Attached files
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| 8-K - 8-K_02/11/2011 - NORTHWESTERN CORP | ek_021110.htm |
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NorthWestern Corporation
d/b/a NorthWestern Energy
3010 W. 69th Street
Sioux Falls, SD 57108
www.northwesternenergy.com
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NYSE: NWE
News Release
FOR IMMEDIATE RELEASE
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Media Contact:
Claudia Rapkoch
(866) 622-8081
claudia.rapkoch@northwestern.com
Investor Relations Contact:
Dan Rausch
(605) 978-2902
daniel.rausch@northwestern.com
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NORTHWESTERN REPORTS 2010 FINANCIAL RESULTS
Reports improvement in earnings per share of 5.9% over 2009
Increased the quarterly dividend 5.9% to 36 cents per share
Provides guidance for 2011 of $2.25 - $2.40 per fully diluted share
SIOUX FALLS, S.D. – Feb. 11, 2011 – NorthWestern Corporation d/b/a NorthWestern Energy (NYSE: NWE) reported financial results for the year ended Dec. 31, 2010.
Highlights for the year include:
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·
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Net income improved $4 million to $77.4 million, or $2.14 per fully diluted share, for 2010 compared with $73.4 million, or $2.02 per fully diluted share, in 2009;
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In addition, the Company’s Board of Directors declared a common stock dividend of 36 cents per share, payable on March 31, 2011, to common shareholders of record as of March 15, 2011; and
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In January 2011, Moody’s Investors Services upgraded our senior secured debt from A3 to A2 and our senior unsecured bank credit facility from Baa2 to Baa1.
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Completed the Mill Creek Generating Station, a $183 million, 150-megawatt natural gas-fired regulating reserve power plant that was placed into commercial operation on January 1, 2011;
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Received a final order from the Montana Public Service Commission (MPSC) in NWE’s electric and natural gas delivery services rate filing, approving a net increase of $5.4 million annually in the utility’s revenue requirement;
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Continued to make progress on our strategy to gain more control on our supply for our customers by signing memoranda of understanding to develop two wind projects in Montana totaling 48 megawatts and purchased a majority interest in the Battle Creek Natural Gas Field in Montana (Battle Creek Field) for a total of $12.4 million;
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“2010 was a successful year as we saw our gross margin, operating income and net income improve compared with 2009,” said Bob Rowe, President and CEO. “These strong results and our free cash flow allowed us to increase our quarterly dividend for the fifth year in a row. Our significant dividend increase was done to remain within our targeted, and sustainable, payout range.”
“In addition, we added the Mill Creek Generating Station to our existing Montana generation resources, under budget and on time. The Mill Creek Station will enhance service to our customers at regulated cost-of-service rates,” added Rowe. “We remain committed to investments in generation resources that will provide our customers with safe and reliable service at a reasonable price. We are also focused on investing in our electric and natural gas distribution systems to ensure their long-term reliability, capacity and safety for our customers.”
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 2
Annual Financial Results
Consolidated net income was $77.4 million or $2.14 per diluted share for the year ended Dec. 31, 2010, compared with consolidated net income of $73.4 million or $2.02 per diluted share for the year ended Dec. 31, 2009.
NORTHWESTERN CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(unaudited)
(in thousands, except per share amounts)
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Three Months Ended
December 31,
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Twelve Months Ended
December 31,
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2010
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2009
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2010
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2009
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||||||||||
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Total Revenues
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291,670
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302,408
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1,110,720
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1,141,910
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|||||||||
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Cost of sales
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140,404
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153,653
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531,089
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573,686
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Gross Margin
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151,266
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148,755
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579,631
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568,224
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Operating Expenses
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Operating, general and administrative
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63,176
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61,408
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237,047
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245,618
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Property and other taxes
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19,711
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16,181
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88,198
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79,582
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Depreciation
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23,072
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22,080
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91,769
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89,039
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Total Operating Expenses
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105,959
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99,669
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417,014
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414,239
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Operating Income
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45,307
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49,086
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162,617
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153,985
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Interest Expense, net
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(16,413
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)
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(17,357
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)
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(65,826
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)
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(67,760
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)
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Other Income
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1,424
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1,307
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6,345
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2,499
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Income Before Income Taxes
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30,318
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33,036
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103,136
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88,724
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Income Tax Expense
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(7,730
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)
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(7,427)
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(25,760
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)
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(15,304
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)
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Net Income
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$
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22,588
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$
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25,609
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$
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77,376
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$
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73,420
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Average Common Shares Outstanding
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36,217
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36,142
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36,190
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36,091
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Basic Earnings per Average Common Share
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$
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0.63
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$
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0.70
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$
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2.14
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$
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2.03
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Diluted Earnings per Average Common Share
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$
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0.63
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$
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0.70
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$
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2.14
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$
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2.02
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Dividends Declared per Average Common Share
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$
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0.340
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$
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0.335
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$
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1.36
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$
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1.34
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The following table reconciles the primary changes in 2010 results from 2009:
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Twelve Months Ended
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Pre-tax
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Net
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EPS - Fully
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($millions, except EPS)
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Income
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Income 1
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Diluted
