United States
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
[X] Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the quarterly period ended:
September 30, 2011
[ ] Transition report 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, Wisconsin 53703
(608) 252-7000
www.mgeenergy.com
39-2040501
000-1125
Madison Gas and Electric Company
www.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 was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days: Yes [X] No [ ]
Indicate by check mark whether the registrants have submitted electronically and posted on its corporate Web site, 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 registrant was required to submit and post such files):
Yes [X] No [ ]
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of "large accelerated filer," "accelerated filer," and "smaller reporting company" in Rule 12b-2 of the Exchange Act.
Large Accelerated Filer
Accelerated Filer
Non-accelerated Filer
Smaller Reporting Company
X
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act):
MGE Energy, Inc. and Madison Gas and Electric Company: Yes [ ] No [X]
Number of Shares Outstanding of Each Class of Common Stock as of October 31, 2011
Common stock, $1.00 par value, 23,113,638 shares outstanding.
Common stock, $1.00 par value, 17,347,894 shares outstanding (all of which are owned beneficially and of record by MGE Energy, Inc.).
1
Table of Contents
PART I. FINANCIAL INFORMATION.
3
Filing Format
Forward-Looking Statements
Where to Find More Information
Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report
4
Item 1. Financial Statements.
5
Consolidated Statements of Income (unaudited)
Consolidated Statements of Cash Flows (unaudited)
6
Consolidated Balance Sheets (unaudited)
7
Consolidated Statements of Common Equity (unaudited)
8
9
10
11
12
MGE Energy, Inc., and Madison Gas and Electric Company
13
Notes to Consolidated Financial Statements (unaudited)
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.
34
Item 3. Quantitative and Qualitative Disclosures About Market Risk.
51
Item 4. Controls and Procedures.
53
PART II. OTHER INFORMATION.
54
Item 1. Legal Proceedings.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.
Item 6. Exhibits.
Signatures - MGE Energy, Inc.
55
Signatures - Madison Gas and Electric Company
56
2
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.
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 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," 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 (a) include those factors discussed in the Registrants' 2010 Annual Report on Form 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 18, 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 undertake no obligation to publicly release any revision to these forward-looking statements to reflect events or circumstances after the date of this report.
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 at http://www.sec.gov, MGE Energy's website at http://www.mgeenergy.com, and MGE's website at http://www.mge.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.
Abbreviations, acronyms, and definitions used in the text and notes of this report are defined below.
AFUDC
Allowance for Funds Used During Construction
ATC
American Transmission Company LLC
BACT
Best Available Control Technology
Blount
Blount Station
CAA
Clean Air Act
CAIR
Clean Air Interstate Rule
Codification
Financial Accounting Standards Board Accounting Standards Codification
Columbia
Columbia Energy Center
cooling degree days
Measure 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
CSAPR
Cross-State Air Pollution Rule
CWDC
Central Wisconsin Development Corporation
DOE
U.S. Department of Energy
Dth
Dekatherms
Elm Road Units
Elm Road Generating Station
EPA
United States Environmental Protection Agency
ERISA
Employee Retirement Income Security Act
EGU
Electric Generating Unit
FASB
Financial Accounting Standards Board
FERC
Federal Energy Regulatory Commission
FTR
Financial Transmission Rights
GHG
Greenhouse Gas
HAPs
Hazardous Air Pollutants
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
ICI Boilers
Industrial, Commercial, or Institutional Boilers
IRS
Internal Revenue Service
kWh
Kilowatt-hour
MACT
Maximum Achievable Control Technology
MAGAEL
MAGAEL, LLC
MGE
MGE Construct
MGE Construct LLC
MGE Energy
MGE Power
MGE Power LLC
MGE Power Elm Road
MGE Power Elm Road, LLC
MGE Power West Campus
MGE Power West Campus, LLC
MGE Transco
MGE Transco Investment LLC
MISO
Midwest Independent System Operator (a regional transmission organization)
MW
Megawatt
MWh
Megawatt-hour
NAAQS
National Ambient Air Quality Standards
NO2
Nitrogen Dioxide
NOV
Notice of Violation
NOx
Nitrogen Oxides
NSPS
New Source Performance Standards
OPRB
Other Postretirement Benefits
PGA
Purchased Gas Adjustment clause
PJM
PJM Interconnection, LLC (a regional transmission organization)
PM
Particulate Matter
PPA
Purchased power agreement
PSCW
Public Service Commission of Wisconsin
PSD
Prevention of Significant Deterioration
SEC
Securities and Exchange Commission
SIP
State Implementation Plan
SO2
Sulfur Dioxide
Stock Plan
Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW
University of Wisconsin at Madison
VIE
Variable Interest Entity
WCCF
West Campus Cogeneration Facility
WDNR
Wisconsin Department of Natural Resources
WEPCO
Wisconsin Electric Power Company
Working capital
Current assets less current liabilities
WPDES
Wisconsin Pollutant Discharge Elimination System
WPL
Wisconsin Power and Light Company
WPSC
Wisconsin Public Service Corporation
(In thousands, except per-share amounts)
Three Months Ended
Nine Months Ended
September 30,
2011
2010
Operating Revenues:
Regulated electric revenues
$
114,963
109,849
291,804
279,281
Regulated gas revenues
17,249
17,394
119,748
114,231
Nonregulated revenues
1,360
695
3,884
3,151
Total Operating Revenues
133,572
127,938
415,436
396,663
Operating Expenses:
Fuel for electric generation
16,656
12,622
39,304
31,765
Purchased power
18,024
18,603
49,997
56,537
Cost of gas sold
8,171
8,300
72,170
70,776
Other operations and maintenance
39,744
40,403
119,814
120,126
Depreciation and amortization
10,296
9,560
30,669
28,263
Other general taxes
4,347
4,098
13,053
12,947
Total Operating Expenses
97,238
93,586
325,007
320,414
Operating Income
36,334
34,352
90,429
76,249
Other income, net
2,341
2,646
6,880
9,314
Interest expense, net
(5,142)
(4,099)
(15,047)
(12,052)
Income before income taxes
33,533
32,899
82,262
73,511
Income tax provision
(12,495)
(12,990)
(30,718)
(27,790)
Net Income
21,038
19,909
51,544
45,721
Earnings Per Share of Common Stock
(basic and diluted)
0.91
0.86
2.23
1.98
Dividends per share of common stock
0.383
0.375
1.133
1.112
Average Shares Outstanding
23,114
The accompanying notes are an integral part of the above unaudited consolidated financial statements.
(In thousands)
Operating Activities:
Net income
Items not affecting cash:
Deferred income taxes
16,854
9,229
Provision for doubtful receivables
1,441
1,785
Employee benefit plan expenses
10,259
9,068
Equity earnings in ATC
(6,434)
(6,374)
Gain on sale of property
(74)
(3,129)
Other items
1,118
1,648
Changes in working capital items:
Decrease in current assets
27,868
27,514
Decrease in current liabilities
(10,547)
(10,639)
Dividend income from ATC
5,012
5,000
Cash contributions to pension and other postretirement plans
(22,484)
(15,333)
Other noncurrent items, net
1,299
4,627
Cash Provided by Operating Activities
106,525
97,380
Investing Activities:
Capital expenditures
(44,859)
(43,236)
Capital contributions to investments
(958)
(583)
Purchase of investment - land
(2,152)
-
Proceeds from sale of property
74
3,334
Other
(249)
Cash Used for Investing Activities
(47,889)
(40,734)
Financing Activities:
Cash dividends paid on common stock
(26,183)
(25,700)
Repayment of long-term debt
(1,834)
(1,111)
Issuance of long-term debt
30,000
50,000
Decrease in short-term debt
(22,500)
(66,000)
(336)
(1,008)
Cash Used for Financing Activities
(20,853)
(43,819)
Change in Cash and Cash Equivalents:
37,783
12,827
Cash and cash equivalents at beginning of period
7,110
4,704
Cash and cash equivalents at end of period
44,893
17,531
The accompanying notes are an integral part of the unaudited consolidated financial statements.
December 31,
ASSETS
Current Assets:
Cash and cash equivalents
Receivable - margin account
3,528
2,501
Accounts receivable, less reserves of $3,868 and $3,994, respectively
35,115
40,153
Other accounts receivable, less reserves of $476 and $595, respectively
4,157
4,082
Unbilled revenues
19,113
29,220
Materials and supplies, at average cost
17,103
17,642
Fossil fuel
5,817
6,758
Stored natural gas, at average cost
21,832
22,839
Prepaid taxes
11,209
22,496
Regulatory assets - current
2,866
1,732
Other current assets
8,030
7,769
Total Current Assets
173,663
162,302
Regulatory assets
121,337
121,085
Other deferred assets and other
11,546
10,654
Property, Plant, and Equipment:
Property, plant, and equipment, net
955,646
857,572
Construction work in progress
29,850
110,435
Total Property, Plant, and Equipment
985,496
968,007
Investments
59,873
55,845
Total Assets
1,351,915
1,317,893
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year
2,667
1,667
Short-term debt
22,500
Accounts payable
26,381
32,555
Accrued interest and taxes
5,407
3,990
Accrued payroll related items
9,016
8,525
2,398
Other current liabilities
7,278
9,577
Total Current Liabilities
52,481
81,212
Other Credits:
184,668
166,774
Investment tax credit - deferred
1,855
2,081
Regulatory liabilities
21,146
23,772
Accrued pension and other postretirement benefits
107,640
123,648
Other deferred liabilities and other
72,136
60,975
Total Other Credits
387,445
377,250
Capitalization:
Common shareholders' equity
550,433
525,080
Long-term debt
361,556
334,351
Total Capitalization
911,989
859,431
Commitments and contingencies (see Footnote 9)
Total Liabilities and Capitalization
Accumulated
Additional
Common Stock
Paid-in
Retained
Comprehensive
Shares
Value
Capital
Earnings
(Loss)/Income
Total
Beginning balance - December 31, 2009
316,268
162,208
205
501,795
Other comprehensive income/(loss):
Unrealized loss on available-for-sale
securities, net of $48 tax
(71)
Common stock dividends declared
($1.112 per share)
Ending balance - September 30, 2010
182,229
134
521,745
Beginning balance - December 31, 2010
185,556
142
Unrealized gain on available-for-sale
securities, net of $4 tax
Reclassification of realized gain on
available-for-sale securities, net of
$10 tax
(15)
($1.133 per share)
Ending balance - September 30, 2011
210,917
39,558
40,147
119,162
119,522
11,525
11,993
28,082
24,096
108,577
105,323
352,437
343,906
24,995
22,615
62,999
52,757
Other Income and Deductions:
AFUDC - equity funds
101
97
304
222
Equity in earnings in ATC
2,167
2,092
6,434
6,374
(933)
(1,117)
(2,689)
(3,894)
(56)
461
(217)
2,716
Total Other Income and Deductions
1,279
1,533
3,832
5,418
Income before interest expense
26,274
24,148
66,831
58,175
Interest Expense:
Interest on long-term debt
5,214
4,755
15,428
14,028
Other interest, net
(670)
(244)
(1,815)
AFUDC - borrowed funds
(40)
(38)
(123)
(87)
Net Interest Expense
5,182
4,047
15,061
12,126
21,092
20,101
51,770
46,049
Less Net Income Attributable to Noncontrolling Interest, net of tax
(6,010)
(5,108)
(17,935)
(15,104)
Net Income Attributable to MGE
15,082
14,993
33,835
30,945
16,160
9,239
1,542
2,049
26,349
19,201
(10,407)
(1,127)
1,238
2,532
105,041
97,223
(888)
(533)
299
(45,374)
(40,427)
Cash dividends paid to parent by MGE
(19,921)
(19,553)
Distributions to parent from noncontrolling interest
(43,000)
(50,293)
Equity contribution received by noncontrolling interest
888
533
Affiliate financing of Elm Road
(4,193)
(3,500)
(19,000)
(297)
(850)
(37,664)
(44,467)
22,003
12,329
4,494
2,474
26,497
14,803
34,179
Affiliate receivables
568
638
4,155
4,063
11,793
21,500
7,995
7,742
155,446
159,282
Affiliate receivable long-term
7,016
7,413
9,858
8,337
955,144
857,442
984,994
967,877
57,086
54,947
1,335,737
1,318,941
3,500
26,378
32,524
Affiliate payables
2,475
24
6,397
7,294
7,148
9,472
55,813
65,404
181,580
164,399
60,977
384,357
374,877
416,195
402,316
Noncontrolling interest
117,816
141,993
Total Equity
534,011
544,309
895,567
878,660
Non-
Controlling
Interest
Beginning balance - Dec. 31, 2009
17,348
192,417
180,905
112
178,943
569,725
15,104
securities, net of $32 tax
(48)
Cash dividends paid to parent
by MGE
Equity contribution received by
noncontrolling interest
Distributions to parent from
192,297
64
144,287
546,413
Beginning balance - Dec. 31, 2010
192,480
71
17,935
securities, net of $14 tax
(20)
206,394
36
1.
