
|
| Total | $ | 5.6 |
|
For the three months ended September 30, 2018, increased distributionIncreased electric production expenses are primarily related to the timing of Columbia maintenance costs
39
completed during a scheduled plant outage. The 2018 outage was completed in the first quarter.
Increased transmission costs are primarily related to an increase in transmission rates as a result of a one-time refund received in June 2018. The lower transmission rate is reflected in customer revenue as revenue subject to refund.
Increased administrative and general costs are primarily related increased overhead line maintenance.technology related costs associated with the multi-year Enterprise Forward project, which includes a new customer information system.
Consolidated depreciation expense
Electric depreciation expense increased $3.8 million and gas depreciation expense increased $0.4 million for the three months ended June 30, 2019, compared to the same period in the prior year. MGE accelerated depreciation for combustion turbines and Columbia Unit 1 in 2019, as approved in the December 2018 rate settlement, increasing electric depreciation expense compared to the prior period. Also approved in the December 2018 rate settlement were new depreciation rates for Columbia, further contributing to the increase in electric depreciation expense.
Nonregulated Energy Operations - MGE Energy and MGE
The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. For the three months ended SeptemberJune 30, 20182019 and 2017,2018, net income at the nonregulated energy operations segment was $5.1 million and $4.8$5.0 million, respectively. The decrease in tax rate from 35 to 21 percent, effective January 1, 2018, lowered lease revenues and income tax expense for the three months ended 2018. Income tax expense is a factor used in the formula to calculate lease rates.
Transmission Investment Operations - MGE Energy
For the three months ended SeptemberJune 30, 20182019 and 2017,2018, other income at the transmission investment segment was $1.6$2.3 million and $2.3$1.9 million, respectively. The decrease in tax rate from 35 to 21 percent, effective January 1, 2018, lowered earnings from ATC and income tax expense for the three months ended 2018. Income tax expense is a factor used in the calculation of ATC's transmission rates. The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational. See Footnote 4 of the Notes to Consolidated Financial Statements in this Report and "Other Matters""Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.
Consolidated Income Taxes - MGE Energy and MGE
AlthoughIn 2019, the effective electric tax rates have been loweredrate decreased as a result of a tax credit from the Tax Act, regulated revenues have been affected as tax expense is a factor incommercial operation of the determination of rates for electric and gas service, and rates relating to our investment in transmission.Saratoga Wind Farm. See Footnote 5 of the Notes to Consolidated Financial Statements in this Report for effective tax rate reconciliation.
Noncontrolling Interest, Net of Tax - MGE
The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs.
|
The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:
|
|
| Three Months Ended |
| ||
|
|
| September 30, |
| ||
| (In millions) |
| 2018 |
| 2017 |
|
| MGE Power Elm Road | $ | 3.8 | $ | 3.6 |
|
| MGE Power West Campus |
| 1.8 |
| 1.8 |
|
Nine Months Ended September 30, 2018 and 2017
The following table provides a calculation of electric and gas margins (non-GAAP), along with a reconciliation to the most comparable GAAP measure, operating income:
|
|
| Nine Months Ended September 30, |
| ||||
| (In millions) |
| 2018 |
| 2017 |
| $ Change |
|
| Electric revenues | $ | 312.6 | $ | 321.3 | $ | (8.7) |
|
| Fuel for electric generation |
| 43.9 |
| 39.9 |
| 4.0 |
|
| Purchased power |
| 43.0 |
| 48.1 |
| (5.1) |
|
| Total Electric Margins |
| 225.7 |
| 233.3 |
| (7.6) |
|
|
|
|
|
|
|
|
|
|
| Gas revenues |
| 106.2 |
| 101.3 |
| 4.9 |
|
| Cost of gas sold |
| 54.1 |
| 50.1 |
| 4.0 |
|
| Total Gas Margins |
| 52.1 |
| 51.2 |
| 0.9 |
|
|
|
|
|
|
|
|
|
|
| Other operating revenues |
| 0.9 |
| 0.2 |
| 0.7 |
|
| Other operations and maintenance |
| 132.0 |
| 131.2 |
| 0.8 |
|
| Depreciation and amortization |
| 41.8 |
| 39.6 |
| 2.2 |
|
| Other general taxes |
| 14.7 |
| 14.5 |
| 0.2 |
|
| Operating Income | $ | 90.2 | $ | 99.4 | $ | (9.2) |
|
Electric sales and revenues
The following table compares MGE's electric revenues and electric kWh sales by customer class for each of the periods indicated:
|
| Revenues |
| Sales (kWh) | ||||||||
(In thousands, except cooling degree days) |
| Nine Months Ended September 30, |
| Nine Months Ended September 30, | ||||||||
| 2018 |
| 2017 |
| % Change |
| 2018 |
| 2017 |
| % Change | |
Residential | $ | 107,847 | $ | 104,892 |
| 2.8 % |
| 664,195 |
| 601,310 |
| 10.5 % |
Commercial |
| 159,264 |
| 168,921 |
| (5.7)% |
| 1,432,222 |
| 1,389,036 |
| 3.1 % |
Industrial |
| 11,193 |
| 13,286 |
| (15.8)% |
| 136,485 |
| 153,759 |
| (11.2)% |
Other-retail/municipal |
| 26,245 |
| 29,141 |
| (9.9)% |
| 294,345 |
| 315,692 |
| (6.8)% |
Total retail |
| 304,549 |
| 316,240 |
| (3.7)% |
| 2,527,247 |
| 2,459,797 |
| 2.7 % |
Sales to the market |
| 6,334 |
| 3,090 |
| n.m.% |
| 151,586 |
| 80,273 |
| 88.8 % |
Other revenues |
| 1,406 |
| 1,436 |
| (2.1)% |
| - |
| - |
| - % |
Adjustments to revenues |
| 344 |
| 513 |
| (32.9)% |
| - |
| - |
| - % |
Total | $ | 312,633 | $ | 321,279 |
| (2.7)% |
| 2,678,833 |
| 2,540,070 |
| 5.5 % |
|
|
|
|
|
|
|
|
|
|
|
|
|
Cooling degree days (normal 671) |
|
|
|
|
|
|
| 783 |
| 570 |
| 37.4 % |
n.m.: not meaningful
Electric margin, a non-GAAP measure, decreased $7.6 million for the nine months ended September 30, 2018, compared to the same period in 2017, due to the following:
| ||||
|
|
| ||
|
| |||
|
| |||
|
| |||
|
|
|
|
·
Revenue subject to refund.For cost recovery mechanisms,any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.
o
Tax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. During the nine months ended September 30, 2018, MGE recorded a $3.2 million reduction in retail electric revenues and recorded a corresponding regulatory liability. During the nine months ended September 30, 2018, MGE returned $4.8 million to electric customers through bill credits related to the tax credit.
o
Fuel-related costs.MGE's fuel-related costs subject to refund decreased $3.9 million. Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding. Beginning in 2018, over-collection of fuel-related costs outside the tolerance band are reflected as a reduction of revenue in the period incurred. Under-collection of costs outside the tolerance band is reflected as a reduction of purchase power expense in the period incurred. Any potential recovery of excess fuel costs will be recorded in the period received. Prior to adoption of the new revenue recognition guidance, effective January 1, 2018, deferred fuel-related costs were reflected in purchased power expense, with potential refunds associated with fuel savings increasing that expense and potential recovery of excess fuel costs decreasing that expense.
o
Transmission.MGE's transmission costs subject to refund decreased $1.8 million primarily related to a one-time refund received in June 2018.
o
Operating Costs. MGE's electric plant operating costs subject to refund decreased $3.2 million primarily related to lower leased generation costs due to the reduction in tax rate.