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Full Year 2009 reported
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$ 88.7
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$ 73.4
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$ 2.02
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Insurance reserves
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6.0
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3.7
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0.10
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Postretirement health care
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4.0
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2.5
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0.07
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Other Income (mainly Mill Creek AFUDC)
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3.8
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2.4
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0.06
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Montana electric interim rate increase
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2.8
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1.7
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0.05
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All other gross margin
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2.4
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1.5
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0.04
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NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 3
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Jointly owned plant operations
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2.3
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1.4
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0.04
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Change in market value of other capacity contract
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2.0
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1.2
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0.03
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Interest expense
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1.9
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1.2
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0.03
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Demand-side management (DSM) lost revenues
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1.7
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1.0
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0.03
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Transmission capacity
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1.5
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0.9
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0.03
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South Dakota retail electric volumes
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1.5
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0.9
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0.03
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Reclamation settlement
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1.0
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0.6
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0.02
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Legal and professional fees
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0.9
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0.6
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0.01
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Pension
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0.7
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0.4
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0.01
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Labor
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0.6
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0.4
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0.01
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Gas production
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0.5
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0.3
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0.01
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All other OG&A
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0.5
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0.3
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0.01
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Insurance recoveries and settlements
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0.3
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0.2
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0.01
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Bad debt expense
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0.3
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0.2
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0.01
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South Dakota wholesale electric
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(1.2)
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(0.7)
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(0.02)
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Retail natural gas volumes
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(2.7)
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(1.7)
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(0.05)
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Depreciation expense
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(2.8)
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(1.7)
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(0.05)
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QF supply costs
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(3.6)
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(2.2)
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(0.06)
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Montana property tax, net of tracker
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(3.6)
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(2.2)
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(0.06)
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Operating and maintenance (tree trimming & proactive work)
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(6.5)
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(4.0)
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(0.11)
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Items related to income tax
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Repairs tax deduction (2010 greater than 2009)
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2.0
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0.06
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Bonus depreciation and other tax items
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-
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1.7
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0.05
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Increase in valuation allowance accrual
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-
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(0.7)
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(0.02)
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2008 Repairs tax deduction recorded in 2009
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-
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(7.9)
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(0.22)
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All other, net
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0.1
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0.1
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-
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Subtotal
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0.12
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Full Year 2010 reported
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$ 103.1
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$ 77.4
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$ 2.14
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1.) Income Tax Benefit (Expense) calculation on reconciling items assumes normal effective tax rate of 38.5%.
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For more information see www.northwesternenergy.com/documents/investor/Q410.pdf
Consolidated gross margin for 2010 was $579.6 million compared with $568.2 million for 2009. The increase in gross margin was due to an increase in Montana property taxes included in a tracker, an increase in Montana electric transmission and distribution rates, a change in the market value of a capacity contract included in our “other” segment, an increase in demand side management lost revenues recovered through our supply tracker, improved transmission capacity revenues caused by increased demand, an increase in electric volumes due to warmer summer weather in South Dakota, a decrease in cost of sales due to a settlement to recover previously incurred reclamation costs and gas production margin from the purchase of the Battle Creek Field in September 2010. These increases in margin were offset in part by higher qualifying facility related supply costs, a decrease in retail natural gas volumes caused by warmer winter weather and lower wholesale electric prices in South Dakota.
Consolidated operating, general and administrative expenses were $237.0 million for the year ended Dec. 31, 2010 as compared with $245.6 million during 2009. The decrease in operating, general and administrative expenses of $8.6 million was primarily due to the following:
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Lower insurance reserves due to fewer claims compared with the prior year and a favorable arbitration decision in the first quarter of 2010;
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NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 4
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Lower postretirement health care costs due to a plan amendment during the fourth quarter of 2009;
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Lower plant operations costs due to scheduled maintenance and an unplanned outage at Colstrip Unit 4 for a rotor repair in 2009, offset in part by increased costs in 2010 related to chemical injection technologies installed at the Colstrip plant;
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Decreased legal and professional fees;
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Lower pension expense;
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Decreased labor costs primarily due to lower severance costs, offset in part by compensation increases;
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Higher insurance recoveries and settlements due to $5.9 million received during 2010 as compared with $5.6 million received during 2009; and
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Lower bad debt expense based on lower average customer receivables.
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These decreases were partially offset by:
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Increased operating and maintenance costs primarily due to tree trimming and proactive line maintenance. The increase in these activities during 2010 was part of our commitment to maintain high level reliability and improve system performance. We expect these costs to continue to increase in 2011; however, we submitted a request for an accounting order to the MPSC in January 2011 to defer and amortize incremental operating and maintenance expense for 2011 and 2012 over a five-year period beginning in 2013 associated with our distribution infrastructure project.