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 West Campus and MGE Power Elm Road own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power West Campus and MGE Power Elm Road.
The accompanying consolidated financial statements as of September 30, 2011, and for the three and nine 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 MGE Energy's and MGE's 2010 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 55 through 109 of the 2010 Annual Report on Form 10-K.
2.
Equity and Financing Arrangements.
a.
Common Stock - MGE Energy.
MGE Energy purchases stock in the open market for issuance pursuant to its Stock Plan. All MGE Energy common stock issued under the Stock Plan is sold pursuant to a registration statement that has been filed with the SEC and is currently effective.
MGE Energy can issue new shares of its common stock through the Stock Plan. For both the nine months ended September 30, 2011 and 2010, MGE Energy did not issue any new shares of common stock under the Stock Plan.
b.
Dilutive Shares Calculation - MGE Energy.
MGE Energy does not hold any dilutive securities.
c.
Secured Debt - MGE Energy and MGE.
On February 28, 2011, MGE Power Elm Road issued $30 million of 4.74% senior secured notes due February 25, 2041. MGE Power Elm Road distributed the net proceeds from the sale of notes to MGE Energy, which used that distribution to repay existing short-term indebtedness, consisting of bank loans, which were used to finance a portion of the construction of the Elm Road Units. The notes provide for monthly principal and interest payments, which commenced on March 25, 2011, and continue until maturity. The principal payments are level over the life of the notes. The Note Purchase Agreement requires MGE Power Elm Road to maintain a debt service coverage ratio at the end of any calendar quarter of not less than 1.25 to 1.00 for the trailing 12-month period. The debt is secured by a collateral assignment of lease payments that MGE is making to MGE Power Elm Road for use of the Elm Road Units pursuant to long-term leases. As of September 30, 2011, MGE Power Elm Road is in compliance with the covenant requirements.
d.
Credit Facilities - MGE Energy and MGE.
On August 1, 2011, each of MGE Energy and MGE entered into an amendment to its existing credit agreement dated as of July 30, 2010, with various financial institutions and JPMorgan Chase Bank, N.A., as administrative agent. The existing credit agreements provide MGE Energy with a $40 million revolving credit facility and MGE with a $75 million revolving credit facility. As of September 30, 2011, MGE Energy had no borrowings outstanding and MGE had no commercial paper outstanding.
The principal purpose of the amendments was to extend the termination date of the credit agreements by two years to July 31, 2015. The amendments also lowered the commitment fees, letter of credit fees and interest rate adders under the credit agreements. Borrowings under each credit agreement may bear interest at a rate that floats daily based upon a prime rate, or at a rate fixed for a specified interest period based upon a LIBOR-based index, in each case plus an adder based upon the senior unsecured credit rating for MGE. Based upon MGE's current senior unsecured credit rating, the adder is zero for prime rate-based borrowings and 0.850% for LIBOR-based borrowings.
3.
Comprehensive Income - MGE Energy and MGE.
Total comprehensive income represents the change in equity during a period from transactions and other events and circumstances from nonowner sources. MGE Energy's and MGE's total comprehensive income is:
Unrealized gain (loss) on available-for-sale securities, net of tax ($50 and $6, and $4 and $48)
Reclassification of realized gain on available-for-sale securities, net of tax ($- and $-, and $10 and $-)
Total comprehensive income
20,964
19,918
51,536
45,650
Unrealized gain (loss) on available-for-sale securities, net of tax ($35 and $2, and $14 and $32)
(52)
21,040
20,105
51,735
46,001
Less: Comprehensive income attributable to noncontrolling interest
Comprehensive income attributable to MGE
15,030
14,997
33,800
30,897
4.
Investment in ATC - 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. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE.
MGE Transco has accounted for its investment in ATC under the equity method of accounting. For both the nine months ended September 30, 2011 and 2010, MGE Transco recorded equity earnings from the investment in ATC of $6.4 million. Dividend income received from ATC was $5.0 million for both the nine months ended September 30, 2011 and 2010. In addition, during the nine months ended September 30, 2011 and 2010, MGE Transco made $0.9 million and $0.5 million, respectively, in capital contributions to ATC.
MGE Energy and MGE's investment in ATC as of September 30, 2011 and December 31, 2010 was $56.5 million and $54.2 million, respectively.
During March 2010, MGE sold a parcel of land in Middleton, Wisconsin to ATC for $2.7 million, resulting in a gain of $2.6 million (pretax) in other income. The transaction was approved by the PSCW.
14
At September 30, 2011, MGE is the majority owner, and MGE Energy, the holding company, is the minority owner of MGE Transco. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as noncontrolling interest.
ATC's summarized financial data for the three and nine months ended September 30, 2011 and 2010, is as follows:
Operating revenues
142,741
136,889
420,562
414,046
Operating expenses
(66,413)
(59,732)
(192,491)
(185,067)
Other expense, net
(173)
(609)
(665)
(1,428)
(19,517)
(21,530)
(60,893)
(63,361)
Earnings before members' income taxes
56,638
55,018
166,513
164,190
5.
Taxes - MGE Energy and MGE.
Accounting for Uncertainty in Income Taxes.
MGE Energy and MGE account for the difference between the tax benefit amount taken on prior year tax returns, or expected to be taken on a current year tax return, and the tax benefit amount recognized in the financial statements as an unrecognized tax benefit.
MGE Energy has changed its tax method of accounting for repairs, the 2010 tax return for gas repairs and the 2009 tax return for electric repairs. This method change accelerates tax deductions for repairs in accordance with Treasury Regulations and case law, as compared to the prior method of claiming tax depreciation on project costs. MGE Energy and MGE have an unrecognized tax benefit at September 30, 2011 and December 31, 2010, in the amount of $5.2 million and $4.4 million, respectively, for the tax uncertainty primarily related to the change in tax method of accounting for repairs.
Effective Tax Rate.
MGE Energy's effective income tax rate for the three and nine months ended September 30, 2011, are 37.3% and 37.3%, respectively, compared to 39.5% and 37.8% for the same periods in 2010; and MGE's effective income tax rate for the three and nine months ended September 30, 2011, are 37.1% and 37.3%, respectively, compared to 39.5% and 37.8% for the same periods in 2010. The lower effective tax rate is, in part, attributable to a higher estimated domestic manufacturing deduction.
6.
Elm Road - MGE Energy and MGE.
MGE Power Elm Road owns an 8.33% ownership interest in each of two 615 MW coal-fired generating units in Oak Creek, Wisconsin. Unit 1 entered commercial operation in February 2010. Unit 2 entered commercial operation in January 2011. MGE Power Elm Road's sole principal asset is that ownership interest in those generating units. Each generating unit owner provides its own financing and reflects its respective portion of the facility and costs in its financial statements. MGE Power Elm Road has leased the Elm Road Units to MGE pursuant to separate facility lease agreements for each unit. These leases were authorized by order of the PSCW in accordance with applicable provisions of Wisconsin law that authorized financing of new generation through facility leases. The PSCW order establishes a cap on the construction costs that may be passed through the lease agreements to MGE and its customers, through rates. Additional costs attributable to force majeure events, as defined in the leases, do not count against this cap, but are subject to PSCW review and determination that the costs were prudently incurred.
As of September 30, 2011, $195.8 million (including capitalized interest) related to this project was placed in-service on MGE Energy's and MGE's consolidated balance sheets.
MGE has approval from the PSCW to defer the recovery of the payments made to MGE Power Elm Road for carrying costs during construction of the generating units. The total carrying costs on the Elm Road Units is $62.2 million.
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MGE began collecting the carrying costs in rates in 2006. These amounts are being collected over multiple years. Of these costs, $17.0 million relates to the capitalized interest and the debt portion of the units. These costs will be recognized over the period in which the generating units will be depreciated. The remaining $45.2 million represents the equity portion and is being recognized over the period allowed for recovery in rates.
During 2011, MGE will recover $4.8 million in carrying costs associated with the Elm Road Units. For the nine months ended September 30, 2011, $3.6 million related to the carrying costs were recovered in rates. Of this amount, $0.7 million relates to the debt portion of the units and was deferred on the consolidated financial statements of MGE Energy and MGE. The remaining $2.9 million represents the equity portion and was recognized as nonregulated revenues in the consolidated financial statements of MGE Energy and MGE.
7.
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 deferred contribution 401(k) benefit plans.
The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months ended September 30, 2011 and 2010. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets. The PSCW allowed MGE to defer the 2009 incremental pension and OPRB costs above the amounts recovered in rates. During both the three months ended September 30, 2011 and 2010, $0.7 million has been recovered in rates. During both the nine months ended September 30, 2011 and 2010, $2.0 million has been recovered in rates.
Pension Benefits
Components of net periodic benefit cost:
Service cost
1,527
1,469
4,581
4,406
Interest cost
3,055
2,912
9,165
8,734
Expected return on assets
(3,502)
(2,848)
(10,507)
(8,541)
Amortization of:
Prior service cost
108
106
324
318
Actuarial loss
939
839
2,816
2,517
Net periodic benefit cost
2,127
2,478
6,379
7,434
Postretirement Benefits
500
463
1,501
1,389
1,010
948
3,028
2,844
(407)
(296)
(1,221)
Transition obligation
110
102
329
307
28
27
85
80
114
342
316
1,355
1,350
4,064
4,048
8.
Share-Based Compensation - MGE Energy and MGE.
Under MGE Energy's Performance Unit Plan, eligible participants 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 set performance period.
In addition to units granted in 2007 through 2010, on January 21, 2011, 15,655 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule. On the grant date, MGE Energy and MGE measured the cost of the employee services received in exchange for the award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at September 30, 2011, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount will be re-measured throughout the vesting period, the compensation cost is subject to variability.
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For nonretirement eligible employees, 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 also using the graded vesting method.
In April 2011, the MGE Energy Board approved an amendment to the outstanding awards under the Performance Unit Plan to provide for the continued vesting of those awards in the event of a bona fide retirement, provided the retired individual does not provide services to a competitor. The amendment did not change the number of performance units covered by any outstanding awards currently held by any of the participants.
As a result of the changes made by the amendment, the Company accelerated the recognition of costs associated with the outstanding awards resulting in a compensation-related charge of $0.5 million in the second quarter of 2011.
During the nine months ended September 30, 2011 and 2010, MGE recorded $0.9 million and $0.8 million, respectively, in compensation expense as a result of the Performance Unit Plan. In January 2011, cash payments of $0.5 million were distributed relating to awards that became payable under the 2006 Performance Unit Plan. No forfeitures occurred during the nine months ended September 30, 2011 or 2010. At September 30, 2011, $2.2 million of these awards were vested.