·
Other.During the nine months ended September 30, 2018, other items affecting electric operating revenues decreased $1.5 million primarily attributable to a decrease in demand charges as a result of a large industrial customer relocating its operations out of state.
·
Volume.During the nine months ended September 30, 2018, there was a 10.5% increase in residential sales volumes compared to the same period in the prior year driven by favorable weather conditions. During the nine months ended September 30, 2018, there was an 11.2% decrease in industrial retail sales volumes compared to the same period in the prior year as a result of a large industrial customer relocating its operations out of state.
·
Fuel costs.Fuel costs decreased during the nine months ended September 30, 2018, primarily as a result of a reduction in purchased power. The purchase of the Forward Wind Energy Center in April 2018 replaced an existing purchase power agreement.
Gas deliveries and revenues
The following table compares MGE's gas revenues and gas therms delivered by customer class for each of the periods indicated:
|
| Revenues |
| Therms Delivered | ||||||||
(In thousands, except HDD and average rate per therm of retail customer) |
| Nine Months Ended September 30, |
| Nine Months Ended September 30, | ||||||||
| 2018 |
| 2017 |
| % Change |
| 2018 |
| 2017 |
| % Change | |
Residential | $ | 64,087 | $ | 61,164 |
| 4.8 % |
| 70,750 |
| 60,794 |
| 16.4 % |
Commercial/Industrial |
| 38,728 |
| 36,512 |
| 6.1 % |
| 67,613 |
| 58,865 |
| 14.9 % |
Total retail |
| 102,815 |
| 97,676 |
| 5.3 % |
| 138,363 |
| 119,659 |
| 15.6 % |
Gas transportation |
| 3,018 |
| 3,285 |
| (8.1)% |
| 54,259 |
| 50,828 |
| 6.8 % |
Other revenues |
| 319 |
| 324 |
| (1.5)% |
| - |
| - |
| - % |
Total | $ | 106,152 | $ | 101,285 |
| 4.8 % |
| 192,622 |
| 170,487 |
| 13.0 % |
|
|
|
|
|
|
|
|
|
|
|
|
|
Heating degree days (normal 4,436) |
|
|
|
|
|
|
| 4,650 |
| 4,025 |
| 15.5 % |
Average rate per therm of |
|
|
|
|
|
|
|
|
|
|
|
|
retail customer | $ | 0.743 | $ | 0.816 |
| (8.9)% |
|
|
|
|
|
|
|
Gas margin, a non-GAAP measure, increased $0.9 million for the nine months ended September 30, 2018, compared to the same period in 2017, due to the following:
| (In millions) |
|
|
|
| Increase in volume | $ | 3.2 |
|
| Other |
| 0.3 |
|
| Revenue subject to refund/tax credit |
| (2.6) |
|
| Total | $ | 0.9 |
|
·
Volume. For the nine months ended September 30, 2018, retail gas deliveries increased 15.6% compared to the same period in the prior year primarily related to customer growth and more favorable weather conditions in the current year.
·
Revenue subject to refund/tax credit. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. Any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred. For the nine months ended September 30, 2018, MGE recorded a $1.3 million reduction in retail gas revenues and recorded a corresponding regulatory liability. During the nine months ended September 30, 2018, MGE returned $1.1 million to gas customers through bill credits related to the tax credit.
Consolidated operations and maintenance expenses
For the nine months ended September 30, 2018, operations and maintenance expenses increased $0.8 million, compared to the same period in the prior year. The following contributed to the net change:
| (In millions) |
|
|
|
| Increased distribution expenses | $ | 1.0 |
|
| Increased other costs |
| 0.8 |
|
| Increased administrative and general costs |
| 0.4 |
|
| Increased electric production expenses |
| 0.3 |
|
| Decreased transmission costs |
| (1.7) |
|
| Total | $ | 0.8 |
|
For the nine months ended September 30, 2018, increased distribution costs are primarily related to increased overhead line maintenance. For the nine months ended September 30, 2018, decreased transmission costs are primarily related to a decrease in transmission rates as a result of a one-time refund received in June 2018. The lower transmission rate is reflected in customer revenue as revenue subject to refund.
Consolidated depreciation expense
Depreciation expense increased $2.2 million for the nine months ended September 30, 2018, compared to the same period in the prior year primarily related to an increase in depreciable assets.
Nonregulated Energy Operations - MGE Energy and MGE
The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. For the nine months ended September 30, 2018 and 2017, net income at the nonregulated energy operations segment was $15.2 million and $14.2 million, respectively. The decrease in tax rate from 35 to 21 percent, effective January 1, 2018, lowered lease revenues and income tax expense for the nine months ended 2018. Income tax expense is a factor used in the formula to calculate lease rates.
Transmission Investment Operations - MGE Energy
For the nine months ended September 30, 2018 and 2017, other income at the transmission investment segment was $5.9 million and $7.2 million, respectively. The decrease in tax rate from 35 to 21 percent, effective January 1, 2018, lowered earnings from ATC and income tax expense for the nine months ended 2018. Income tax expense is a factor used in the calculation of ATC's transmission rates. The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was
|
formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational. See Footnote 4 of the Notes to Consolidated Financial Statements in this Report and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.
Consolidated Income Taxes - MGE Energy and MGE
Although effective tax rates have been lowered as a result of the Tax Act, regulated revenues have been affected as tax expense is a factor in the determination of rates for electric and gas service, and rates relating to our investment in transmission. See Footnote 5 of the Notes to Consolidated Financial Statements in this Report for effective tax rate reconciliation.