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Higher operating expenses recovered from customers through supply trackers primarily related to costs incurred for customer efficiency programs, which have no impact on operating income.
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Property and other tax expenses were $88.2 million for the year ended Dec. 31, 2010, compared with $79.6 million during 2009 due to higher assessed property valuations in Montana.
Depreciation expense was $91.8 million for the year ended Dec. 31, 2010, compared with $89.0 million during 2009. The increase in depreciation expense was related primarily to plant additions.
Interest expense was $65.8 million for the year ended Dec. 31 2010, compared with $67.8 million for the year ended Dec. 31, 2009. The decrease in interest expense was due to capitalizing $3.2 million of AFUDC primarily related to the Mill Creek Generating Station, partially offset by an increase in interest expense due to increased debt outstanding. As the Mill Creek Generating Station began operating in January 2011, we will not have AFUDC associated with that plant in 2011.
Consolidated other income in 2010 was $6.4 million, compared with $ 2.5 million in 2009. The increase in other income was primarily due to an increase of $5.0 million of capitalized equity portion of AFUDC related to the MCGS, partially offset by lower interest income. We will not have AFUDC associated with that plant in 2011.
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 5
Consolidated income tax expense in 2010 was $25.8 million as compared with $15.3 million in 2009. The effective tax rate in 2010 was 25.0% as compared with 17.2% for the same period of 2009. These effective tax rates differ from the federal tax rate of 35% primarily due to the regulatory flow-through treatment of repairs deductions and state tax depreciation deductions. While we reflect an income tax provision in our financial statements, we expect our cash payments for income taxes will be minimal through at least 2015,based on our projected taxable income and anticipated use of consolidated net operating loss carryforwards.
Fourth Quarter Financial Results
Consolidated net income for the fourth quarter ended Dec. 31, 2010, was $22.6 million, or $.63/share, compared with $25.6 million, or $.70/share for the fourth quarter in 2009. The decrease was primarily due to an increase in operating expenses, partially offset by an increase in gross margin.
Consolidated operating expenses increased in the fourth quarter approximately $6.3 million, primarily due to increased property taxes in Montana. Consolidated gross margin increased in the fourth quarter approximately $2.5 million primarily due to an increase in Montana property taxes included in a tracker and an increase in Montana electric transmission and distribution rates, partially, offset by warmer winter weather in our service territories.
Results from Regulated Operations
Regulated electric gross margin for the year ended Dec. 31, 2010, was $434.4 million, up 2.1%, compared with $425.6 million for 2009. The improvement was primarily due to the recovery of increased Montana property taxes included in a tracker, the increase in Montana transmission and distribution rates, the increase in demand side management revenue recovered, an increase in transmission capacity revenues, an increase in retail electric volumes in South Dakota due to warmer summer weather, a decrease in cost of sales due to a settlement to recover previously incurred reclamation costs and higher revenues for operating expenses recovered in supply trackers for customer efficiency programs.
This increase in gross margin was offset in part by higher qualifying facility related supply costs based on actual qualifying facility pricing and output and lower average wholesale prices in South Dakota.
Regulated retail electric volumes for the year ended Dec. 31, 2010, totaled 9,856,000 megawatt hours compared with 9,958,000 megawatt hours for the year ended 2009. The decrease was due primarily to a decline in Montana volumes caused by a weaker economy, offset by an increase in volumes in South Dakota from favorable weather and customer growth, compared with 2009.
Wholesale electric volumes were 1,008,000 megawatt hours for the year ended Dec. 31, 2010, an increase from 859,000 megawatt hours for 2009. Wholesale volumes increased in Montana due to higher plant availability, and increased slightly in South Dakota due to lower plant availability in 2009 related to scheduled maintenance. We will no longer have Montana wholesale volumes beginning January 1, 2011 as these volumes will be dedicated to retail customers, due to the expiration of a wholesale supply contract. In addition, we estimate our South Dakota wholesale volumes will increase by approximately 24 megawatt hours and margin will increase by approximately $1.3 million in 2011 primarily due to higher plant availability at higher average prices.
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 6
Regulated electric gross margin for the fourth quarter of 2010 was $108.2 million as compared with $104.4 million for the same period in 2009.
Regulated retail electric volumes for the fourth quarter of 2010 totaled 2,466,000 megawatt hours as compared with 2,510,000 megawatt hours in the same period in 2009. Regulated wholesale electric volumes for the fourth quarter of 2010 were 230,000 megawatt hours, a decrease from 272,000 megawatt hours in the same period in 2009.