9.
Commitments and Contingencies.
Environmental - MGE Energy and MGE.
Solid waste
Lenz Oil Site
MGE is listed as a potentially responsible party for a site on the EPA's national priorities Superfund list. The Lenz Oil site in Lemont, Illinois, was used for storing and processing waste oil for several years. This site requires cleanup under the Comprehensive Environmental Response, Compensation and Liability Act. The remedy includes a five year $2.2 million implementation plan. The EPA asked all potentially responsible parties to pay upfront for this plan. MGE has paid its share; however, the cleanup process has not begun. We will not know if additional costs exist at the site until cleanup is completed. At September 30, 2011, MGE's portion of the plan costs is less than $0.1 million. Management believes that its share of the final cleanup costs for the Lenz Oil site will not result in any materially adverse effects on MGE's operations, cash flows, or financial position. Insurance may cover a portion of the cleanup costs. Management believes that any cleanup costs not covered by insurance will be recovered in current and future rates.
Proposed Regulation of Coal Combustion Byproducts
The EPA published a proposed rule on May 4, 2010, that would regulate coal combustion byproducts from the electric generating sector. If adopted, the proposed regulations may require new or additional monitoring of storage sites, may re-classify ash and other coal combustion byproducts, and may regulate ash storage site structural design. MGE is following developments on this proposed rule and evaluating the impact of these proposed regulations on our operations and cannot estimate the potential costs until the rule is final.
Water quality
MGE is subject to water quality regulations issued by the WDNR. These regulations include discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies under compliance schedules established under the Federal Water Pollution Control Act. The WDNR has published categorical regulations for chemical and thermal discharges from electric-steam generating plants. These regulations limit discharges from MGE's plants into Lake Monona and other Wisconsin waters.
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EPA Cooling Water Intake Rules (Section 316(b))
On March 28, 2011, the EPA proposed and asked for public comment on standards to reduce entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) from existing structures designed to take in cooling water for plants such as power plants. This rule is commonly referred to as Phase II of Section 316(b). The proposed rule includes provisions for structures designed to take in as little as two million gallons per day. Both our Blount and Columbia generating plants are subject to the impingement and entrainment aspects of the current proposed rule. Our WCCF plant is subject to the impingement aspect only under the current proposed rule. MGE is following developments on this proposed rule and evaluating the impact of these proposed regulations on our operations and cannot estimate the potential costs until the rule is final.
WPDES Thermal Discharge Rule
WDNR rules to regulate thermal effluent discharges from point sources in Wisconsin became effective on October 1, 2010. As MGE's WPDES permits are issued or renewed, it will need to meet the revised rule requirements. MGE submitted a thermal analysis with its most recent Blount WPDES permit application that showed thermal impacts within the acceptable limits of the rule. MGE obtained positive preliminary feedback in July 2011 from the WDNR regarding the analysis but is waiting for a final determination. Final determination is expected to occur in 2012. If the WNDR does not concur with MGE's analysis, additional studies could be required.
WPDES Phosphorus Nutrient Standards
The WDNR is in the process of developing water quality standards for phosphorus in streams, rivers, and inland lakes, including effluent limitations for dischargers. Blount and WCCF both currently discharge phosphorus under their WPDES permits, and it is likely both facilities may have phosphorus limitations added to their permits. It is unclear at this time if current phosphorus use at our plants will meet the implementation of future standards. MGE has however identified potential compliance options and believe this can be managed without significant capital investments.
WPDES Mercury Discharge Limit
WPDES permit holders in certain industries, including coal-fired electric power plants, are required to meet mercury effluent limits. If permit holders do not meet the mercury limits, then they must apply for a variance as part of their next permit renewal with the WDNR. MGE has applied for a mercury variance for Blount as part of its permit renewal, which was submitted in the fall of 2010. In July 2011, MGE received positive preliminary feedback from the WDNR regarding the variance but is waiting for a final determination. Final determination is expected to occur in 2012. If the variance is not approved, MGE may have operational or capital costs associated with meeting the mercury effluent limits when the permit is renewed. We cannot estimate the effect that compliance with developing mercury water quality standards will have on the operation of our generating facilities and our future results of operations, cash flows, and financial position.
Air quality
Air quality regulations promulgated by the EPA and the WDNR in accordance with the Federal Clean Air Act and the Clean Air Act Amendments of 1990 impose restrictions on emission of particulates, sulfur dioxide (SO2), nitrogen oxides (NOx), and other pollutants and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically.
Various initiatives, including the EPA's Cross-State Air Pollution Rule, maximum achievable control technology (MACT) standards, new source performance standards (NSPS) and the Clean Air Visibility Rule (also known as the Regional Haze Rule), as well as state mercury emissions limits, may result in additional operating and capital expenditure costs for electric generating units.
Maximum Achievable Control Technologies (MACT) and National Emissions Standards for Hazardous Air Pollutants
On March 16, 2011, the EPA proposed and asked for public comments on pollution control standards to limit mercury, acid gases and other hazardous air pollutants from new and existing electric generating units (EGU) in power plants. This proposed rule is commonly referred to as EGU MACT. The current version of this proposed rule establishes numerical limits for HAPs, work practice methods, and other standards based on several defined subcategories of EGUs. MGE's generating facilities should meet MACT criteria under the current proposed rule. The EPA has indicated that they will be delaying the release of the final rule for 30 days and has set December 16, 2011 as the release date. MGE cannot fully evaluate the operational and financial impacts of this rule until it is finalized.
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On March 21, 2011, the EPA finalized its MACT rule for industrial, commercial and institutional (ICI) boilers commonly referred to as Boiler MACT. The final rule includes provisions for ICI boilers that burn fossil fuels including coal, oil and natural gas. MGE owns some smaller natural gas and oil-burning boilers that are governed by this rule. Although the EPA has finalized this rule, it has also indicated that the finalized rule is under evaluation and has offered potential revisions to this rule. MGE cannot fully evaluate the operational or financial impacts of this rule until the revisions are settled.
EPA's Cross-State Air Pollution Rule, Formerly the Proposed Transport Rule (To Replace the Clean Air Interstate Rule (CAIR))
In July 2011, the EPA issued the final CAIR replacement rule, referred to as Cross-State Air Pollution Rule (CSAPR) (formerly known as the "Transport Rule"). CSAPR requires SO2 and NOx emissions reductions from emission sources located in 27 states in the eastern half of the U.S. CSAPR affects fossil-fueled EGUs in Wisconsin with greater than 25 MW of capacity. Existing CAIR compliance requirements remain effective through 2011. Beginning in 2012, CSAPR establishes state emission budgets for SO2 and NOx (Phase I). These SO2 and NOx emission budgets will be lowered further in 2014 (Phase II).
In addition, the EPA establishes enforceable state-wide emission caps. These caps limit the amount of emissions trading allowed to meet compliance requirements. Plants in Wisconsin that are subject to CSAPR will need to hold sufficient allowances to cover emissions. The emission allowances used for Acid Rain and CAIR program compliance cannot be used for compliance with CSAPR. If allowances are not adequate, emissions will need to be reduced at the plant level by fuel-switching, installation of controls, curtailment of operations or a combination thereof. CSAPR's 2012 emission caps for the State of Wisconsin are significantly lower than Wisconsin's recent annual emissions. Given this, it is anticipated that the number of allowances available for trading within Wisconsin will be quite restricted in 2012.
The EPA announced on October 6, 2011 that it would be revising the CSAPR state budget for a handful of states, including Wisconsin, to adjust for certain technical discrepancies. Although the proposed revision will increase Wisconsin's allocations, a significant deficiency will still remain. The proposed supplemental rule also amends the assurance penalty provisions so they start in 2014, instead of 2012 to promote the development of allowance market liquidity. Numerous legal challenges to CSAPR have been filed seeking to stay the effectiveness of the rule.
In July 2011, the EPA also issued a supplemental proposed rule that would expand the scope of the CSAPR ozone season NOx emission reduction program to add six states, including Wisconsin.
MGE has been evaluating CSAPR and the supplemental proposed rule and will adjust environmental compliance plans as needed. The Columbia generating facility which is operated by WPL (MGE has a 22% ownership interest) has significantly fewer SO2 allocations than recent actual emissions. Planned new SO2 controls at Columbia will not be completed until mid 2014. MGE's share of this project will be approximately $140 million. Other interim operational strategies are being evaluated by the co-owners of Columbia to address anticipated SO2 allowance deficiencies in 2012. Either additional allowances, if available, will likely need to be purchased or Columbia generation will likely need to be reduced to comply with CSAPR limits in 2012. MGE expects that the costs pertaining to this project will be fully recoverable through rates.
National Ambient Air Quality Standards (NAAQS) for Ozone, Nitrogen Dioxide and Sulfur Dioxide
The EPA has developed National Ambient Air Quality Standards (NAAQS) for six compounds currently identified as criteria pollutants: nitrogen dioxide (NO2), particulate matter (PM), ozone, SO2, lead and carbon monoxide. The NAAQS for criteria pollutants establish acceptable ambient air levels based on effects to human health and the environment, and changes to those NAAQS can affect compliance requirements and associated capital and operating costs. The EPA is required to review NAAQS every five years. MGE is currently tracking two NAAQS developments: (1) modeling requirements for the EPA's January 2010 final revisions to NO2 NAAQS, and (2) the WDNR's attainment/nonattainment designations associated with the EPA's June 2010 final revisions to its SO2 NAAQS. These two NAAQS developments have a potential material affect on capital and maintenance costs at our generating facilities.
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Current Climate Change Regulations
On May 13, 2010, the EPA released its final Prevention of Significant Deterioration (PSD) revisions and its Title V Greenhouse Gas "Tailoring Rule" under Section 111 of the Clean Air Act (CAA). Under these rule revisions, facilities that meet a 25,000 metric ton GHG threshold would need to obtain or modify their Title V air permits during their next permit renewal to include GHGs as permitted air emissions. New or modified facilities meeting additional GHG (and other air emissions) thresholds would need to request a revision to their permit under PSD and apply best available control technologies (BACT) to minimize their releases of GHG emissions. Current technologies for minimizing GHGs are scarce. As these technologies advance, meeting BACT may require substantial capital expenditures and additional permitting requirements may be developed under this section of the CAA.
In September 2011, the EPA announced a delay of its proposed rules for GHG New Source Performance Standards (NSPS) for power plants and refineries until sometime after September 30, 2011. The rules have not yet been published. The EPA's September deadline is the result of a settlement agreement that set the proposed rule release as September 30, 2011 and the final rule release as May 26, 2012. The EPA originally planned to issue the standards by July 26, 2011. MGE cannot evaluate the operational and financial impacts of this rule until it is finalized.
MGE and two other utilities jointly own Columbia, a coal-fired generating facility, which accounts for 225 MW (27%) of MGE's net generating capability. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. Wisconsin Public Service Corporation (WPSC) owns a 31.8% interest, and MGE owns a 22% interest in Columbia. Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia and may affect those expenditures at other MGE generating facilities.
Certificate of Authority
On March 11, 2011, the PSCW issued a Certificate and Order authorizing the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. The operator's current estimate shows that MGE's share of the capital expenditures required to comply with this project will be approximately $140 million. As of September 30, 2011, MGE had incurred $1.4 million (excluding carrying costs) in deferred pre-certification and construction expenditures at Columbia related to the proposed project. MGE expects to incur capital expenditures on the project as follows: $5 million for the remainder of 2011, $53 million in 2012, $68 million in 2013, and $13 million in 2014. According to the current estimate, this project is expected to result in an increase to Columbia's ongoing operating expenses. MGE expects that the costs pertaining to this project will be fully recoverable through rates. The PSCW has permitted MGE to defer pre-certification costs related to compliance with environmental regulations at Columbia. Additionally, MGE is entitled to a carrying cost on the related construction costs at a 100% AFUDC rate.