Noncontrolling Interest, Net of Tax - MGE
The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. The following table shows MGE Energy'sEnergy's noncontrolling interest, net of tax, reflected on MGE'sMGE's consolidated statement of income:
|
|
| Three Months Ended |
| ||
|
|
| June 30, |
| ||
| (In millions) |
| 2019 |
| 2018 |
|
| MGE Power Elm Road | $ | 3.8 | $ | 3.8 |
|
| MGE Power West Campus |
| 1.8 |
| 1.7 |
|
|
|
| Nine Months Ended |
| ||
|
|
| September 30, |
| ||
| (In millions) |
| 2018 |
| 2017 |
|
| MGE Power Elm Road | $ | 11.6 | $ | 10.8 |
|
| MGE Power West Campus |
| 5.3 |
| 5.4 |
|
40
Six Months Ended June 30, 2019 and 2018
The following table provides a calculation of electric and gas margins (non-GAAP), along with a reconciliation to the most comparable GAAP measure, operating income:
|
|
| Six Months Ended June 30, |
| ||||
| (In millions) |
| 2019 |
| 2018 |
| $ Change |
|
| Electric revenues | $ | 194.3 | $ | 193.5 | $ | 0.8 |
|
| Fuel for electric generation |
| (24.3) |
| (27.2) |
| 2.9 |
|
| Purchased power |
| (21.9) |
| (30.0) |
| 8.1 |
|
| Total Electric Margins |
| 148.1 |
| 136.3 |
| 11.8 |
|
|
|
|
|
|
|
|
|
|
| Gas revenues |
| 95.2 |
| 87.7 |
| 7.5 |
|
| Cost of gas sold |
| (52.2) |
| (49.2) |
| (3.0) |
|
| Total Gas Margins |
| 43.0 |
| 38.5 |
| 4.5 |
|
|
|
|
|
|
|
|
|
|
| Other operating revenues |
| 0.3 |
| 0.7 |
| (0.4) |
|
| Other operations and maintenance |
| (95.9) |
| (87.8) |
| (8.1) |
|
| Depreciation and amortization |
| (35.2) |
| (27.5) |
| (7.7) |
|
| Other general taxes |
| (10.0) |
| (9.8) |
| (0.2) |
|
| Operating Income | $ | 50.3 | $ | 50.4 | $ | (0.1) |
|
Operating income for the six months ended June 30, 2019, compared to the same period in the prior year primarily reflects the effects of the following factors:
A $0.8 million increase in electric revenue driven by timing of deferred revenue collected in rates.
A $2.9 million decrease in fuel for electric generation driven by lower costs from the generation of Saratoga (construction was completed in February 2019) and lower internal generation as a result of scheduled outages at Columbia and the Elm Road units.
An $8.1 million decrease in purchased power costs driven by the purchase of the Forward Wind Energy Center in April 2018, which replaced an existing purchased power agreement and increased internal generation.
A $7.5 million increase in gas revenues reflecting higher customer demand resulting from colder weather in the first quarter.
A $3.0 million increase in cost of gas sold driven by increased gas sales.
An $8.1 million increase in other operations and maintenance. See consolidated operations and maintenance expenses section below.
A $7.7 million increase in depreciation and amortization expense driven by accelerated depreciation expense for specified electric assets as discussed in the consolidated depreciation expense section below.
Electric sales and revenues
The following table compares MGE's electric revenues and electric kWh sales by customer class for each of the periods indicated:
41
|
| Revenues |
| Sales (kWh) | ||||||||
(In thousands, except cooling degree days) |
| Six Months Ended June 30, |
| Six Months Ended June 30, | ||||||||
| 2019 |
| 2018 |
| % Change |
| 2019 |
| 2018 |
| % Change | |
Residential | $ | 65,330 | $ | 65,476 |
| (0.2)% |
| 385,804 |
| 407,375 |
| (5.3)% |
Commercial |
| 102,015 |
| 97,626 |
| 4.5 % |
| 890,540 |
| 911,395 |
| (2.3)% |
Industrial |
| 6,253 |
| 7,525 |
| (16.9)% |
| 85,423 |
| 89,104 |
| (4.1)% |
Other-retail/municipal |
| 17,185 |
| 16,814 |
| 2.2 % |
| 177,740 |
| 187,392 |
| (5.2)% |
Total retail |
| 190,783 |
| 187,441 |
| 1.8 % |
| 1,539,507 |
| 1,595,266 |
| (3.5)% |
Sales to the market |
| 2,751 |
| 4,829 |
| (43.0)% |
| 73,138 |
| 118,496 |
| (38.3)% |
Other revenues |
| 745 |
| 1,188 |
| (37.3)% |
| - |
| - |
| - % |
Total | $ | 194,279 | $ | 193,458 |
| 0.4 % |
| 1,612,645 |
| 1,713,762 |
| (5.9)% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Cooling degree days (normal 187) |
|
|
|
|
|
|
| 118 |
| 247 |
| (52.2)% |
Electric margin, a non-GAAP measure, increased $11.8 million for the six months ended June 30, 2019, compared to the same period in 2018, due to the following:
| (In millions) |
|
|
|
| Revenue subject to refund, net | $ | 14.0 |
|
| Decreased fuel costs |
| 7.5 |
|
| Rate changes |
| (4.9) |
|
| Decrease in volume |
| (3.7) |
|
| Other |
| (1.1) |
|
| Total | $ | 11.8 |
|
Revenue subject to refund. For cost recovery mechanisms,any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred.
oTax Act. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. During the six months ended June 30, 2018, MGE recorded a $2.0 million reduction in retail electric revenues and recorded a corresponding regulatory liability. During the six months ended June 30, 2018, MGE returned $3.1 million to electric customers through bill credits related to the tax credit.
oFuel-related costs. MGE's fuel-related costs subject to refund in 2018 was $5.2 million. There were no fuel-related costs subject to refund in 2019. Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding.
oTransmission. MGE's transmission costs subject to refund decreased revenue $1.4 million in 2019. In 2018, MGE recorded a $2.2 million reduction in retail electric revenues primarily related to a one-time refund received in June 2018.
oOperating Costs. MGE recognized revenue for electric plant operating costs subject to refund from previous years of $0.7 million in 2019. In 2018, MGE recorded a reduction of $2.3 million in retail electric revenues primarily related to lower leased generation costs due to the reduction in tax rate.
Fuel costs. Fuel costs decreased during the six months ended June 30, 2019, primarily as a result of a reduction in purchased power. The purchase of the Forward Wind Energy Center in April 2018 replaced an existing purchase power agreement that was previously recorded as purchased power expense in fuel costs. The commercial operation of the Saratoga Wind Farm in February 2019 further decreased the need for purchased power contributing to the reduction in fuel costs in the current year.
Rate changes. Rates charged to retail customers during the six months ended June 30, 2019, were $4.9 million lower than those charged during the same period in the prior year.
42
In December 2018, the PSCW authorized MGE to decrease 2019 rates for electric retail customers by 2.24%.
Volume. During the six months ended June 30, 2019, there was a 5.3% decrease in residential sales volumes compared to the same period in the prior year driven by less favorable weather conditions.
Other. During the six months ended June 30, 2019, other items affecting electric operating revenues decreased $1.1 million primarily attributable to a decrease in demand charges.