Regulated natural gas gross margin was $143.9 million for the year ended Dec. 31, 2010, compared with $144.5 million during 2009. The decline in margin is primarily due to warmer winter weather, offset in part by an increase in recovery of property taxes included in a tracker as compared with the same period in 2009 and gas production margin related to the purchase of our interest in the Battle Creek Field.
Regulated retail natural gas volumes were 30,631,000 dekatherms for the year ended Dec. 31, 2010, compared with 32,124,000 dekatherms for the same period in 2009.
Regulated natural gas gross margin for the fourth quarter of 2010 was $42.7 million compared with $44.3 million for the same period in 2009.
Regulated retail natural gas volumes were 9,227,000 dekatherms for the fourth quarter of 2010 compared with 10,674,000 dekatherms for the same period in 2009. The decline was primarily due to warmer winter weather in our service territories.
Liquidity and Capital Resources
As of Dec. 31, 2010, cash and cash equivalents were $6.2 million compared with $4.3 million at Dec. 31, 2009. The Company had $96.5 million available from its revolving credit facility at Dec. 31, 2010, compared with $180.9 million at Dec. 31, 2009.
Cash provided by operating activities totaled $218.9 million for the year ended Dec. 31, 2010, as compared with $116.8 million during 2009. This increase in operating cash flows is primarily related to a decrease in contributions to our qualified pension plans of $82.9 million as compared with 2009. In addition, during 2009 we paid a lawsuit verdict of approximately $26.7 million and prepaid a power purchase agreement for $10.8 million. Partially offsetting these changes were increased cash outflows for natural gas storage injections during 2010 as compared with 2009.
Cash used in investing activities totaled $240.7 million during the year ended December 31, 2010, as compared with $189.1 million during 2009. During 2010, we invested $228.4 million in property, plant and equipment additions, including approximately $92.1 million related to Mill Creek Generating Station, as compared with $189.4 million in property, plant and equipment additions during 2009.
Cash provided by financing activities totaled $23.6 million during 2010, as compared with $65.3 million during 2009. During 2010 we had net borrowings of $80.8 million, paid dividends on common stock of $49.0 million and paid deferred financing costs of $8.0 million. During 2009 we had net borrowings of $125.0 million, paid dividends on common stock of $48.2 million and paid deferred financing costs of $10.8 million.
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 7
Dividend Declaration
NorthWestern’s Board of Directors declared a quarterly common stock dividend of 36 cents per share, payable on Mar. 31, 2011, to common shareholders of record as of Mar. 15, 2011, an increase of 2 cents per share from Dec. 31, 2010.
Rate Case Update
In December, we received a final order from the Montana Public Service Commission (MPSC) in NWE’s electric and natural gas delivery services rate filing, approving an increase of $6.4 million annually in the electric utility’s revenue requirement and decrease of approximately $1 million in the natural gas utility’s revenue requirement. The final order includes several requirements applicable to the electric utility’s revenue requirement, including the obligation to implement a modified lost revenue adjustment mechanism (filed originally as a decoupling mechanism) with a related reduction in the return on equity for the electric utility from 10.25% to 10%, and an inclining block rate structure for residential electric customers. NorthWestern has appealed these provisions of the order.
2011 Earnings Outlook
NorthWestern expects its earnings for 2011 to be $2.25 - $2.40 per fully diluted share.
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Summary:
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Net Income
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EPS
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2010 Reported GAAP
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$ 77.4
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$ 2.14
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Adjustments:
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Insurance recoveries
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$ (2.8)
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$ (0.08)
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Montana rate adjustment
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(1.9)
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(0.05)
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Weather - Montana
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2.1
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0.06
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2010 Earnings, comparable with guidance of $1.95 - $2.10
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$ 74.8
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$ 2.07
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EPS Bridge
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| $ 2.07 | |||||
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Year / Year Changes
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Low
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High
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Mill Creek net income
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$ 0.16
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$ 0.18
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Montana rate adjustment
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0.09
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0.11
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Expiration of legacy CU4 contract
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0.10
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0.10
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Non-weather related load growth - Montana gas & electric
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0.10
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0.13
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Montana electric transmission OASIS (wholesale) sales
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0.03
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0.04
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Labor and other miscellaneous increased expenses
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(0.10)
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(0.08)
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Scheduled maintenance on electric plants
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(0.07)
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(0.06)
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Property and other taxes (net of margin recovery)
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(0.10)
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(0.09)
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Depreciation - increased utility capital
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(0.05)
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(0.04)
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NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 8
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Incremental bonus depreciation on new tax legislation
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0.02
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0.04
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Subtotal
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$ 0.18
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$ 0.33
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2011 Range
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$ 2.25
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$ 2.40
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|||
Basic assumptions include the following expectations:
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A consolidated income tax rate of approximately 20% - 24% of pre-tax income;
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·
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Fully diluted average shares outstanding of 36.4 million; and
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·
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Normal weather in the Company’s electric and natural gas service territories for 2010.