Title V Operating Permit Petition
In September 2008, the WDNR issued a Title V renewal operating permit to WPL for Columbia. A citizen group petitioned the EPA to object to the issuance of the permit renewal. In October 2009, the EPA issued an order granting in part and denying in part the petition and sent the operating permit back to the WDNR for further review based on the EPA order. In September 2010, the WDNR acted on the order by issuing a draft construction permit and a revised operating permit for public comment. In February 2011, the WDNR issued a letter stating its determination not to issue either the proposed construction permit or a revised operating permit for Columbia. Thus, MGE believes the permits currently in effect for Columbia remain in place at this time. In February 2011, the citizen group involved filed an action against the EPA in the U.S. District Court for the Western District of Wisconsin seeking to have the EPA take over the permit process. On May 18, 2011, the WDNR issued a public notice as to a revised operating permit. Both the Columbia owners and the Sierra Club have commented on the WDNR's draft permit and are awaiting the WDNR's response. MGE continues to follow developments on and evaluate this draft permit for potential financial or operational impacts.
Columbia Clean Air Act Litigation
In December 2009, the EPA sent a Notice of Violation (NOV) to MGE as one of the co-owners of Columbia. The NOV alleges that WPL and the Columbia co-owners failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the PSD program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin SIP.
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In September 2010, Sierra Club filed a civil lawsuit against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. The parties have requested a stay of proceedings to explore settlement options. The trial date has been scheduled for April 2012.
In response to similar EPA CAA enforcement initiatives, certain utilities have elected to settle with the EPA, while others have elected to litigate. If the EPA and/or Sierra Club successfully prove their claims that projects completed in the past at Columbia required either state or federal CAA permits, MGE may, under the applicable statutes, be required to pay civil penalties in amounts of up to $37,500 per day for each violation and/or complete actions for injunctive relief. Payment of fines and/or injunctive relief could be included in a settlement outcome. Injunctive relief contained in settlements or court-ordered remedies for other utilities in similar matters required the installation of pollution control technology, changed operating conditions (including use of alternative fuels other than coal), caps for emissions and limitations on generation (including retirement of generating units) and other supplemental environmental projects. If similar remedies are required for final resolution of these matters at Columbia, MGE would likely incur additional capital and operating expenditures. MGE and the other co-owners of Columbia are exploring settlement options with the EPA and Sierra Club while simultaneously defending against these allegations. WPL has informed MGE that WPL believes the projects at Columbia were routine or not projected to increase emissions and therefore did not violate the permitting requirements of the CAA. At this time, MGE is unable to predict the impact of these claims on its financial condition or results of operations but believes that should there ultimately be an adverse outcome, it could have a significant effect.
Chattel Paper Agreement and Other Guarantees - MGE Energy and MGE.
MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2012. At September 30, 2011, MGE has outstanding a $4.5 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of September 30, 2011, the servicing asset recognized by MGE is $0.2 million.
MGE accounts for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.
MGE would be required to perform under its guarantee if a customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at September 30, 2011, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan. Principal payments for the remainder of 2011 and the next four years on the loans are:
2012
2013
2014
2015
Chattel Paper
145
588
630
444
754
Other Legal Matters - MGE Energy and MGE.
MGE is involved in various other 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. MGE has accrued for such matters in the financial statements. The ultimate outcomes of such matters are uncertain and may have an adverse effect on MGE Energy's and MGE's results of operations, financial position, or cash flows.
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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. As of September 30, 2011, the future commitments related to these purchase contracts were as follows:
Coal(a)
6,264
24,374
18,769
3,670
Natural gas
Transportation & storage(b)
4,897
17,285
17,037
16,843
16,689
Supply(c)
15,797
14,841
26,958
56,500
35,806
20,513
(a)
Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, the operating companies. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.
(b)
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.
(c)
These commitments include market-based pricing. Management expects to recover these costs in future customer rates.
e.
Wind Development Rights - MGE Energy.
In August 2011, MGE Energy, through its subsidiary MAGAEL, LLC, terminated two existing wind development agreements. The termination of these agreements resulted in the termination of any further rights or obligations related to these wind development sites in Iowa. The original agreements were entered into in June 2009 to purchase land development rights, including land option agreements, electrical interconnection rights, wind data, engineering plans, licenses, permits, and governmental approvals for two wind development sites. These wind development rights potentially would have been used to develop wind farms of approximately 175 MW in three counties in Iowa. The payments made pursuant to these agreements totaled $2.0 million and will be returned to MAGAEL, LLC. As of September 30, 2011, the principal balance still outstanding is $1.8 million, with payments of $0.9 million expected to be received by December 31, 2011 and December 31, 2012.
f.
Smart Grid Investment Grant - MGE Energy and MGE.
MGE was approved by the U.S. Department of Energy (DOE) under the federal stimulus program for a $5.5 million grant for smart grid projects. The DOE grant requires MGE to match the grant funding, bringing the total cost of the proposed projects to more than $11 million. The proposed projects will install technologies to boost efficiency, enhance service and improve reliability for customers. The stimulus grant will help fund the following projects: advanced metering infrastructure, plug-in hybrid electric vehicles support, and distribution management. As of September 30, 2011, MGE has spent $4.9 million related to these projects and has outstanding agreements to purchase $0.6 million in smart grid related products for the remainder of 2011.
10.
Blount Station - MGE Energy and MGE.
In 2006, MGE announced a plan to reduce capacity at Blount from 190 MW to 100 MW by the end of 2011. As part of the plan, coal use at Blount will be discontinued. MGE has determined that certain employee positions will be eliminated as a result of this plan.
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In March 2009, MGE received notification from MISO that in order to meet national electric system reliability standards, MGE would need to keep Blount available at its full capacity until MISO declares that the 90 MW are no longer needed for system reliability. MGE recently received notification from MISO that the 90 MW of capacity is no longer needed to meet reliability standards and is now available for retirement on or after December 31, 2011. As a result, MGE estimates the reduction in capacity and the transition to operate exclusively on natural gas will occur by the end of 2011. MGE was previously estimating the reduction in capacity to occur in 2013.
MGE has entered into agreements providing severance benefits to employees affected by the exit plan. These benefits are being recognized ratably over the expected future service period of the employees. Total benefits expected to be paid are $0.4 million in 2011. MGE does not plan to seek recovery of severance costs resulting from the reduction of the capacity.
The following table presents the activity in the restructuring accrual from December 31, 2010, through September 30, 2011:
Balance at December 31, 2010
259
Additional expense, net
Cash payments during the period
(24)
Balance at September 30, 2011
341
The exit plan has also resulted in accelerated depreciation for the Blount assets expected to be retired in 2011 and 2013. The majority of these assets are being recovered in rates over a four-year period that began in 2008, with the remaining balance recovered by the end of 2013. For the nine months ended September 30, 2011 and 2010, $2.5 million of accelerated depreciation expense had been recognized and recovered in rates each year.
11.
Derivative and Hedging Instruments - MGE Energy and MGE.
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 and gas revenues. 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, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. The majority of MGE's 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 ranges from eighteen months to 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. 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.
Notional Amounts.
The gross notional volume of open derivatives is as follows:
December 31, 2010
Commodity derivative contracts
415,845 MWh
544,820 MWh
6,850,000 Dth
5,420,000 Dth
FTRs
3,724 MW
2,609 MW
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Financial Statement Presentation.
MGE Energy and MGE offset fair value amounts recognized for the right to reclaim collateral (a receivable) or the obligation to return collateral (a payable) against fair value amounts recognized for derivative instruments executed with the same counterparty under a master netting agreement. At September 30, 2011 and December 31, 2010, MGE Energy and MGE had $0.4 million and $0.5 million, respectively, in collateral that was netted against the net derivative positions with counterparties.
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 transmission paths in the MISO and PJM markets, MGE holds 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 reflected as a 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. At September 30, 2011 and December 31, 2010, the cost basis of exchange traded derivatives and FTRs exceeded their fair value by $0.2 million.
MGE has also entered into a ten-year 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 the option to purchase power during a period of time preceding that base term as well as 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 balance sheet. 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 at September 30, 2011 and December 31, 2010, reflects a loss position of $26.4 million and $19.0 million, respectively. The actual fuel 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 balance sheet. 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, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral.
Asset Derivatives
Liability Derivatives
Balance Sheet Location
Fair Value
583
1,003
Other deferred charges
Other deferred liabilities
180
Ten-year PPA
N/A
2,260
24,090
649
1,227
214
167
312
19,010
The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the balance sheet at September 30, 2011 and 2010, and the income statement for the three and nine months ended September 30, 2011 and 2010 (a).
Current and long-term regulatory asset
Three Months Ended September 30:
Balance at July 1,
22,604
1,001
17,345
1,030
Change in unrealized loss
3,839
4,055
Realized loss reclassified to a deferred account
(210)
210
(572)
572
Realized gain (loss) reclassified to income
statement
350
(233)
(177)
(399)
Balance at September 30,
26,583
978
20,651
1,203
Nine Months Ended September 30:
Balance at January 1,
19,230
1,411
12,542
1,334
7,775
10,731
(1,484)
1,484
(1,381)
1,381
1,062
(1,917)
(1,241)
(1,512)
Realized losses (gains)
Fuel for electric
Regulated
generation/
Cost of
gas revenues
purchased power
gas sold
Three Months Ended September 30, 2011:
(94)
(23)
Three Months Ended September 30, 2010:
573
(128)
131
Nine Months Ended September 30, 2011:
(465)
1,315
Nine Months Ended September 30, 2010:
2,276
481
(4)
MGE's commodity derivative contracts, FTRs, and ten-year 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 balance sheet 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 ten-year PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-) once MGE begins purchasing energy under the contract in 2012. 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. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of September 30, 2011 and December 31, 2010, no counterparties were in a net liability position.
25
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, 2011, no counterparties have defaulted.
12.
Rate Matters - MGE Energy and MGE.
Rate Proceedings.
In May 2011, MGE filed with the PSCW a limited scope reopener of its 2012 electric and gas rates. The reopener included an update to MGE's electric fuel and purchased power costs, increased transmission costs, an update to the Elm Road costs, and an increase for energy efficiency programs. The requested changes would result in a 5.7% increase in electric rates and a 0.4% increase in gas rates effective January 1, 2012. MGE has also requested a deferral of CSAPR costs.
On January 12, 2011, the PSCW authorized MGE to increase 2011 rates for retail electric customers by 2.3% or $8.0 million and to increase gas rates by 1.0% or $1.9 million. The increase in retail electric rates is driven by costs for MGE's share of the Elm Road Units. Pursuant to the provisions of this rate order, the fuel rules bandwidth effective January 1, 2011, will be plus or minus 2%. See below for further description of fuel rules. Authorized return on common stock equity was set at 10.3% based on a 58.1% utility common equity.
In December 2009, the PSCW authorized MGE to increase 2010 rates for retail electric customers by 3.3% or $11.9 million, while gas rates decreased 0.74% or $1.5 million. The increase in retail electric rates was driven by costs for MGE's share of the Elm Road Units and transmission reliability enhancements. Pursuant to the provisions of this rate order, the fuel rules bandwidth effective January 1, 2010, was plus or minus 2%. Authorized return on common stock equity was set at 10.4% based on a 55.3% utility common equity.
Fuel Rules.
The PSCW approved new fuel rules that became effective January 1, 2011. The new rules require the PSCW and Wisconsin utilities to automatically defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the deferred costs is determined on an annual basis and will be adjusted in future billings to its electric retail customers. 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 plan year 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.