Gas deliveries and revenues
The following table compares MGE's gas revenues and gas therms delivered by customer class for each of the periods indicated:
|
| Revenues |
| Therms Delivered | ||||||||
(In thousands, except HDD and average rate per therm of retail customer) |
| Six Months Ended June 30, |
| Six Months Ended June 30, | ||||||||
| 2019 |
| 2018 |
| % Change |
| 2019 |
| 2018 |
| % Change | |
Residential | $ | 56,317 | $ | 52,171 |
| 7.9 % |
| 69,062 |
| 65,056 |
| 6.2 % |
Commercial/Industrial |
| 36,008 |
| 33,158 |
| 8.6 % |
| 61,060 |
| 57,956 |
| 5.4 % |
Total retail |
| 92,325 |
| 85,329 |
| 8.2 % |
| 130,122 |
| 123,012 |
| 5.8 % |
Gas transportation |
| 2,630 |
| 2,189 |
| 20.1 % |
| 38,614 |
| 38,475 |
| 0.4 % |
Other revenues |
| 215 |
| 227 |
| (5.3)% |
| - |
| - |
| - % |
Total | $ | 95,170 | $ | 87,745 |
| 8.5 % |
| 168,736 |
| 161,487 |
| 4.5 % |
|
|
|
|
|
|
|
|
|
|
|
|
|
Heating degree days (normal 4,317) |
|
|
|
|
|
|
| 4,720 |
| 4,525 |
| 4.3 % |
Average rate per therm of |
|
|
|
|
|
|
|
|
|
|
|
|
retail customer | $ | 0.710 | $ | 0.694 |
| 2.3 % |
|
|
|
|
|
|
Gas margin, a non-GAAP measure, increased $4.5 million for the six months ended June 30, 2019, compared to the same period in 2018, due to the following:
| (In millions) |
|
|
|
| Revenue subject to refund/tax credit | $ | 1.9 |
|
| Increase in volume |
| 1.1 |
|
| Rate changes |
| 0.9 |
|
| Other |
| 0.6 |
|
| Total | $ | 4.5 |
|
Revenue subject to refund/tax credit. MGE received a PSCW order in January 2018 to defer the over-collection of income tax expense collected in customer rates as a result of the Tax Act reduction in federal income tax rate to 21 percent. Any over-collection of the difference between actual costs incurred and the amount of costs collected from customers is recorded as a reduction of revenue in the period incurred. For the six months ended June 30, 2018, MGE recorded a $1.0 million reduction in retail gas revenues and recorded a corresponding regulatory liability. During the six months ended June 30, 2018, MGE returned $1.0 million to gas customers through bill credits related to the tax credit.
Volume. For the six months ended June 30, 2019, retail gas deliveries increased 5.8% compared to the same period in the prior year primarily related to customer growth and more favorable weather conditions in the current year.
Rate changes. In December 2018, the PSCW authorized MGE to increase 2019 rates for retail gas customers by 1.06%.
Consolidated operations and maintenance expenses
For the six months ended June 30, 2019, operations and maintenance expenses increased $8.1 million, compared to the same period in the prior year. The following contributed to the net change:
43
| (In millions) |
|
|
|
| Increased administrative and general costs | $ | 3.4 |
|
| Increased electric production expenses |
| 1.5 |
|
| Increased gas distribution expenses |
| 1.0 |
|
| Increased transmission costs |
| 0.9 |
|
| Increased customer accounts costs |
| 0.8 |
|
| Increased other costs |
| 0.5 |
|
| Total | $ | 8.1 |
|
Increased administrative and general costs are primarily related to increased technology related costs associated with the multi-year Enterprise Forward project, which includes a new customer information system.
Increased electric production expenses are primarily related to increased operations and maintenance costs at the Elm Road Units.
Increased gas distribution expenses are primarily related to increased costs for maintenance on equipment and locator services.
Consolidated depreciation expense
Electric depreciation expense increased $6.9 million and gas depreciation expense increased $0.8 million for the six months ended June 30, 2019, compared to the same period in the prior year. MGE accelerated depreciation for combustion turbines and Columbia Unit 1 in 2019, as approved in the December 2018 rate settlement, increasing electric depreciation expense compared to the prior period. Also approved in the December 2018 rate settlement were new depreciation rates for Columbia, further contributing to the increase in electric depreciation expense.
Nonregulated Energy Operations - MGE Energy and MGE
The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF), which have been formed to own and lease electric generating capacity to assist MGE. For both the six months ended June 30, 2019 and 2018, net income at the nonregulated energy operations segment was $10.1 million.
Transmission Investment Operations - MGE Energy
For the six months ended June 30, 2019 and 2018, other income at the transmission investment segment was $4.4 million and $4.3 million, respectively. The transmission investment segment holds our interest in ATC and ATC Holdco, and its income reflects our equity in the earnings of those investments. ATC Holdco was formed in December 2016. In the near term, it is expected that ATC Holdco will be pursuing transmission development opportunities that typically have long development and investment lead times before becoming operational. See Footnote 4 of the Notes to Consolidated Financial Statements in this Report and "Other Matters" below for additional information concerning ATC and summarized financial information regarding ATC.
Consolidated Income Taxes - MGE Energy and MGE
In 2019, the effective electric tax rate decreased as a result of a tax credit from the commercial operation of the Saratoga Wind Farm. See Footnote 5 of the Notes to Consolidated Financial Statements in this Report for effective tax rate reconciliation.
Noncontrolling Interest, Net of Tax - MGE
The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs with respect to MGE and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. The following table shows MGE Energy's noncontrolling interest, net of tax,
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reflected on MGE's consolidated statement of income:
|
|
| Six Months Ended |
| ||
|
|
| June 30, |
| ||
| (In millions) |
| 2019 |
| 2018 |
|
| MGE Power Elm Road | $ | 7.5 | $ | 7.8 |
|
| MGE Power West Campus |
| 3.6 |
| 3.5 |
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Contractual Obligations and Commercial Commitments - MGE Energy and MGE
There were no material changes, other than from the normal course of business, to MGE Energy's and MGE's contractual obligations (representing cash obligations that are considered to be firm commitments) and commercial commitments (representing commitments triggered by future events) during the ninesix months ended SeptemberJune 30, 2018,2019, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 17 of Notes to Consolidated Financial Statements and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in MGE Energy's and MGE's 20172018 Annual Report on Form 10-K.
Purchase Contracts - MGE Energy and MGE
See items c. and d. within Footnote 9.c.9 of Notes to Consolidated Financial Statements in this Report for a description of commitments at SeptemberJune 30, 2018,2019, that MGE Energy and MGE have entered with respect to various commodity supply and transportation contracts to meet their obligations to deliver electricity and natural gas to customers and the Saratoga wind project.solar farm construction and operating contracts.
Long-term Debt - MGE Energy and MGE
MGE issued $40 million of long-term unsecured debt in July 2018 and $60 million of long-term unsecured debt in September 2018. The proceeds of these debt financings were used to assist with the financing of additional capital expenditures, such as the Saratoga Wind Farm, and refinance $20 million of long-term debt that matured in September 2018. See Footnote 7 of the Notes to Consolidated Financial Statements in this Report for further discussion of these debt issuances.