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Company Hosting Investor Conference Call
NorthWestern will host an investor conference call today at 3:00 pm Eastern Time (2:00 p.m. Central Time) to review its financial results for the year ended Dec. 31, 2010.
The conference call will be webcast live on the Internet at http://www.northwesternenergy.com under the “Investor Information” heading. To listen, please go to the site at least 10 minutes in advance of the call to register. An archived webcast will be available shortly after the call.
A telephonic replay of the call will be available beginning at 5:00 p.m. ET on Feb. 11, 2011, through March 11, 2011, at 800-475-6701, access code 189762.
Annual Meeting
The Company's Annual Meeting of Stockholders will be held on Wednesday, April 27, 2011, in Grand Island, Nebraska. The record date for the annual meeting is February 28, 2011. The annual meeting notice, proxy statement, annual report to stockholders and voting instructions will be provided approximately 40 days prior to the meeting date to stockholders as of the record date.
About NorthWestern Energy
NorthWestern Energy is one of the largest providers of electricity and natural gas in the Upper Midwest and Northwest, serving approximately 665,000 customers in Montana, South Dakota and Nebraska. More information on NorthWestern Energy is available on the Company's Web site at www.northwesternenergy.com.
SPECIAL NOTE REGARDING FORWARD—LOOKING STATEMENTS
This press release contains forward-looking statements within the meaning of the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995, including, without limitation, the information under “2011 Earnings Outlook”. Forward-looking statements often address our expected future business and financial performance, and often contain words such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “seeks,” or “will.” These statements are based upon our current expectations and speak only as of the date hereof. Our actual future business and financial performance may differ materially and adversely from those expressed in any forward-looking statements as a result of various factors and uncertainties, including, but not limited to:
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 9
|
·
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potential adverse federal, state, or local legislation or regulation or adverse determinations by regulators could have a material adverse effect on our liquidity, results of operations and financial condition;
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·
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we have capitalized approximately $16.7 million in preliminary survey and investigative costs related to our proposed Mountain States Transmission Intertie transmission project. If our efforts to complete MSTI are not successful we may have to write-off all or a portion these costs, which could have a material adverse effect on our results of operations;
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·
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changes in availability of trade credit, creditworthiness of counterparties, usage, commodity prices, fuel supply costs or availability due to higher demand, shortages, weather conditions, transportation problems or other developments, may reduce revenues or may increase operating costs, each of which could adversely affect our liquidity and results of operations;
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·
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unscheduled generation outages or forced reductions in output, maintenance or repairs, which may reduce revenues and increase cost of sales or may require additional capital expenditures or other increased operating costs; and