As of September 30, 2011, MGE did not defer any electric fuel-related costs. In 2010, a refund of $0.3 million of over collected 2009 fuel costs was refunded on customers' April 2010 bills.
Purchased Gas Adjustment Clause.
MGE's natural gas rates are subject to a fuel adjustment clause designed to recover or refund the difference between the actual cost of purchased gas and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates. At September 30, 2011 and December 31, 2010, MGE had over collected $1.1 million and $4.8 million, respectively. These amounts were recorded in other current liabilities on the consolidated balance sheet.
26
13.
Fair Value of Financial Instruments - MGE Energy and MGE.
Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount.
At September 30, 2011 and December 31, 2010, 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 MGE Energy's and MGE long-term debt is based on quoted market prices for similar financial instruments at September 30, 2011 and December 31, 2010. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:
Carrying
Fair
Amount
Assets:
Liabilities:
Short-term debt - bank loans
19,000
Short-term debt - commercial paper
Long-term debt*
365,139
412,108
336,973
356,395
*Includes long-term debt due within one year.
Recurring Fair Value Measurements.
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 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.
The following table presents the balances of assets and liabilities measured at fair value on a recurring basis for MGE Energy and MGE.
Fair Value as of September 30, 2011
Level 1
Level 2
Level 3
Exchange-traded investments
386
Derivatives, net(a)
673
25,910
Deferred compensation
1,660
Total Liabilities
28,243
2,333
170
(a) These amounts are shown gross and exclude $0.4 million of collateral that was posted
against derivative positions with counterparties.
Fair Value as of December 31, 2010
430
Derivatives, net(b)
19,216
1,525
20,755
1,539
260
(b) These amounts are shown gross and exclude $0.5 million of collateral that was posted
No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2011.
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 party transactions, a ten-year 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 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 with markets with similar exchange traded transactions. The ten-year purchased power agreement (see Footnote 11) was valued using an internally-developed pricing model and therefore classified as Level 3. The model includes both observable and unobservable inputs. Inputs to the model require significant management judgment and estimation. The model uses a forward power pricing curve based on exchange-traded contracts in the electric futures market. As described above, the market prices from this source have insufficient volumes and are classified as Level 3 in the fair value hierarchy. To project future prices beyond the period in which these quoted market prices are available, MGE calculates the price based on forward gas prices and an implied heat rate. MGE 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 incorporates discounting, credit, and model risks. 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 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 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, and are therefore based upon observable market data and classified as Level 1.
The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.
Beginning balance,
(22,983)
(17,604)
(19,216)
(13,047)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)
(2,927)
(1,594)
(6,694)
(6,151)
Included in other comprehensive income
Included in earnings
182
(306)
815
(1,409)
Included in current assets
(7)
(66)
Purchases
178
Sales
122
223
Issuances
Settlements
(353)
184
(1,091)
1,186
Transfers in and/or out of Level 3
Balance as of September 30,
(25,910)
(19,198)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(c)
29
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 for both MGE Energy and MGE (c).
Purchased Power Expense
(311)
(1,389)
Cost of Gas Sold Expense
Regulated Gas Revenues
(c) MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset with a corresponding regulatory asset or liability.
14.
New Accounting Pronouncements - MGE Energy and MGE.
Fair Value Measurements and Disclosures.
In January 2010, the FASB issued authoritative guidance within the Codification's Fair Value Measurements and Disclosures topic that provides guidance on additional disclosures about fair value measurements. This authoritative guidance became effective January 1, 2010, except for the disclosures about purchases, sales, issuances, and settlements in the roll forward of activity in Level 3 fair value measurements, which were effective January 1, 2011. The authoritative guidance did not have any financial impact, but required additional disclosures. See Footnote 13 for additional information.
In May 2011, the FASB issued authoritative guidance within the Codification's Fair Value Measurements and Disclosures topic that provides guidance on additional disclosures about fair value measurements, specifically related to Level 3 assets and liabilities. This authoritative guidance will become effective January 1, 2012. The authoritative guidance will not have a material financial impact, but will require additional disclosures.
Presentation of Comprehensive Income.
In June 2011, the FASB issued authoritative guidance within the Codification's Comprehensive Income topic that provides guidance on presentation of comprehensive income. Comprehensive income will be presented either in a single continuous statement of comprehensive income or in two separate but consecutive statements. This authoritative guidance will become effective January 1, 2012. The authoritative guidance will have an effect on our financial statement presentation of comprehensive income.
15.
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 MGE Energy's and MGE's 2010 Annual Report on Form 10-K for additional discussion of each of these segments.
30
The following tables show segment information for MGE Energy's operations for the indicated periods:
Consolidation/
Transmission
All
Elimination
Consolidated
Electric
Gas
Energy
Investment
Others
Entries
Three Months Ended September 30, 2011
Interdepartmental revenues
163
5,083
9,582
(14,828)
Total operating revenues
115,126
22,332
10,942
(7,144)
(1,377)
(1,775)
(10,296)
Other operating expenses
(78,118)
(23,422)
(44)
(186)
14,828
(86,942)
Operating income (loss)
29,864
(2,467)
9,123
35
127
Interest (expense) income, net
(2,747)
(775)
(1,660)
40
Income (loss) before taxes
27,152
(3,230)
7,463
(19)
Income tax (provision) benefit
(9,944)
(2,994)
(870)
(37)
Net income (loss)
17,208
(1,880)
4,469
1,297
Three Months Ended September 30, 2010
161
4,509
8,011
(12,681)
110,010
21,903
8,706
(6,888)
(1,309)
(1,363)
(9,560)
(73,469)
(22,948)
(35)
(255)
12,681
(84,026)
29,653
(2,354)
7,308
Other (deductions) income, net
435
123
2,091
(3)
(2,646)
(746)
(655)
27,442
(2,977)
6,653
(310)
(10,874)
1,305
(2,670)
119
16,568
(1,672)
3,983
1,221
(191)
Nine Months Ended September 30, 2011
391
8,247
28,559
(37,197)
292,195
127,995
32,443
(21,173)
(4,246)
(5,250)
(30,669)
(218,556)
(112,192)
(138)
(649)
37,197
(294,338)
52,466
11,557
27,055
68
357
(8,100)
(2,284)
(4,677)
44,434
9,294
22,378
(278)
(15,666)
(3,532)
(8,981)
(2,592)
28,768
5,762
13,397
3,842
(225)
Nine Months Ended September 30, 2010
398
10,353
22,631
(33,382)
279,679
124,584
25,782
(20,520)
(3,884)
(3,859)
(28,263)
(212,274)
(112,554)
(101)
(604)
33,382
(292,151)
46,885
8,146
21,822
2,372
669
(104)
(7,874)
(2,221)
(2,031)
41,383
6,594
19,687
(527)
(15,175)
(2,336)
(7,890)
(2,589)
200
26,208
4,258
11,797
3,785
(327)
31
The following tables show segment information for MGE's operations for the indicated periods:
Other operating expenses*
(88,013)
(22,057)
(3,039)
(98,281)
Operating income (loss)*
19,969
(1,102)
6,128
Other (deductions) income, net*
(14)
(5,182)
(1,881)
4,468
Less: Net income attributable to
noncontrolling interest, net of tax
Net income (loss) attributable to MGE
(84,150)
(21,589)
(2,705)
(95,763)
18,972
(995)
4,638
Other income, net*
243
69
(4,047)
16,569
Less: net income attributable to
(234,145)
(115,701)
(9,119)
(321,768)
Operating income*
36,877
8,048
18,074
(8)
(2)
(15,061)
28,769
Net income attributable to MGE
(226,431)
(114,603)
(7,991)
(315,643)
32,728
6,097
13,932
382
(12,126)
26,209
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.
32
16.
Subsequent Events - MGE Energy and MGE.
Receivable – Margin Account.
MGE enters into financial transactions to hedge its costs for fuel used in electric generation, purchased power, and cost of gas sold to customers. These transactions are conducted pursuant to a PSCW approved risk management plan through an account held at MF Global. As of October 31, 2011, MGE had approximately $3.3 million in a customer segregated margin account held at MF Global. As a result of a bankruptcy filing on October 31, 2011 by affiliated MF Global entities, the Chicago Mercantile Exchange froze all MF Global-related accounts (including MGE's account). At this time, MGE is unable to predict the ultimate impact of these events, including any regulatory recovery related to any losses we may incur.
33
General
MGE Energy is an investor-owned public utility holding company operating through subsidiaries in five business segments:
·
Electric utility operations, conducted through MGE,
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
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 139,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 143,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.
Our nonregulated energy operations own interests in new 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 partial ownership of a cogeneration project on the UW-Madison campus and an undivided 8.33% ownership interest in two 615 MW coal-fired generating units in Oak Creek, Wisconsin. MGE operates the cogeneration project, and a third party operates the units in Oak Creek. Due to the nature of MGE's participation in these facilities, the results of our nonregulated operations are also consolidated into MGE's consolidated financial position and results of operations under applicable accounting standards.
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 shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE plans to meet this challenge by investing in more efficient generation projects, including renewable energy sources. In the future, MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE will continue to maintain 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 of electricity and gas,
Economic conditions, including current business activity and employment and their impact on customer demand,
Regulation and regulatory issues,
Energy commodity 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 pending environmental rule changes,
and other factors listed in "Item 1A. Risk Factors" of our 2010 Annual Report on Form 10-K.
For the three months ended September 30, 2011, MGE Energy's earnings were $21.0 million or $0.91 per share compared to $19.9 million or $0.86 per share for the same period in the prior year. MGE's earnings for the three months ended September 30, 2011, were $15.1 million compared to $15.0 million for the same period in the prior year.
For the nine months ended September 30, 2011, MGE Energy's earnings were $51.5 million or $2.23 per share compared to $45.7 million or $1.98 per share for the same period in the prior year. MGE's earnings for the nine months ended September 30, 2011, were $33.8 million compared to $30.9 million for the same period in the prior year.
MGE Energy's income was derived from our business segments as follows:
Business Segment:
Electric Utility
Gas Utility
Nonregulated Energy
Transmission Investments
All Other
Our net income during the three months ended September 30, 2011 primarily reflects the effects of the following factors:
A 4.7% increase in electric revenues reflecting increased customer demand, driven by warmer-than-normal weather in July 2011. Cooling degree days (a measure for determining the impact of weather during the cooling season) in July increased by 20% compared to the prior period. In addition, electric operating and maintenance expenses decreased compared to the prior period.
Higher nonregulated energy income attributable to Elm Road Unit 2 entering commercial operation. Elm Road Unit 2 was placed in-service in January 2011.
Our net income during the nine months ended September 30, 2011 primarily reflects the effects of the following factors:
A 4.5% increase in electric revenues reflecting increased customer demand. In addition, electric operating and maintenance expenses decreased compared to the prior period.
A 10.5% increase in gas sales reflecting higher customer demand due to a colder winter. Heating degree days (a measure for determining the impact of weather during the heating season) increased by 14% compared to the prior period.
The electric and gas utilities received a one-time $2.6 million (pretax) gain on a sale of property to ATC during March 2010.
Higher nonregulated energy revenues are attributable to both Elm Road Units entering commercial operation. Elm Road Unit 1 was placed in-service in February 2010 and Elm Road Unit 2 was placed in-service in January 2011.
During 2011, the following events occurred:
Elm Road Units: Elm Road Unit 2 entered commercial operation in January 2011. On February 28, 2011, our subsidiary, MGE Power Elm Road, which owns an ownership interest in those Units, issued $30 million of its 4.74% senior secured notes to refinance a portion of the costs of those Units. The proceeds of those notes were used to repay borrowings under MGE Energy's credit facilities.