Liquidity and Capital Resources
MGE Energy and MGE have adequate liquidity to fund future operations and capital expenditures over the next twelve months. Available resources include cash and cash equivalents, operating cash flows, liquid assets, borrowing capacity under revolving credit facilities, and access to equity and debt capital markets. See "Credit Facilities""Credit Facilities" under Part II, Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources in MGE Energy's and MGE's 20172018 Annual Report on Form 10-K for information regarding MGE Energy's and MGE's credit facilities.
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Cash Flows
The following summarizes cash flows for MGE Energy and MGE during the ninesix months ended SeptemberJune 30, 20182019 and 2017:2018:
|
|
| MGE Energy |
| MGE |
| |||||
| (In thousands) |
| 2018 |
| 2017 |
|
| 2018 |
| 2017 |
|
| Cash provided by/(used for): |
|
|
|
|
|
|
|
|
|
|
| Operating activities | $ | 138,432 | $ | 96,146 |
| $ | 135,027 | $ | 91,496 |
|
| Investing activities |
| (153,434) |
| (70,589) |
|
| (149,681) |
| (64,580) |
|
| Financing activities |
| 37,949 |
| (19,128) |
|
| 53,011 |
| (38,075) |
|
|
|
| MGE Energy |
| MGE |
| |||||
| (In thousands) |
| 2019 |
| 2018 |
|
| 2019 |
| 2018 |
|
| Cash provided by (used for): |
|
|
|
|
|
|
|
|
|
|
| Operating activities | $ | 85,884 | $ | 91,618 |
| $ | 85,286 | $ | 90,047 |
|
| Investing activities |
| (82,634) |
| (103,071) |
|
| (79,363) |
| (100,811) |
|
| Financing activities |
| (16,357) |
| (374) |
|
| (4,301) |
| 8,487 |
|
Cash Provided by Operating Activities
MGE Energy
MGE Energy's consolidated net cash provided by operating activities is derived mainly from the electric and gas operations of its principal subsidiary, MGE.
Cash provided by operating activities for the ninesix months ended SeptemberJune 30, 2018,2019, was $138.4$85.9 million, an increasea decrease of $42.3$5.7 million when compared to the same period in the prior year, primarily reflecting changes in working capital items between periods.year.
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MGE Energy's net income increased $6.4$1.2 million for the ninesix months ended SeptemberJune 30, 2018,2019, when compared to the same period in the prior year.
MGE Energy's federal and state taxes paid decreased $12.3increased $5.4 million for the ninesix months ended SeptemberJune 30, 2018,2019, when compared to the same period in the prior year, reflecting the reduction in tax rates effected by the Tax Act.year.
Working capital accounts (excluding prepaid and accrued taxes) resulted in $17.2$14.4 million in cash provided by operating activities for the ninesix months ended SeptemberJune 30, 2018,2019, primarily due to decreased unbilled revenues, decreased accounts receivable, and increaseddecreased gas inventories, partially offset by decreased other current liabilities.
Working capital accounts (excluding prepaid and accrued taxes) resulted in $16.8$17.6 million in cash provided by operating activities for the six months ended June 30, 2018, primarily due to decreased unbilled revenues, decreased accounts receivable, decreased gas inventories, and increased other current liabilities, partially offset by decreased accounts payable.
An increase in hosted software asset expenditures resulted in additional $4.1 million in cash used for operating activities for the ninesix months ended SeptemberJune 30, 2017, primarily due to decreased accounts payable and increased gas inventories, partially offset by decreased unbilled revenues and increased other current liabilities.
A decrease in pension contribution resulted in an additional $5.8 million in cash provided by operating activities for the nine months ended September 30, 2018,2019, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts.
MGE
Cash provided by operating activities for the ninesix months ended SeptemberJune 30, 2018,2019, was $135.0$85.3 million, an increasea decrease of $43.5$4.8 million when compared to the same period in the prior year, primarily reflecting changes in working capital items between periods.year.
Net income increased $5.1$1.2 million for the ninesix months ended SeptemberJune 30, 2018,2019, when compared to the same period in the prior year.
MGE's federal and state taxes paid decreased $12.3increased $5.4 million for the ninesix months ended SeptemberJune 30, 2018,2019, when compared to the same period in the prior year, reflecting the reduction in tax rates effected by the Tax Act.year.
Working capital accounts (excluding prepaid and accrued taxes) resulted in $19.3$16.9 million in cash provided by operating activities for the ninesix months ended SeptemberJune 30, 2018,2019, primarily due to decreased unbilled revenues, decreased accounts receivable, and increaseddecreased gas inventories, partially offset by decreased other current liabilities.
Working capital accounts (excluding prepaid and accrued taxes) resulted in $16.5$19.7 million in cash provided by operating activities for the six months ended June 30, 2018, primarily due to decreased unbilled revenues, decreased accounts receivable, decreased gas inventories, and increased other current liabilities, partially offset by decreased accounts payable.
An increase in hosted software asset expenditures resulted in additional $4.1 million in cash used for operating activities for the ninesix months ended SeptemberJune 30, 2017, primarily due2019, when compared to the prior year.
Cash Used for Investing Activities
MGE Energy
MGE Energy's cash used for investing activities decreased accounts payable and increased gas inventories, partially offset by decreased unbilled revenues and increased other current liabilities.
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A decrease in pension contribution resulted in an additional $5.8$20.4 million in cash provided by operating activities for the ninesix months ended SeptemberJune 30, 2018,2019, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts.
Cash Used for Investing Activities
MGE Energy
MGE Energy's cash used for investing activities increased $82.8 million for the nine months ended September 30, 2018, when compared to the same period in the prior year.
Capital expenditures for the ninesix months ended SeptemberJune 30, 2018,2019, were $149.0$79.1 million. This amount represents an increasea decrease of $82.7$21.3 million from the expenditures made in the same period in the prior year. This increasedecrease primarily reflects expenditures on the construction of the Saratoga wind project in the prior year. 2019 capital expenditures include $9.2 million related to the Two Creeks and Badger Hollow solar construction projects. Total cost of the purchasetwo projects is expected to be approximately $130 million. The projects are anticipated to be completed by the end of Forward Wind.2020.
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MGE
Capital contributions to ATC and other investments
MGE's cash used for investing activities decreased $2.1$21.4 million for theninethe six months ended SeptemberJune 30, 2018,2019, when compared to the same period in the prior year.
MGE Energy received $2.4 million in proceeds from the sales of property for the nine months ended September 30, 2017.
MGE
MGE's cash used for investing activities increased $85.1 million for the nine months ended September 30, 2018, when compared to the same period in the prior year.