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·
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adverse changes in general economic and competitive conditions in the U.S. financial markets and in our service territories.
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Our Annual Report on Form 10-K, recent and forthcoming Quarterly Reports on Form 10-Q, recent Current Reports on Form 8-K and other Securities and Exchange Commission filings discuss some of the important risk factors that may affect our business, results of operations and financial condition.
We undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.
# # #
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 10
NORTHWESTERN CORPORATION
CONSOLIDATED BALANCE SHEETS
(in thousands)
|
Year Ended December 31,
|
|||||||
|
2010
|
2009
|
||||||
|
ASSETS
|
|||||||
|
303,054
|
264,827
|
||||||
|
Property, plant, and equipment, net
|
2,117,977
|
1,964,121
|
|||||
|
Goodwill
|
355,128
|
355,128
|
|||||
|
Regulatory assets
|
222,341
|
182,382
|
|||||
|
Other noncurrent assets
|
39,169
|
28,674
|
|||||
|
$
|
3,037,669
|
$
|
2,795,132
|
||||
|
LIABILITIES AND SHAREHOLDERS' EQUITY
|
|||||||
|
Current maturities of long-term debt and capital leases
|
$
|
7,854
|
$
|
7,320
|
|||
|
296,115
|
287,672
|
||||||
|
Long-term capital leases
|
34,288
|
35,570
|
|||||
|
Long-term debt
|
1,061,780
|
981,296
|
|||||
|
Deferred income taxes
|
232,709
|
161,188
|
|||||
|
Noncurrent regulatory liabilities
|
251,133
|
238,332
|
|||||
|
Other noncurrent liabilities
|
333,443
|
296,730
|
|||||
|
2,217,322
|
2,008,108
|
||||||
|
Total shareholders' equity
|
820,347
|
787,024
|
|||||
|
Total liabilities and shareholders' equity
|
$
|
3,037,669
|
$
|
2,795,132
|
|||
NORTHWESTERN CORPORATION
(in thousands)
|
Year Ended December 31,
|
|||||||||||
|
2010
|
2009
|
2008
|
|||||||||
|
Operating Activities
|
|||||||||||
|
Net income
|
$
|
77.4
|
$
|
73.4
|
$
|
67.6
|
|||||
|
Non-cash adjustments to net income
|
137.4
|
137.5
|
132.3
|
||||||||
|
Changes in working capital
|
(1.8
|
)
|
(40.3
|
)
|
(7.8
|
)
|
|||||
|
Other noncurrent assets and liabilities
|
5.9
|
(53.8
|
)
|
6.2
|
|||||||
|
Cash Provided by Operating Activities
|
218.9
|
116.8
|
198.3
|
||||||||
|
Cash Used in Investing Activities
|
(240.7
|
)
|
(189.1
|
)
|
(124.4
|
)
|
|||||
|
Cash Provided by (Used in) Financing Activities
|
23.6
|
65.3
|
(75.4
|
)
|
|||||||
|
Net Increase (Decrease) in Cash and Cash Equivalents
|
$
|
1.9
|
$
|
(7.0
|
)
|
$
|
(1.5
|
)
|
|||
|
Cash and Cash Equivalents, beginning of period
|
$
|
4.3
|
$
|
11.3
|
$
|
12.8
|
|||||
|
Cash and Cash Equivalents, end of period
|
$
|
6.2
|
$
|
4.3
|
$
|
11.3
|
|||||
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 11
NORTHWESTERN CORPORATION
YEAR ENDED DECEMBER 31, 2010 AND 2009 SEGMENT RESULTS
(Unaudited)
|
Electric
|
Gas
|
Other
|
Eliminations
|
Total
|
|||||||||||||||
|
Operating revenues
|
$
|
790,701
|
$
|
318,735
|
$
|
1,284
|
$
|
—
|
$
|
1,110,720
|
|||||||||
|
Cost of sales
|
356,325
|
174,764
|
—
|
—
|
531,089
|
||||||||||||||
|
Gross margin
|
434,376
|
143,971
|
1,284
|
—
|
579,631
|
||||||||||||||
|
Operating, general and administrative
|
169,483
|
71,088
|
(3,524
|
)
|
—
|
237,047
|
|||||||||||||
|
Property and other taxes
|
65,027
|
23,159
|
12
|
—
|
88,198
|
||||||||||||||
|
Depreciation
|
74,227
|
17,509
|
33
|
—
|
91,769
|
||||||||||||||
|
Operating income
|
125,639
|
32,215
|
4,763
|
—
|
162,617
|
||||||||||||||
|
Interest expense
|
(49,576
|
)
|
(12,608
|
)
|
(3,642
|
)
|
—
|
(65,826
|
)
|
||||||||||
|
Other income
|
5,954