Columbia Certificate of Authority: In March 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. MGE's estimated share of the capital expenditures required to comply with this project will be approximately $140 million and are expected to occur between the 2011-2014 timeframe.
ATC: MGE Transco contributed $0.9 million for voluntary capital contributions to ATC for the nine months ended September 30, 2011.
Smart Grid Investment Grant: MGE was approved by the U.S. Department of Energy (DOE) under the federal stimulus program for a $5.5 million grant for smart grid projects. The DOE grant requires MGE to match the grant funding, bringing the total cost of the proposed projects to more than $11 million. The proposed projects will install technologies to boost efficiency, enhance service and improve reliability for customers. The stimulus grant will help fund the following projects: advanced metering infrastructure, plug-in hybrid electric vehicles support, and distribution management. As of September 30, 2011, MGE has spent $4.9 million related to these projects and has outstanding agreements to purchase $0.6 million in smart grid related products for the remainder of 2011.
Rate Filing: In May, 2011, MGE filed with the PSCW a limited scope reopener of its 2012 electric and gas rates. The reopener included an update to MGE's electric fuel and purchased power costs, increased transmission costs, an update to the Elm Road costs, and an increase for energy efficiency programs. The requested changes would result in a 5.7% increase in electric rates and a 0.4% increase in gas rates effective January 1, 2012. MGE has also requested deferral of CSAPR costs.
In the near term, several items may affect us, including:
Environmental Initiatives: There are proposed legislation, rules and initiatives involving matters related to air emissions (including CSAPR), water effluent, hazardous materials and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. Such legislation and rulemaking could significantly affect the costs of owning and operating fossil-fueled generating plants, such as Columbia and Elm Road, from which we derive approximately 40% of our electric generating capacity. 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. In addition, MGE is involved in claims surrounding the alleged failure, among other things, to obtain necessary air permits and implement necessary emission controls associated with activities previously undertaken at Columbia. MGE and the other co-owners are defending against these claims. MGE is unable to predict the impact of these claims on its financial condition or results of operations at this time. However should there ultimately be an adverse outcome, MGE believes it could have a significant effect.
Cross-State Air Pollution Rule (CSAPR): In July 2011, the EPA issued the CSAPR, which requires SO2 and NOx emissions reductions from emission sources. CSAPR affects fossil-fueled EGUs in Wisconsin with greater than 25 MW of capacity. Beginning in 2012, CSAPR establishes state emission caps for SO2 and NOx (Phase I). These SO2 and NOx emission caps will be lowered further in 2014 (Phase II). MGE estimates that its fuel costs could increase as much as $14.5 million in 2012 related to CSAPR compliance and has requested deferred rate recovery of these costs from the PSC. Numerous legal challenges to CSPAR have been filed seeking to stay the effectiveness of the rule.
General economic conditions: Economic conditions both inside and outside our service area are expected to continue to affect the level of demand for our utility services and may affect the collection of our accounts receivable and the creditworthiness of counterparties with whom we do business. We have in place lines of credit aggregating $115 million for MGE Energy (including MGE) and $75 million for MGE to address our liquidity needs.
The following discussion is based on the business segments as discussed in Footnote 15.
Three Months Ended September 30, 2011 and 2010
Electric Utility Operations - MGE Energy and MGE
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,
% Change
Residential
39,176
38,156
2.7%
251,426
250,849
0.2%
Commercial
59,131
56,380
4.9%
516,744
507,997
1.7%
Industrial
5,588
5,357
4.3%
71,591
70,072
2.2%
Other-retail/municipal
11,497
10,628
8.2%
132,721
124,983
6.2%
Total retail
115,392
110,521
4.4%
972,482
953,901
1.9%
Sales to the market
606
625
(3.0)%
4,376
2,676
63.5%
Adjustments to revenues
(1,035)
(1,297)
20.2%
-%
4.7%
976,858
956,577
2.1%
Cooling degree days (normal 445)
612
623
(1.8)%
Electric operating revenues increased $5.1 million or 4.7% for the three months ended September 30, 2011, due to the following:
(In millions)
Rate changes
2.7
Volume
2.2
0.2
5.1
Rate changes. Rates charged to retail customers for the three months ended September 30, 2011, were 2.4% or $2.7 million higher than those charged during the same period in the prior year.
In January 2011, the PSCW authorized MGE to increase 2011 rates for retail electric customers by 2.3% or $8.0 million. The increase in retail electric rates is driven by costs for MGE's share of the Elm Road Units.
Volume. During the three months ended September 30, 2011, there was a 1.9% increase in total retail sales volumes compared to the same period in the prior year, reflecting increased customer demand as a result of warmer-than-normal weather in July 2011.
Adjustments to revenues. The adjustments to revenues amount includes the elimination of carrying costs for WCCF and the Elm Road Units that were collected in electric rates, which are recognized as nonregulated energy operating revenues in our Nonregulated Energy Operations segment. The amount eliminated was $1.5 million and $1.8 million for the three months ended September 30, 2011 and 2010, respectively.
Sales to the market. For the three months ended September 30, 2011, market volumes increased compared to the same period in the prior year, reflecting increased opportunities for sales. In addition, market settlement resulted in lower revenue per kWh for the period ended September 30, 2011.
Electric fuel and purchased power
The expense for fuel for electric generation increased $4.0 million or 32.0% during the three months ended September 30, 2011, compared to the same period in the prior year, reflecting higher generation at Elm Road. Elm Road Unit 1 and Unit 2 entered commercial operation in February 2010 and January 2011, respectively.
Purchased power expense decreased $0.5 million during the three months ended September 30, 2011, compared to the same period in the prior year (including the effect of the reversal of the fuel deferral from second quarter of $2.7 million). Of this amount, $2.5 million was due to a 13.5% decrease in the volume of power purchased from third parties and $0.7 million was due to a 4.5% decrease in the per-unit cost of purchased power.
Under fuel rules, MGE defers costs, less any excess revenues, if its actual electric fuel-related costs fall outside a symmetrical cost tolerance band. Excess revenues are defined as revenues that provide MGE with a greater return on common equity than authorized by the PSCW. Any over/under recovery of these costs is determined on an annual basis and then adjusted in future billings to its electric retail customers.
Electric operating and maintenance expenses
Electric operating and maintenance expenses decreased $0.7 million during the three months ended September 30, 2011, compared to the same period in 2010. The following changes contributed to the net change:
Decreased administrative and general costs
(0.4)
Decreased production costs
(0.3)
(0.7)
37
Gas Utility Operations - MGE Energy and MGE
Gas deliveries and revenues
The following table compares MGE's gas revenues and gas therms delivered by customer class during each of the periods indicated:
Therms Delivered
(In thousands, except HDD and average rate per therm of retail customer)
8,614
8,080
6.6%
5,939
5,526
7.5%
Commercial/Industrial
8,001
8,314
(3.8)%
13,008
14,450
(10.0)%
16,615
16,394
1.3%
18,947
19,976
(5.2)%
Gas Transportation
506
484
4.5%
6,367
6,524
(2.4)%
Other revenues
128
516
(75.2)%
(0.8)%
25,314
26,500
(4.5)%
Heating degree days (normal 183)
216
151
43.0%
Average Rate Per Therm of
Retail Customer
0.877
0.821
6.8%
Gas revenues decreased $0.1 million or 0.8% for the three months ended September 30, 2011. These changes are related to the following factors:
Gas deliveries
(0.8)
Transportation and other effects
Gas costs/rates
1.1
(0.1)
Retail gas deliveries. For the three months ended September 30, 2011, retail gas deliveries decreased 5.2% compared to the same period in 2010.
Gas costs/rates. The average retail rate per therm for the three months ended September 30, 2011, increased 6.8% compared to the same period in 2010, reflecting higher natural gas commodity costs.
For the three months ended September 30, 2011, cost of gas sold decreased by $0.1 million, compared to the same period in the prior year, reflecting decreased volumes. The volume of gas purchased decreased 8.2%, which resulted in $0.7 million of decreased expense. This was offset by a 7.2% increase in the cost per therm of natural gas, which resulted in $0.6 million of increased expense.
Gas operating and maintenance expenses
Gas operating and maintenance expenses increased by $0.1 million for the three months ended September 30, 2011, compared to the same period a year ago.
Nonregulated Energy Operations - MGE Energy and MGE
Nonregulated energy operating revenues
Operating revenues from nonregulated energy operations increased $2.2 million for the three months ended September 30, 2011, when compared to the same period in the prior year, reflecting the commencement of commercial operations at Elm Road Unit 2 in January 2011.
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MGE received approval from the PSCW to collect from customers the carrying costs incurred by MGE Power Elm Road during construction of the Elm Road Units. The total carrying costs on the Elm Road Units is $62.2 million. A portion of this amount is being recognized over the period in which Elm Road Units costs are recovered in rates and a portion is being deferred and will be recognized over the period in which the Units are depreciated. See Footnote 6 for additional information regarding these carrying charges. For both the three months ended September 30, 2011 and 2010, MGE Power Elm Road recognized $1.0 million related to carrying costs on the Elm Road Units.
Nonregulated depreciation expense
Nonregulated depreciation expense increased $0.4 million for the three months ended September 30, 2011, compared to the same period in the prior year. This additional depreciation is related to the commencement of commercial operations at Elm Road Unit 2 in January 2011.
Nonregulated energy interest expense, net
For the three months ended September 30, 2011 and 2010, interest expense, net at the nonregulated energy operations segment was $1.7 million and $0.7 million, respectively. Interest expense at the nonregulated energy segment for both the three months ended September 30, 2011 and 2010, includes interest expense incurred on $50 million of borrowings at MGE Power West Campus, and $50 million of borrowings at MGE Power Elm Road, which were long-term and fixed-rate during both periods. Interest expense at the nonregulated energy segment for the three months ended September 30, 2011, also includes interest incurred on $30 million of borrowings at MGE Power Elm Road, which were issued in late February 2011 and are long-term and fixed-rate during 2011.
Transmission Investment Operations - MGE Energy and MGE
Transmission investment other income
For the three months ended September 30, 2011 and 2010, other income at the transmission investment segment was $2.2 million and $2.1 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 4 for additional information concerning ATC and summarized financial information regarding ATC.
Consolidated Income Taxes - MGE Energy and MGE
MGE Energy's effective income tax rate for the three months ended September 30, 2011, is 37.3% compared to 39.5% for the same period in 2010, and MGE's effective income tax rate for the three months ended September 30, 2011, is 37.1% compared to 39.5% for the same period in 2010. The lower effective tax rate is, in part, attributable to a higher estimated domestic manufacturing deduction.
Noncontrolling Interest, Net of Tax - MGE
The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in the WCCF and Elm Road Units. MGE Energy owns 100% of MGE Power West Campus and MGE Power Elm Road; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. Also included in noncontrolling interest, net of tax, is MGE Energy's interest in MGE Transco.
For the three months ended September 30, 2011, MGE Energy (through its wholly owned subsidiary MGE Power) earned $1.9 million and $3.7 million, net of tax, for its interest in MGE Power West Campus and MGE Power Elm Road, respectively. Additionally, MGE Energy earned $0.5 million, net of tax, for its interest in MGE Transco for the three months ended September 30, 2011. These amounts are recorded as noncontrolling interest, net of tax, on MGE's consolidated statement of income.
For the three months ended September 30, 2010, MGE Energy (through its wholly owned subsidiary MGE Power) had earned $1.9 million and $2.8 million, net of tax, for its interest in MGE Power West Campus and MGE Power Elm Road, respectively. Additionally, MGE Energy had earned $0.4 million, net of tax, for its interest in MGE Transco for the three months ended September 30, 2010. These amounts are recorded as noncontrolling interest, net of tax, on MGE's consolidated statement of income.