Capital expenditures for the ninesix months ended SeptemberJune 30, 2018,2019, were $149.0$79.1 million. This amount represents an increasea decrease of $82.7$21.3 million from the expenditures made in the same period in the prior year. This increasedecrease primarily reflects expenditures on the construction of the Saratoga wind project in the prior year. 2019 capital expenditures include $9.2 million related to the Two Creeks and Badger Hollow solar construction projects. Total cost of the purchasetwo projects is expected to be approximately $130 million. The projects are anticipated to be completed by the end of Forward Wind.2020.
MGE received $1.8 million in proceeds from the sales of property for the nine months ended September 30, 2017.
Cash Provided by/(Used for) Financing Activities
MGE Energy
Cash provided byused for MGE Energy's financing activities was $37.9$16.4 million for the ninesix months ended SeptemberJune 30, 2018,2019, compared to $19.1$0.4 million of cash used for MGE Energy's financing activities for the same period in the prior year.
For the ninesix months ended SeptemberJune 30, 2018,2019, dividends paid were $34.1$23.4 million compared to $32.5$22.4 million in the prior year. This increase was a result of a higher dividend per share ($0.9830.675 vs. $0.938)$0.645).
DuringFor the ninesix months ended SeptemberJune 30, 2018, MGE issued $100.0 million of senior unsecured notes, which was used to refinance $20.0 million of maturing long-term notes and assist with financing additional capital expenditures. The increase in long-term debt primarily reflects expenditures on the construction of the Saratoga wind project. During the nine months ended September 30, 2017, MGE issued $40.0 million of senior unsecured notes, which was used to refinance $30.0 million of maturing medium-term notes and assist with financing additional capital expenditures.
For the nine months ended September 30, 2018,2019, net short-term debt repaymentsborrowings were $4.0$10.5 million compared to net short-term borrowings of $7.0$24.2 million for the ninesix months ended SeptemberJune 30, 2017.2018.
MGE
During the ninesix months ended SeptemberJune 30, 2018,2019, cash provided byused for MGE's financing activities was $53.0$4.3 million, compared to $38.1$8.5 million of cash used forprovided by MGE's financing activities for the same period in the prior year.
Dividends paid from MGE to MGE Energy were $35.0 million for the nine months ended September 30, 2017. There were no dividends from MGE to MGE Energy for the nine months ended September 30, 2018.
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Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus to MGE Energy, were $19.0$11.5 million for the ninesix months ended SeptemberJune 30, 2018,2019, compared to $16.5$13.5 million in the prior year.
DuringFor the ninesix months ended SeptemberJune 30, 2018, MGE issued $100.0 million of senior unsecured notes, which was used to refinance $20.0 million of maturing long-term notes and assist with financing additional capital expenditures. The increase in long-term debt primarily reflects expenditures on the construction of the Saratoga wind project. During the nine months ended September 30, 2017, MGE issued $40.0 million of senior unsecured notes, which was used to refinance $30.0 million of maturing medium-term notes and assist with financing additional capital expenditures.
For the nine months ended September 30, 2018,2019, net short-term debt repaymentsborrowings were $4.0$10.5 million compared to net short-term borrowings of $7.0$24.2 million for the ninesix months ended SeptemberJune 30, 2017.2018.
Capitalization Ratios
MGE Energy's capitalization ratios were as follows:
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| MGE Energy |
| ||
|
| September 30, 2018 |
| December 31, 2017 |
|
| Common shareholders' equity | 61.9 % |
| 64.6 % |
|
| Long-term debt(a) | 38.1 % |
| 35.1 % |
|
| Short-term debt | -% |
| 0.3 % |
|
| (a) Includes the current portion of long-term debt. |
|
|
|
|
|
| MGE Energy |
| ||
|
| June 30, 2019 |
| December 31, 2018 |
|
| Common shareholders' equity | 61.6 % |
| 61.5 % |
|
| Long-term debt(a) | 36.7 % |
| 37.5 % |
|
| Short-term debt | 1.7 % |
| 1.0 % |
|
(a)Includes the current portion of long-term debt.
MGE Energy'sEnergy's and MGE'sMGE's Capital Requirements
MGE Energy'sEnergy's and MGE'sMGE's liquidity are primarily affected by their capital expenditure requirements. During the ninesix months ended SeptemberJune 30, 2018,2019, capital expenditures for MGE Energy and MGE totaled $149.0$79.1 million, which included $144.5$77.3 million of utility capital expenditures. Included in the utility capital expenditures primarily related toare costs associated with the Two Creeks and Badger Hollow solar construction of the Saratoga wind project and the purchase of Forward Wind.projects.
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Credit Ratings
MGE Energy's and MGE's access to the capital markets, including, in the case of MGE, the commercial paper market, and their respective financing costs in those markets, may depend on the credit ratings of the entity that is accessing the capital markets.
None of MGE Energy'sEnergy's or MGE's borrowings are subject to default or prepayment as a result of a downgrading of credit ratings, although a downgrading of MGE'sMGE's credit ratings could increase fees and interest charges under both MGE Energy's and MGE's credit agreements.
Environmental Matters
The following discussion is limited to updates or developments in environmental matters that occurred during the ninesix months ended SeptemberJune 30, 2018.2019. Further discussion of environmental matters is included in MGE Energy's and MGE's 20172018 Annual Report on Form 10-K and Footnote 9.a. of Notes to Consolidated Financial Statements in this Report.
EPA's Greenhouse Gas (GHG)EPA Affordable Clean Energy (ACE) Rule and Associated Rules Under Section 111(d) of the Clean Air Act (CAA)
In 2015, the EPA finalized the Clean Power Plan (CPP) which directed states to submit plans to reduce greenhouse gas (GHG) emissions from the electric generation sector. In February 2016, the U.S. Supreme Court stayed implementation of the CPP and the stay remains in effect. In October 2017, the EPA issued a proposed rule to repeal the CPP. In August 2018, the EPA proposed the Affordable Clean Energy (ACE) rule which would replace the CPP, if successfully implemented. The ACE proposal directs states to submit plans to the EPA for approval that implement standards of performance (called Best System of Emissions Reductions, or BSER) for individual electric generating units (EGUs) over 25 MW. ACE defines BSER as on-site, heat-rate efficiency improvements, whereas the CPP defines BSERs using carbon dioxide emission performance rates. Simple cycle units such as our smaller combustion units, and combined cycle units such as our WCCF are exempt from the proposed rule. If a state fails to
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prepare a plan, or their plan is not approved by the EPA a federal implementation plan (FIP) will be issued for that state. The proposed ACE as it is currently written has the potential to impact our Blount Generating Station, Columbia, and the Elm Road Units.
MGE cannot yet determine with any certainty the impact of the proposed ACE rule on our operations. MGE previously determined that if the CPP were to be implemented in its present form, it would have a material impact on MGE. MGE will continue to monitor developments with the proposed ACE rule and the CPP rule and litigation.