|
284
|
107
|
—
|
6,345
|
||||||||||||||
|
Income tax expense
|
(18,939
|
)
|
(4,183
|
)
|
(2,638
|
)
|
—
|
(25,760
|
)
|
||||||||||
|
Net income (loss)
|
$
|
63,078
|
$
|
15,708
|
$
|
(1,410
|
)
|
$
|
—
|
$
|
77,376
|
||||||||
|
Electric
|
Gas
|
Other
|
Eliminations
|
Total
|
|||||||||||||||
|
Operating revenues
|
$
|
782,318
|
$
|
354,470
|
$
|
6,747
|
$
|
(1,625
|
)
|
$
|
1,141,910
|
||||||||
|
Cost of sales
|
356,722
|
210,016
|
6,948
|
—
|
573,686
|
||||||||||||||
|
Gross margin
|
425,596
|
144,454
|
(201
|
)
|
(1,625
|
)
|
568,224
|
||||||||||||
|
Operating, general and administrative
|
170,656
|
76,730
|
(143
|
)
|
(1,625
|
)
|
245,618
|
||||||||||||
|
Property and other taxes
|
58,488
|
20,953
|
141
|
—
|
79,582
|
||||||||||||||
|
Depreciation
|
71,968
|
17,038
|
33
|
—
|
89,039
|
||||||||||||||
|
Operating income (loss)
|
124,484
|
29,733
|
(232
|
)
|
—
|
153,985
|
|||||||||||||
|
Interest expense
|
(51,193
|
)
|
(12,858
|
)
|
(3,709
|
)
|
—
|
(67,760
|
)
|
||||||||||
|
Other income
|
2,125
|
261
|
113
|
—
|
2,499
|
||||||||||||||
|
Income tax (expense) benefit
|
(13,493
|
)
|
(2,457
|
)
|
646
|
—
|
(15,304
|
)
|
|||||||||||
|
Net income (loss)
|
$
|
61,923
|
$
|
14,679
|
$
|
(3,182
|
)
|
$
|
—
|
$
|
73,420
|
||||||||
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 12
NORTHWESTERN CORPORATION
REGULATED ELECTRIC SEGMENT
(Unaudited)
|
Results
|
||||||||||||||
|
2010
|
2009
|
Change
|
% Change
|
|||||||||||
|
(in millions)
|
||||||||||||||
|
Retail revenue
|
$
|
663.3
|
$
|
660.7
|
$
|
2.6
|
0.4
|
%
|
||||||
|
Transmission
|
47.0
|
45.5
|
1.5
|
3.3
|
||||||||||
|
Wholesale
|
45.0
|
43.9
|
1.1
|
2.5
|
||||||||||
|
Regulatory Amortization and Other
|
35.4
|
32.2
|
3.2
|
9.9
|
||||||||||
|
Total Revenues
|
790.7
|
782.3
|
8.4
|
1.1
|
||||||||||
|
Total Cost of Sales
|
356.3
|
356.7
|
(0.4
|
)
|
(0.1
|
)%
|
||||||||
|
Gross Margin
|
$
|
434.4
|
425.6
|
$
|
8.8
|
2.1
|
%
|
|||||||
|
Revenues
|
Megawatt Hours (MWH)
|
Avg. Customer Counts
|
|||||||||||||||||
|
2010
|
2009
|
2010
|
2009
|
2010
|
2009
|
||||||||||||||
|
(in thousands)
|
|||||||||||||||||||
|
Retail Electric
|
|||||||||||||||||||
|
Montana
|
$
|
223,813
|
$
|
222,610
|
2,323
|
2,317
|
270,536
|
268,492
|
|||||||||||
|
South Dakota
|
44,896
|
43,971
|
555
|
523
|
48,479
|
48,258
|
|||||||||||||
|
268,709
|
266,581
|
2,878
|
2,840
|
319,015
|
316,750
|
||||||||||||||
|
Montana
|
274,017
|
270,558
|
3,149
|
3,161
|
61,003
|
60,445
|
|||||||||||||
|
South Dakota
|
63,508
|
63,004
|
920
|
877
|
11,796
|
11,659
|
|||||||||||||
|
Commercial
|
337,525
|
333,562
|
4,069
|
4,038
|
72,799
|
72,104
|
|||||||||||||
|
Industrial
|
32,927
|
35,902
|
2,746
|
2,899
|
71
|
71
|
|||||||||||||
|
Other
|
24,124
|
24,697
|
163
|
181
|
5,874
|
5,943
|
|||||||||||||
|
Total Retail Electric
|
$
|
663,285
|
$
|
660,742
|
9,856
|
9,958
|
397,759
|
394,868
|
|||||||||||
|
Wholesale Electric
|
|||||||||||||||||||
|
Montana
|
$
|
40,486
|
$
|
38,263
|
788
|
642
|
N/A
|
N/A
|
|||||||||||
|
South Dakota
|
4,503
|
5,653
|
220
|
217
|
N/A
|
N/A
|
|||||||||||||
|
Total Wholesale Electric
|
$
|
44,989
|
$
|
43,916
|
1,008
|
859
|
—
|
—
|
|||||||||||
|
2010 as compared with:
|
||||
|
Cooling Degree-Days
|
2009
|
Historic Average
|
||
|
Montana
|
28% cooler
|
27% cooler
|
||
|
South Dakota
|
78% warmer
|
12% warmer
|
||
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 13
NORTHWESTERN CORPORATION
REGULATED NATURAL GAS SEGMENT
(Unaudited)
|
Results
|
||||||||||||||
|
2010
|
2009
|
Change
|
% Change
|
|||||||||||
|
(in millions)
|
||||||||||||||
|
Retail revenue
|
$
|
268.0
|
$
|
310.1
|
$
|
(42.1
|
)
|
(13.6
|
)%
|
|||||
|
Wholesale and other
|
50.7
|
44.4
|
6.3
|
14.2
|
||||||||||
|
Total Revenues