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Nine Months Ended September 30, 2011 and 2010
Nine Months Ended September 30,
97,225
94,467
2.9%
638,925
635,071
0.6%
152,751
146,908
4.0%
1,398,161
1,383,416
1.1%
14,676
201,815
198,661
1.6%
28,583
26,817
336,788
323,169
4.2%
293,552
282,868
3.8%
2,575,689
2,540,317
1.4%
1,489
1,574
(5.4)%
32,634
21,110
54.6%
(3,237)
(5,161)
37.3%
2,608,323
2,561,427
1.8%
Cooling degree days (normal 622)
804
825
(2.5)%
Electric operating revenues increased $12.5 million or 4.5% for the nine months ended September 30, 2011, due to the following:
6.7
3.9
1.9
12.5
Rate changes. Rates charged to retail customers for the nine months ended September 30, 2011, were 2.4% or $6.7 million higher than those charged during the same period in the prior year.
Volume. During the nine months ended September 30, 2011, there was a 1.4% increase in total retail sales volumes compared to the same period in the prior year, reflecting increased customer demand as a result of warmer-than-normal weather in July 2011.
Adjustments to revenues. The adjustments to revenues amount includes the elimination of carrying costs for WCCF and the Elm Road Units that were collected in electric rates, which are recognized as nonregulated energy operating revenues in our Nonregulated Energy Operations segment. The amount eliminated was $4.5 million and $5.2 million for the nine months ended September 30, 2011 and 2010, respectively.
During the nine months ended September 30, 2010, MGE began recovering in electric rates the costs associated with the lease payments for Elm Road Unit 2. These amounts were deferred on MGE's balance sheet until the lease term commenced. At September 30, 2010, a $1.5 million reduction to adjustments to revenues was recorded to defer these revenues.
Sales to the market. For the nine months ended September 30, 2010, market volumes increased compared to the same period in the prior year, reflecting increased opportunities for sales. In addition, market settlement resulted in lower revenue per kWh for the period ended September 30, 2010.
The expense for fuel for electric generation increased $7.5 million or 23.7% during the nine months ended September 30, 2011, compared to the same period in the prior year, reflecting higher generation at Elm Road. Elm Road Unit 1 and Unit 2 entered commercial operation in February 2010 and January 2011, respectively.
Purchased power expense decreased by $6.5 million or 11.6% during the nine months ended September 30, 2011, compared to the same period in the prior year. The decrease in expense reflects a $6.1 million or 10.8% decrease in the volume of power purchased from third parties, driven by Elm Road Unit 2 becoming operational in January 2011.
Electric operating and maintenance expenses decreased $0.8 million during the nine months ended September 30, 2011, compared to the same period in 2010. The following changes contributed to the net change:
(0.5)
Decreased transmission costs
Decreased customer services costs
Increased production costs
0.4
For the nine months ended September 30, 2011, decreased administrative and general costs were primarily due to reduced pension costs.
Electric depreciation expense
Electric depreciation expense increased $0.7 million for the nine months ended September 30, 2011, compared to the same period in the prior year. This increase is related to higher levels of electric assets.
67,180
63,309
6.1%
64,827
57,204
13.3%
50,183
48,054
75,265
67,634
11.3%
117,363
111,363
5.4%
140,092
124,838
12.2%
1,909
1,788
26,287
25,753
476
1,080
(55.9)%
4.8%
166,379
150,591
10.5%
Heating degree days (normal 4,532)
4,805
4,217
13.9%
0.838
0.892
(6.1)%
Gas revenues increased $5.5 million or 4.8% for the nine months ended September 30, 2011. These changes are related to the following factors:
13.6
(7.6)
5.5
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Retail gas deliveries. For the nine months ended September 30, 2011, retail gas deliveries increased 12.2% compared to the same period in 2010, as a result of colder weather during the winter months.
Gas costs/rates. The average retail rate per therm for the nine months ended September 30, 2011, decreased 6.1% compared to the same period in 2010, reflecting significantly lower natural gas commodity costs.
For the nine months ended September 30, 2011, cost of gas sold increased by $1.4 million, compared to the same period in the prior year. The volume of purchased gas increased 12.0%, which resulted in $8.5 million of additional expense. A majority of the increase was offset by a 9.0% decrease in the cost per therm of natural gas, which resulted in $7.1 million of decreased expense.
Gas operating and maintenance expenses increased by $0.5 million for the nine months ended September 30, 2011, compared to the same period a year ago. The following changes contributed to the net change:
Increased customer accounts costs
0.3
Increased administrative and general costs
0.5
Other Income (Deductions), Net - MGE Energy and MGE
For the nine months ended September 30, 2011, other income, net for the electric and gas segments decreased by $3.0 million, compared to the same period in the prior year. This decrease is primarily due to a one-time $2.6 million pretax gain on a sale of property to ATC during March 2010.
Operating revenues from nonregulated energy operations increased $6.7 million for the nine months ended September 30, 2011, when compared to the same period in the prior year, reflecting the commencement of commercial operations at Elm Road Unit 2 in January 2011.
MGE received approval from the PSCW to collect from customers the carrying costs incurred by MGE Power Elm Road during construction of the Elm Road Units. The total carrying costs on the Elm Road Units is $62.2 million. A portion of this amount is being recognized over the period in which Elm Road Units costs are recovered in rates and a portion is being deferred and will be recognized over the period in which the Units are depreciated. See Footnote 6 for additional information regarding these carrying charges. For the nine months ended September 30, 2011 and 2010, MGE Power Elm Road recognized $2.9 million and $3.8 million, respectively, related to carrying costs on the Elm Road Units.
Nonregulated depreciation expense increased $1.4 million for the nine months ended September 30, 2011, compared to the same period in the prior year. This additional depreciation is related to the commencement of commercial operations at Elm Road Unit 2 in January 2011.
For the nine months ended September 30, 2011 and 2010, interest expense, net at the nonregulated energy operations segment was $4.7 million and $2.0 million, respectively. Interest expense at the nonregulated energy segment for both the nine months ended September 30, 2011 and 2010, includes interest expense incurred on $50 million of borrowings at MGE Power West Campus, and $50 million of borrowings at MGE Power Elm Road, which were long-term and fixed-rate during both periods. Interest expense at the nonregulated energy segment for the nine months ended September 30, 2011, also includes interest incurred on $30 million of borrowings at MGE Power Elm Road, which were issued in late February 2011 and are long-term and fixed-rate during 2011.
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For the nine months ended September 30, 2011 and 2010, other income at the transmission investment segment was $6.4 million. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 4 for additional information concerning ATC and summarized financial information regarding ATC.
MGE Energy's effective income tax rate for the nine months ended September 30, 2011, is 37.3% compared to 37.8% for the same period in 2010, and MGE's effective income tax rate for the nine months ended September 30, 2011, is 37.3% compared to 37.8% for the same period in 2010. The lower effective tax rate is, in part, attributable to a higher estimated domestic manufacturing deduction.
For the nine months ended September 30, 2011, MGE Energy (through its wholly owned subsidiary MGE Power) earned $5.6 million and $10.9 million, net of tax, for its interest in MGE Power West Campus and MGE Power Elm Road, respectively. Additionally, MGE Energy earned $1.4 million, net of tax, for its interest in MGE Transco for the nine months ended September 30, 2011. These amounts are recorded as noncontrolling interest, net of tax, on MGE's consolidated statement of income.
For the nine months ended September 30, 2010, MGE Energy (through its wholly owned subsidiary MGE Power) had earned $5.7 million and $8.1 million, net of tax, for its interest in MGE Power West Campus and MGE Power Elm Road, respectively. Additionally, MGE Energy had earned $1.3 million, net of tax, for its interest in MGE Transco for the nine months ended September 30, 2010. These amounts are recorded as noncontrolling interest, net of tax, on MGE's consolidated statement of income.
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 nine months ended September 30, 2011, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 9 of this filing and Footnote 18 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 2010 Annual Report on Form 10-K.
Purchase Contracts - MGE Energy and MGE
Transportation and storage(b)
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Total coal commitments for the Columbia and Elm Road Units. Fuel procurement for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, the operating companies. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.
Smart Grid Investment Grant - MGE Energy and MGE
Secured Debt - MGE Energy and MGE
Credit Facilities - MGE Energy and MGE
On August 1, 2011, each of MGE Energy and MGE entered into an amendment to its existing credit agreement dated as of July 30, 2010, with various financial institutions and JPMorgan Chase Bank, N.A., as administrative agent. The existing credit agreements provide MGE Energy with a $40 million revolving credit facility and MGE with a $75 million revolving credit facility.
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Liquidity and Capital Resources
Cash Flows
The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, 2011 and 2010:
Cash provided by/(used for):
Operating activities
Investing activities
Financing activities
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 nine months ended September 30, 2011, was $106.5 million, an increase of $9.1 million when compared to the same period in the prior year, primarily due to higher net income and the benefit of less taxes paid as a result of a tax method change in accounting for repairs and bonus depreciation.
MGE Energy's net income increased $5.8 million for the nine months ended September 30, 2011, when compared to the same period in the prior year.
The cash flows for the nine months ended September 30, 2011, reflect a $7.6 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to the additional benefit from the income tax method change in accounting for repairs and bonus depreciation.
An increase in pension contribution resulted in an additional $7.2 million in cash used by operating activities for the nine months ended September 30, 2011, when compared to the same period in the prior year. These contributions were made to comply with the Employee Retirement Income Security Act (ERISA) and the Pension Protection Act of 2006, and additional contributions were at management's discretion.
Cash provided by operating activities for the nine months ended September 30, 2011, was $105.0 million, an increase of $7.8 million when compared to the same period in the prior year, primarily due to higher net income and the benefit of less taxes paid as a result of a tax method change in accounting for repairs and bonus depreciation.
Net income increased $5.7 million for the nine months ended September 30, 2011, when compared to the same period in the prior year.
The cash flows for the nine months ended September 30, 2011, reflect a $6.9 million benefit of lower taxes payable, compared to the same period in the prior year, primarily due to the additional benefit from the income tax method change in accounting for repairs and bonus depreciation.
An increase in pension contribution resulted in an additional $7.2 million in cash used by operating activities for the nine months ended September 30, 2011, when compared to the same period in the prior year. These contributions were made to comply with the ERISA and the Pension Protection Act of 2006, and additional contributions were at management's discretion.
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MGE Energy's cash used for investing activities increased $7.2 million for the nine months ended September 30, 2011, when compared to the same period in the prior year.
Capital expenditures for the nine months ended September 30, 2011, were $44.9 million. This amount represents an increase of $1.6 million from the expenditures made in the same period in the prior year. This increase is related to increased utility expenditures of $10.7 million, partially offset by $8.9 million in decreased construction activity related to the Elm Road Units.
Cash used for investing activities was further increased by land purchased for investing purposes of $2.2 million in 2011.
Additionally, proceeds of $2.7 million were received for a one time sale of property to ATC in March 2010 and $0.6 million were received for a one time sale of property in September 2010.
MGE's cash used for investing activities increased $4.9 million for the nine months ended September 30, 2011, when compared to the same period in the prior year.
Cash used for MGE Energy's financing activities was $20.9 million for the nine months ended September 30, 2011, compared to $43.8 million of cash used for the nine months ended September 30, 2010.
For the nine months ended September 30, 2011, dividends paid were $26.2 million compared to $25.7 million in the prior year. This increase was a result of a higher dividend per share ($1.133 vs. $1.112).
During the nine months ended September 30, 2011 and 2010, MGE Power Elm Road issued $30.0 million and $50.0 million of long-term debt, respectively.
For the nine months ended September 30, 2011, net short-term debt repayments were $22.5 million compared to $66.0 million for the same period in the prior year, reflecting the use of proceeds from the MGE Power Elm Road long-term debt issues.