Ozone NAAQS
In May 2018, the EPA issued a final rule which designated the northeast portion of Milwaukee County as being in nonattainment with the 2015 Ozone National Ambient Air Quality Standards (NAAQS). The Elm Road Units are located in Milwaukee County, yet outside the designated nonattainment area. In August 2018, several environmental groups, the City of Chicago, and the State of Illinois filed federal lawsuits challenging the EPA's attainment designation decisions, including the partial Milwaukee County designation as being too narrow and not sufficiently protective. MGE is monitoring the outcome of this lawsuit and how it may affect our Elm Road Units in Milwaukee County. At this time MGE expects that the 2015 Ozone NAAQS will not have a material effect on its existing plants based on final designations.
The State of Wisconsin has joined a lawsuit filed by several states challenging the EPA's 2015 Ozone NAAQS, alleging that the new standard is not attainable and the EPA is not properly considering background levels in setting its ozone attainment levels. The lawsuit is ongoing; however, the significance of the challenge, as it might relate to MGE, is now diminished with the final ozone attainment designations.
The EPA's Coal Combustion Residuals Rule (CCR)
In July 2018,2019, the EPA published a final rule which repeals the CPP and creates the replacement Affordable Clean Energy (ACE) rule to reduce greenhouse gas emissions from existing EGUs. The ACE rule will apply to Columbia and the Elm Road Units. MGE is currently evaluating how this rule may impact operations. Until the State of Wisconsin develops a plan that included amendmentsis accepted by the EPA, MGE will not be able to determine the Coal Combustion Residuals (CCR) rule which include: the allowance of alternative performance standards for landfills and surface impoundments, revised risk-based groundwater protection standards, and an extensionfinal impact of the deadline by which certain facilities must cease the placement of waste in CCR units. In August 2018, the Court of Appeals for the D.C. Circuit vacated parts of the EPA's CCR rule for not being sufficiently protective of the environment. It is unclear how the EPA will respond to that decision.rule. MGE will continue to evaluate the rule and monitor ongoing and potential rule modifications to assess potential impacts on our operations.legal proceedings associated with the CPP and ACE rules.
Other Matters
ATC
In 2013, several parties filed a complaint with the FERC seeking to reduce the base return on equity (ROE) used by MISO transmission owners, including ATC, "due to changes in the capital markets." The complaint alleged that the MISO ROE should not exceed 9.15%, the equity components of hypothetical capital structures should be restricted to 50%, and the relevant incentive ROE adders should be discontinued. At the time, MISO's base ROE was 12.38% and ATC's base ROE was 12.2%. On September 28, 2016, FERC issued an order on the 2013 complaint, for the period November 2013 through February 2015, reducing the base ROE to 10.32%. This base ROE also became effective September 28, 2016, and will apply to future periods until FERC rules in the second complaint described below, at which time the base ROE ordered by FERC in the second complaint will prospectively become the authorized base ROE.
In February 2015, a second complaint was filed for the period February 2015 through May 2015 with the FERC requesting a reduction in the base ROE used by MISO transmission owners, including ATC, to 8.67%, with a refund effective date retroactive to the filing date of the complaint. In June 2016, an administrative law judge issued an initial decision for the second complaint that would reduce the transmission owner's base ROE to 9.7%. The initial decision will be reviewed by FERC. It is anticipated FERC will issue an order on this issue in 2019. On September 28, 2016, FERC issued an order on the first complaint, for the period November 2013 through February 2015, reducing the base ROE to 10.32%. This base ROE also became effective September 28, 2016, and will apply to future periods until FERC rules in the second complaint, at which time the base ROE ordered by FERC in the second complaint will prospectively become the authorized base ROE. Any change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future.
In January 2015, FERC accepted the transmission owner's request for a 50 basis-point incentive ROE adder for participating in MISO. The adder became effective January 6, 2015.
Our share of ATC's earnings reflects a pre-tax adjustment of $0.2 million for the nine months ended September 30, 2017, recorded by ATC for these matters representing its estimate of its refund liability. There was not a pre-tax expense for the three months ended September 30, 2017. We derived approximately 6.3%8.0% and 7.2%7.5% of our net income for the ninesix months ended SeptemberJune 30, 20182019 and 2017,2018, respectively, from our investment in ATC. Any change to ATC's ROE could result in lower equity earnings and distributions from ATC in the future.
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Adoption of Accounting Principles and Recently Issued Accounting Pronouncements
See Footnote 2 of Notes to Consolidated Financial Statements in this Report for discussion of new accounting pronouncements.
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Item 3. Quantitative and Qualitative Disclosures About Market Risk.
MGE Energy and MGE are potentially exposed to market risk associated with interest rates, commodity prices, and equity returns. MGE currently has no exposure to foreign currency risk. MGE manages some risk exposure through risk management policies and the use of derivative instruments. MGE's risk management policy prohibits speculative trading transactions.
Commodity Price Risk
MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE's electric operations burn natural gas in several of its peaking power plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices. MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel cost, purchased energy costs, and the cost of natural gas.
MGE's electric fuel costs are subject to fuel rules established by the PSCW. The fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs in a year outside of the symmetrical cost tolerance band is determined in the following year and is then reflected in future billings to electric retail customers.Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual electric fuel costs fall outside the lower end of the range and is required to defer costs, less any excess revenues, if the actual electric fuel costs exceed the upper end of the range. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE'sMGE's latest rate order. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. Currently, MGE is subject to a plus or minus 2% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2018,2019, fuel and purchased power costs included in MGE's fuel monitoring level rates are $102.4$77.3 million. See Footnote 10.b. of the Notes to Consolidated Financial Statements in this Report for additional information.
MGE recovers the cost of natural gas in its gas utility segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas.
MGE also reduces price risk caused by market fluctuations via physical contracts and financial derivative contracts, including futures, swaps, options, forwards, and other contractual commitments. The maximum length of time over which cash flows related to energy commodities can be hedged under applicable PSCW approvals is four years.
MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric utility segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds financial transmission rights (FTRs), which are used to hedge the risk of increased transmission congestion charges. As of SeptemberJune 30, 2018,2019, the fair valuecost basis of these instruments exceeded their cost basisfair value by $1.6$0.9 million. Under the PGA clause and electric fuel rules, MGE may include the costs and benefits of the aforementioned fuel price risk management tools in the costs of fuel (natural gas or power). Because these costs/benefits are recoverable, the related unrealized loss/gain has been deferred on the consolidated balance sheets as a regulatory asset/liability.
MGE has also entered into a purchased power agreement that provides MGE with firm capacity and energy that began on June 1, 2012, and ends on May 31, 2022 (the "base term""base term"). The agreement also allows MGE an option to extend the contract after the base term. The agreement is considered a derivative contract and is recognized at its fair value on the consolidated balance sheets. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract as of SeptemberJune 30, 2018,2019, reflects a loss position of $36.3$32.6 million.