|
318.7
|
354.5
|
(35.8
|
)
|
(10.1
|
)
|
||||||||
|
Total Cost of Sales
|
174.8
|
210.0
|
(35.2
|
)
|
(16.8
|
)%
|
||||||||
|
Gross Margin
|
$
|
143.9
|
$
|
144.5
|
$
|
(0.6
|
)
|
(0.4
|
)%
|
|||||
|
Revenues
|
Dekatherms (Dkt)
|
Customer Counts
|
|||||||||||||||||
|
2010
|
2009
|
2010
|
2009
|
2010
|
2009
|
||||||||||||||
|
(in thousands)
|
|||||||||||||||||||
|
Retail Gas
|
|||||||||||||||||||
|
Montana
|
$
|
115,570
|
$
|
132,586
|
12,635
|
13,291
|
157,764
|
156,714
|
|||||||||||
|
South Dakota
|
26,342
|
32,462
|
2,787
|
2,925
|
37,263
|
36,815
|
|||||||||||||
|
Nebraska
|
24,653
|
28,531
|
2,624
|
2,674
|
36,515
|
36,458
|
|||||||||||||
|
Residential
|
166,565
|
193,579
|
18,046
|
18,890
|
231,542
|
229,987
|
|||||||||||||
|
Montana
|
58,142
|
66,516
|
6,400
|
6,733
|
22,023
|
21,929
|
|||||||||||||
|
South Dakota
|
22,175
|
26,567
|
3,044
|
3,315
|
5,890
|
5,837
|
|||||||||||||
|
Nebraska
|
18,537
|
20,760
|
2,838
|
2,903
|
4,553
|
4,504
|
|||||||||||||
|
Commercial
|
98,854
|
113,843
|
12,282
|
12,951
|
32,466
|
32,270
|
|||||||||||||
|
Industrial
|
1,702
|
1,650
|
194
|
170
|
285
|
295
|
|||||||||||||
|
Other
|
871
|
1,003
|
109
|
113
|
146
|
142
|
|||||||||||||
|
Total Retail Gas
|
$
|
267,992
|
$
|
310,075
|
30,631
|
32,124
|
264,439
|
262,694
|
|||||||||||
|
2010 as compared with:
|
||||
|
Heating Degree-Days
|
2009
|
Historic Average
|
||
|
Montana
|
1% warmer
|
Remained flat
|
||
|
South Dakota
|
5% warmer
|
2% warmer
|
||
|
Nebraska
|
2% warmer
|
1% warmer
|
||
NorthWestern Reports 2010 Financial Results
Feb. 11, 2011
Page 14
NORTHWESTERN CORPORATION
FOURTH QUARTER SEGMENT RESULTS
(Unaudited)
Three Months Ended December 31, 2010
|
December 31, 2010
|
Electric
|
Gas
|
Other
|
Eliminations
|
Total
|
||||||||||||||
|
Operating revenues
|
$
|
198,439
|
$
|
92,853
|
$
|
378
|
$
|
—
|
$
|
291,670
|
|||||||||
|
Cost of sales
|
90,274
|
50,130
|
—
|
—
|
140,404
|
||||||||||||||
|
Gross margin
|
108,165
|
42,723
|
378
|
—
|
151,266
|
||||||||||||||
|
Operating, general and administrative
|
45,262
|
18,634
|
(720
|
)
|
—
|
63,176
|
|||||||||||||
|
Property and other taxes
|
14,403
|
5,305
|
3
|
—
|
19,711
|
||||||||||||||
|
Depreciation
|
18,664
|
4,400
|
8
|
—
|
23,072
|
||||||||||||||
|
Operating income
|
29,836
|
14,384
|
1,807
|
—
|
45,307
|
||||||||||||||
|
Interest expense
|
(12,267
|
)
|
(2,891
|
)
|
(1,255
|
)
|
—
|
(16,413
|
)
|
||||||||||
|
Other income (loss)
|
1,439
|
(42)
|
27
|
—
|
1,424
|
||||||||||||||
|
Income tax expense
|
(1,449
|
)
|
(3,142
|
)
|
(3,139
|
)
|
—
|
(7,730
|
)
|
||||||||||
|
Net income (loss)
|
$
|
17,559
|
$
|
8,309
|
$
|
(3,280
|
)
|
$
|
—
|
$
|
22,588
|
||||||||
Three Months Ended December 31, 2009
|
December 31, 2009
|
Electric
|
Gas
|
Other
|
Eliminations
|
Total
|
||||||||||||||
|
Operating revenues
|
$
|
202,179
|
$
|
100,132
|
$
|
498
|
$
|
(400)
|
$
|
302,409
|
|||||||||
|
Cost of sales
|
97,758
|
55,911
|
(16)
|
—
|
153,653
|
||||||||||||||
|
Gross margin
|
104,421
|
44,221
|
514
|
(400)
|
148,756
|
||||||||||||||
|
Operating, general and administrative
|
42,081
|
17,923
|
1,805
|
(400)
|
61,409
|
||||||||||||||
|
Property and other taxes
|
12,054
|
4,097
|
30
|
—
|
16,181
|
||||||||||||||
|
Depreciation
|
17,856
|
4,216
|
8
|
—
|
22,080
|
||||||||||||||
|
Operating income (loss)
|
32,430
|
17,985
|
(1,329)
|
—
|
49,086
|
||||||||||||||
|
Interest expense
|
(13,230
|
)
|
(3,229
|
)
|
(898
|
)
|
—
|
(17,357
|
)
|
||||||||||
|
Other income (loss)
|
1,341
|
(61)
|
27
|
—
|
1,307
|
||||||||||||||
|
Income tax expense
|
(1,426
|
)
|
(4,029
|
)
|
(1,972
|
)
|
—
|
(7,427
|
)
|
||||||||||
|
Net income (loss)
|
$
|
19,115
|
$
|
10,666
|
$
|
(4,172
|
)
|
$
|
—
|
$
|
25,609
|
||||||||