During the nine months ended September 30, 2011, cash used for MGE's financing activities was $37.7 million compared to $44.5 million of cash used by MGE's financing activities in the prior year.
Dividends paid from MGE to MGE Energy were $19.9 million for the nine months ended September 30, 2011 compared to $19.6 million in the prior year.
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Distributions to parent from noncontrolling interest decreased $7.3 million as a result of long-term debt financing by MGE Power Elm Road. The proceeds from the financing were used to repay MGE Energy, which had been using its short-term credit facilities to help finance the Elm Road Units.
In addition, for the nine months ended September 30, 2011, net short-term debt repayments were $3.5 million compared to $19.0 million in the prior year.
Capitalization Ratios
MGE Energy's capitalization ratios were as follows:
60.2%
59.4%
39.8%
38.0%
2.6%
*Includes the current portion of long-term debt.
MGE Energy's and MGE's Capital Requirements
MGE Energy's and MGE's liquidity are primarily affected by their capital requirements. During the nine months ended September 30, 2011, capital expenditures for MGE Energy and MGE totaled $44.9 million, which included $43.1 million of capital expenditures for utility operations and $1.6 million of capital expenditures for the Elm Road Units.
In March 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. The operator's current estimate shows that MGE's share of the capital expenditures required to comply with this project will be approximately $140 million. As of September 30, 2011, MGE had incurred $1.4 million (excluding carrying costs) in deferred pre-certification and construction expenditures at Columbia related to the proposed project. MGE expects to incur capital expenditures as follows: $5 million for the remainder of 2011, $53 million in 2012, $68 million in 2013, and $13 million in 2014. MGE plans to finance this project primarily from internal sources, although it expects some long-term debt financing to be necessary.
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's or MGE's borrowing is subject to default or prepayment as a result of a downgrading of credit ratings, although a downgrading of MGE'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 nine months ended September 30, 2011. Further discussion of environmental matters is included in MGE Energy's and MGE's 2010 Annual Report on Form 10-K and Footnote 9.a. of Notes to Consolidated Financial Statements in this Report.
Columbia is a coal-fired generating station operated by WPL in which WPL, WPSC and MGE have ownership interests. In September 2010, the Sierra Club filed a civil lawsuit against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. See Footnote 9.a. for additional information regarding these matters.
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Air quality regulations promulgated by the EPA and the WDNR in accordance with the CAA and the Clean Air Act Amendments of 1990 impose restrictions on emission of particulates, sulfur dioxide (SO2) nitrogen oxides (NOx) and other pollutants and require permits for operation of emission sources. These permits have been obtained by MGE and must be renewed periodically.
Various initiatives, including the EPA's recently finalized Cross-State Air Pollution Rule (CSAPR), maximum achievable control technology (MACT) standards, new source performance standards (NSPS) and the Clean Air Visibility Rule (also known as the Regional Haze Rule), as well as state mercury emissions limits, are expected to result in additional operating and capital expenditure costs for electric generating units.
MGE has been evaluating CSAPR and the supplemental proposed rule and will adjust environmental compliance plans as needed. The Columbia generating facility which is operated by WPL (MGE has a 22% ownership interest) has significantly fewer SO2 allocations than recent actual emissions. Planned new SO2 controls at Columbia will not be completed until mid 2014. MGE's share of this project will be approximately $140 million. Other interim operational strategies are being evaluated by the co-owners of Columbia to address anticipated SO2 allowance deficiencies in 2012. Either additional allowances, if available, will need to be purchased or Columbia generation will likely need to be reduced to comply with CSAPR limits in 2012. MGE estimates that its fuel costs could increase as much as $14.5 million in 2012 related to CSAPR compliance and has requested deferred rate recovery of these costs from the PSCW.
On March 16, 2011, the EPA proposed pollution control standards to limit mercury, acid gases and other hazardous air pollutants from new and existing coal and oil-burning electric generating units (EGU). This proposed rule is commonly referred to as EGU MACT. The current version of this proposed rule establishes numerical limits for HAPs, work practice methods, and other standards based on several defined subcategories of EGUs. MGE's generating facilities should meet MACT criteria under the current proposed rule. The EPA has indicated that they will be delaying the release of the final rule for 30 days and has set December 16, 2011 as the release date. MGE cannot fully evaluate the operational and financial impacts of this rule until it is finalized.
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On March 21, 2011, the EPA finalized its MACT rule for industrial, commercial and institutional (ICI) boilers commonly referred to as Boiler MACT. The final rule includes provisions for ICI boilers that burn fossil fuels including coal, oil and natural gas. MGE owns some smaller natural gas and oil-burning boilers that are governed under this rule. Although the EPA has finalized this rule, it has also indicated that the finalized rule is under evaluation and has offered potential revisions to this rule. MGE cannot fully evaluate the operational and financial impacts of this rule until the revisions are settled.
MGE is subject to water quality regulations issued by the WDNR. These regulations include discharge standards, which require the use of effluent-treatment processes equivalent to categorical "best practicable" or "best available" technologies under compliance schedules established under the Federal Water Pollution Control Act. The WDNR has published categorical regulations for chemical and thermal discharges from electric-steam generating plants. The regulations limit discharges from MGE's plants into Lake Monona and other Wisconsin waters.
On March 28, 2011, the EPA proposed and asked for public comment on standards to reduce entrainment (drawing aquatic life into a plant's cooling system) and impingement (trapping aquatic life on screens) from existing structures designed to take in cooling water for facilities such as power plants. This rule is commonly referred to as Phase II of Section 316(b). The proposed rule includes provisions for structures designed to take in as little as two million gallons per day. Both our Blount and Columbia generating plants are subject to the impingement and entrainment aspects of the current proposed rule. Our WCCF plant is subject to the impingement aspect only under the current proposed rule. MGE is following developments on this proposed rule and evaluating the impact of these proposed regulations on our operations and cannot estimate the potential costs until the rule is final.
Global climate change
MGE is a producer of GHG emissions, primarily from the fossil fuel generating facilities it utilizes to meet customers' energy needs, as well as from its natural gas pipeline system and fleet vehicles. Climate change and the regulatory response to it could significantly affect our operations in a number of ways, including increased operating costs and capital expenditures, restrictions on energy supply options, permitting difficulties and emission limits. The probability and specific impact of such regulation cannot be reasonably estimated until final legislation and/or regulations are passed. MGE management would expect to seek and receive rate recovery of such compliance costs, if and when required. MGE will continue to monitor proposed climate change legislation and regulation.
EPA Rule on Greenhouse Gas Reporting
On March 18, 2011, the EPA published in the Federal Register a final regulation extending the Greenhouse Gas Mandatory Reporting Rule (GHG MRR) reporting deadline to September 30, 2011 for data required to be collected for reporting year 2010. MGE met the September 30, 2011 reporting deadline. As the EPA continues to publish proposed revisions in 2011, MGE has continued to monitor the EPA's evolving GHG reporting rule.
In March 2009, MGE had received notification from MISO that in order to meet national electric system reliability standards, MGE would need to keep Blount available at its full capacity until MISO declares that the 90 MW are no longer needed for system reliability. MGE recently received notification from MISO that the 90 MW of capacity is no longer needed to meet reliability standards and is now available for retirement on or after December 31, 2011. As a result, MGE estimates the reduction in capacity and the transition to operate exclusively on natural gas will occur by the end of 2011. MGE was previously estimating the reduction in capacity to occur in 2013.
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Receivable – Margin Account
New Accounting Principles
See Footnote 14 for discussion of new accounting pronouncements.
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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 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.
MGE's electric operations burn natural gas in several of its peaking power plants or as a supplemental fuel at several coal-fired plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE bears regulatory risk for the recovery of such fuel and purchased power costs when they are higher than the base rate established in its current rate structure.
The PSCW approved new fuel rules that became effective January 1, 2011. The new rules require the PSCW and Wisconsin utilities to automatically defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the deferred costs is determined on an annual basis and will be adjusted in future billings to its electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual fuel rules costs fall outside the lower end of the range and would defer costs, less any excess revenues, if the actual fuel rules costs exceeded the upper end of the range. Excess revenues are defined as revenues in the plan year that provide MGE with a greater return on common equity than authorized by the PSCW in MGE'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 bandwidth. For 2011, fuel and purchased power costs included in MGE's base fuel rates are $90.8 million. See Footnote 12.b. for additional information.
MGE's gas segment is governed by the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to 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 ranges from eighteen months to four years.
MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds FTRs, which are used to hedge the risk of increased congestion charges. At September 30, 2011, the cost basis of these instruments exceeded their fair value by $0.2 million. Under the PGA clause and electric fuel rules, MGE may include in the costs of fuel (natural gas or power) the costs and benefits of the aforementioned fuel price risk management tools. Because these costs/benefits are recoverable, the related unrealized loss/gain has been deferred on the balance sheet as a regulatory asset/liability.
MGE has also entered into a ten-year purchased power agreement that provides MGE with firm capacity and energy beginning June 1, 2012, and ending on May 31, 2022 (the "base term"). The agreement also allows MGE the option to purchase power during a period of time preceding the base term as well as an option to extend the contract after the base term. The agreement is a derivative contract and is recognized at its fair value on the balance sheet. The fair value of the contract at September 30, 2011, reflects a loss position of $26.4 million.
Interest Rate Risk
Both MGE Energy and MGE have short term borrowings at varying interest rates. MGE issues commercial 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 includes 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 on accrual contracts. As of September 30, 2011, 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 316 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,631 square miles in Wisconsin. Based on results for the year ended December 31, 2010, no one customer constituted more than 9% 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.
52
During the third quarter of 2011, 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, the registrants do not control or manage certain of their unconsolidated entities and thus, their access and ability to apply their procedures to those entities is more limited than is the case for their consolidated subsidiaries.
As of September 30, 2011, each registrant's principal executive officer and principal financial officer concluded that its disclosure controls and procedures were effective. Each registrant intends to continually strive to improve its disclosure controls and procedures to enhance the quality of its financial reporting.
During the quarter ended September 30, 2011, there were no changes in either registrant's internal controls over financial reporting that materially affected, or are reasonably likely to materially affect, that registrant's internal control over financial reporting.
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.c. for a description of several proceedings involving MGE.
Issuer Purchases of Equity Securities
Maximum number (or
Approximate Dollar
Total Number
Value) of Shares That
Number
Average
of Shares
May Yet Be
of
Price
Purchased as Part of
Purchased
Paid
Publicly Announced
Under the Plans or
Period
per Share
Plans or Programs*
Programs*
July 1-31, 2011
36,922
41.43
August 1-31, 2011
43,485
41.01
September 1-30, 2011
80,650
41.40
161,057
41.30
* Under the 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. In June 2009, MGE Energy switched to using open market purchases to provide shares to meet obligations to participants in the Stock Plan. The shares are purchased on the open market through a 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.
Statement regarding computation of ratio of earnings to fixed charges for Madison Gas and Electric Company.
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2011, filed by the following officers for the following companies:
31.1
Filed by Gary J. Wolter for MGE Energy, Inc.
31.2
Filed by Jeffrey C. Newman for MGE Energy, Inc.
31.3
Filed by Gary J. Wolter for Madison Gas and Electric Company
31.4
Filed by Jeffrey C. Newman for Madison Gas and Electric Company
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) as to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2011, filed by the following officers for the following companies:
32.1
32.2
32.3
32.4
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: November 4, 2011
/s/ Gary J. Wolter
Gary J. Wolter
Chairman, President and Chief Executive Officer
(Duly Authorized Officer)
/s/ Jeffrey C. Newman
Jeffrey C. Newman
Vice President, Chief Financial Officer, Secretary and Treasurer
(Chief Financial and Accounting Officer)
MADISON GAS AND ELECTRIC COMPANY