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Interest Rate Risk
Both MGE Energy and MGE may have short term borrowings at varying interest rates. MGE issues commercial
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paper for its short-term borrowings, while MGE Energy draws from its current credit facility to meet its short-term borrowing needs. Borrowing levels vary from period to period depending upon capital investments and other factors. Future short-term interest expense and payments will reflect both future short-term interest rates and borrowing levels. MGE Energy and MGE manage interest rate risk by limiting their variable rate exposure and continually monitoring the effects of market changes on interest rates. MGE is not exposed to changes in interest rates on a substantial portion of its long-term debt until that debt matures and is refinanced at market rates.
Equity Price Risk - Pension-Related Assets
MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various investment managers. Changes in market value of these investments can have an impact on the future expenses related to these liabilities.
Credit Risk - Counterparty
Credit risk is the loss that may result from counterparty nonperformance. MGE is exposed to credit risk primarily through its merchant energy business. MGE uses credit policies to manage its credit risk, which include utilizing an established credit approval process, monitoring counterparty limits, employing credit mitigation measures such as collateral or prepayment arrangements, and using netting agreements.
Due to the possibility of extreme volatility in the prices of energy commodities and derivatives, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If such a counterparty were then to fail to perform its obligations under its contract (for example, fail to deliver the electricity MGE originally contracted for), MGE could sustain a loss that could have a material impact on its financial results.
Additionally, if a counterparty were to default and MGE were to liquidate all contracts with that entity, MGE's credit loss would include the loss in value of mark-to-market contracts; the amount owed for settled transactions; and additional payments, if any, to settle unrealized losses. As of SeptemberJune 30, 2018,2019, no counterparties have defaulted.
MGE is obligated to provide service to all electric and gas customers within its respective franchised territories. MGE's franchised electric territory includes a 316264 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,6821,684 square miles in Wisconsin. Based on results for the year ended December 31, 2017,2018, no one customer constituted more than 10% of total operating revenues for MGE Energy and MGE. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.
Cash, cash equivalents, and customer accounts receivable are the financial instruments that potentially subject MGE Energy and MGE to concentrations of credit risk. MGE Energy and MGE place their cash and cash equivalents with high credit-quality financial institutions. MGE has limited concentrations of credit risk from customer accounts receivable because of the large number of customers and relatively strong economy in its service territory.
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Item 4.Controls4. Controls and Procedures.
During the thirdsecond quarter of 2018,2019, each registrant's management, including the principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarization, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed to ensure that material information relating to that registrant, including its subsidiaries, is accumulated and made known to that registrant's management, including these officers, by other employees of that registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and that this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC's rules and forms. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision making can be faulty and breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. Also, MGE Energy does not control or manage certain of its unconsolidated entities and thus, its access and ability to apply its procedures to those entities is more limited than is the case for its consolidated subsidiaries.
As of SeptemberJune 30, 2018,2019, each registrant's principal executive officer and principal financial officer concluded that its disclosure controls and procedures were effective. Each registrant intends to strive continually to improve its disclosure controls and procedures to enhance the quality of its financial reporting.
During the quarter ended SeptemberJune 30, 2018,2019, there were no changes in either registrant'sregistrant’s internal controls over financial reporting that materially affected, or are reasonably likely to affect materially, that registrant'sregistrant’s internal control over financial reporting.
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PART II. OTHER INFORMATION.
Item 1. Legal Proceedings.
MGE Energy and MGE
MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business.
See Footnote 9.a. and 9.b. of Notes to Consolidated Financial Statements in this Report for more information.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.
Issuer Purchases of Equity Securities
Period |
| Total Number of Shares Purchased |
| Average Price Paid per Share |
| Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs* |
| Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs* |
July 1-31, 2018 |
| 9,052 | $ | 64.30 |
| - |
| - |
August 1-31, 2018 |
| 9,411 |
| 65.24 |
| - |
| - |
September 1-30, 2018 |
| 46,167 |
| 67.50 |
| - |
| - |
Total |
| 64,630 | $ | 66.73 |
| - |
| - |
Period |
| Total Number of Shares Purchased |
| Average Price Paid per Share |
| Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(a) |
| Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs(a) |
April 1-30, 2019 |
| 8,873 | $ | 67.51 |
| - |
| - |
May 1-31, 2019 |
| 6,553 |
| 68.02 |
| - |
| - |
June 1-30, 2019 |
| 40,700 |
| 70.09 |
| - |
| - |
Total |
| 56,127 | $ | 69.44 |
| - |
| - |
*(a) Under the MGE Energy, Inc. Direct Stock Purchase and Dividend Reinvestment Plan (Stock Plan), common stock shares deliverable to plan participants may be either newly issued shares or shares purchased on the open market, as determined from time to time by MGE Energy. MGE Energy's transfer agent uses open market purchases to provide shares to meet obligations to participants in the Stock Plan. The shares are purchased on the open market through the transfer agent's securities broker-dealer and then are reissued under the Stock Plan as needed to meet share delivery requirements. The volume and timing of share repurchases in the open market depends upon the level of dividend reinvestment and optional share purchases being made from time to time by plan participants. As a result, there is no specified maximum number of shares to be repurchased and no specified termination date for the repurchases. All shares issued through the Stock Plan, whether newly issued or reissued following open market purchases, are issued and sold pursuant to a registration statement that was filed with the SEC and is currently effective.
Item 4. Mine Safety Disclosures.
Not applicable to MGE Energy and MGE.
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Item 6. Exhibits.
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Ex. No. | Exhibit Description | |
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* | ||
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| Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for MGE Energy, Inc. | |
31.2 | * | Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey C. Newman for MGE Energy, Inc. |
31.3 | * | Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey M. Keebler for Madison Gas and Electric Company |
31.4 | * | Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934 filed by Jeffrey C. Newman for Madison Gas and Electric Company |
32.1 | ** | Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for MGE Energy, Inc. |
32.2 | ** | Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey C. Newman for MGE Energy, Inc. |
32.3 | ** | Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey M. Keebler for Madison Gas and Electric Company |
32.4 | ** | Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) filed by Jeffrey C. Newman for Madison Gas and Electric Company |
101.INS | * | XBRL Instance |
101.SCH | * | XBRL Taxonomy Extension Schema |
101.CAL | * | XBRL Taxonomy Extension Calculation |
101.DEF | * | XBRL Taxonomy Extension Definition |
101.LAB | * | XBRL Taxonomy Extension Labels |
101.PRE | * | XBRL Taxonomy Extension Presentation |
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* |
| Filed herewith. |
| Furnished herewith. |
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Signatures - MGE Energy, Inc.
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
MGE ENERGY, INC. | |
Date: | /s/ Jeffrey M. Keebler |
Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer) | |
Date: | /s/ Jeffrey C. Newman |
Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer) |
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Signatures - Madison Gas and Electric Company
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
MADISON GAS AND ELECTRIC COMPANY | |
Date: | /s/ Jeffrey M. Keebler |
Jeffrey M. Keebler Chairman, President and Chief Executive Officer (Duly Authorized Officer) | |
Date: | /s/ Jeffrey C. Newman |
Jeffrey C. Newman Executive Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer) |
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