Friday, February 27, 2009

Republic Services, Inc. Reports Fourth Quarter Results

PHOENIX, Feb. 26 /PRNewswire-FirstCall/ -- Republic Services, Inc. (NYSE: RSG) today reported a net loss for the three months ended December 31, 2008, of $131.7 million, or $.55 per diluted share, compared to net income of $82.1 million, or $.44 per diluted share, for the same period in 2007. Our 2008 financial results include Allied Waste Industries, Inc. (Allied) from the effective date of the merger which was December 5, 2008. Revenue for the three months ended December 31, 2008 was $1,244.4 million compared to $796.0 million for the same period in 2007.

(Logo: http://www.newscom.com/cgi-bin/prnh/20020531/RSGLOGO )

Operating loss for the three months ended December 31, 2008 was $111.6 million compared to operating income of $139.9 million for the same period last year. During the three months ended December 31, 2008, we recorded charges totaling $315.5 million for remediation and related costs, asset impairments, restructuring, landfill and intangible asset amortization expense, bad debt expense, legal settlement reserves and the synergy incentive plan.

For the year ended December 31, 2008, net income was $73.8 million, or $.37 per diluted share, compared to $290.2 million, or $1.51 per diluted share, for 2007. Revenue for the year ended December 31, 2008 was $3,685.1 million compared to $3,176.2 million during 2007.

Operating income for the year ended December 31, 2008 was $283.2 million compared to $536.0 million for 2007. During the year ended December 31, 2008, we recorded charges totaling $383.5 million for remediation and related costs, asset impairments, restructuring, landfill and intangible asset amortization expense, bad debt expense, legal settlement reserves and the synergy incentive plan.

"I am very pleased with our progress to date concerning the integration of Republic and Allied following the merger that took place on December 5, 2008," said James E. O'Connor, Chairman and Chief Executive Officer of Republic Services. "We have already completed initiatives that provide an annual benefit of more than $50.0 million in synergies. I remain confident that we will achieve the estimated $150.0 million in annual run-rate savings by the end of 2010."

Quarterly Dividend Declared

We also announced that our Board of Directors declared a regular quarterly dividend of $.19 per share for stockholders of record on April 1, 2009. The dividend will be paid on April 15, 2009.

Fiscal Year 2009 Outlook

"Despite a weaker economy, we expect 2009 free cash flow, excluding merger-related payments, to be approximately $650.0 million, which compares favorably to 2008," said Donald W. Slager, President and Chief Operating Officer. "Our field organization is adjusting the business for changing economic conditions while remaining focused on the basic aspects of our business including safety, customer service, pricing, and achieving strong and predictable free cash flow."

Our objectives for 2009 remain consistent with previous years and once again focus on enhancing shareholder value through the generation and efficient use of free cash flow. We remain committed to implementing a broad- based pricing initiative across all lines of business to recover increasing costs and provide an adequate return on invested capital. We anticipate using free cash flow to pay regular quarterly dividends and reduce debt. Additionally, we expect to use proceeds from sales of asset divestitures to reduce debt.

Our guidance is based on current economic conditions and does not assume any improvement or deterioration in the overall economy in 2009 from that experienced at the end of 2008.

    Specific guidance is as follows:

    -- Free Cash Flow: We anticipate 2009 free cash flow, excluding merger-
       related payments, of approximately $650.0 million.  We define free cash
       flow as cash provided by operating activities less purchases of
       property and equipment plus proceeds from sales of property and
       equipment as presented in our consolidated statement of cash flows.
       Additionally, we expect to realize proceeds from sales of asset
       divestitures which are not included in free cash flow.

    -- Earnings Per Share:  We anticipate reported 2009 earnings per diluted
       share before the accounting impact of our merger with Allied and
       restructuring charges to be in the range of $1.70 to $1.75 per share.
       Reported earnings per diluted share are expected to be in the range of
       $1.10 to $1.15 per share.  As of the effective date of the merger,
       Republic recorded significant changes in the carrying values of
       Allied's assets, liabilities and debt, as a result of assigning fair
       values in purchase accounting.  Republic also conformed Allied's
       accounting policies to Republic's.  Taken together, we estimate that
       the impact of these changes will have the effect of lowering 2009
       earnings by approximately $.60 per diluted share.  This decrease in
       2009 earnings consists of the following (approximately):

       -- $.17 per diluted share is attributable to higher depreciation,
          depletion and amortization,

       -- $.18 per diluted share is attributable to non-cash interest expense
          for amortizing the discount to fair value on Allied's debt,

       -- $.05 per diluted share is for conforming Allied's accounting
          policies with ours, and

       -- $.20 per diluted share is related to the
          integration of our businesses.

    -- Revenue:  We expect 2009 revenue to increase by approximately 129
       percent.  This reflects increases of approximately 139 percent
       resulting from our merger with Allied and approximately 4 percent for
       price increases, which are partially offset by a decline of
       approximately 14 percent due to weaker economic conditions (but not a
       loss of market share) and divestitures, as shown below:


                                   Increase
                                  (Decrease)
       Price                          4.0 %
       Volume                        (8.0)
       Divestitures                  (1.5)
       Fuel fees                     (2.5)
       Commodities                   (2.0)
          Total change              (10.0)%


    -- Capital Spending:  We anticipate 2009 net capital spending of
       approximately $845.0 million.

    -- Margins:  EBITDA margins for 2009 are anticipated to be approximately
       28%, or approximately 29.5% before costs related to integrating our
       businesses.

    -- Merger Synergies:  In 2009, we anticipate realizing $100.0 million in
       year-end, run-rate synergies as a result of the merger of Republic
       Services and Allied.  Our goal for the merger is $150.0 million in
       annual run-rate synergies by the end of 2010.  The cost to merge our
       systems and business units, and thus achieve the $150.0 million
       synergies, is projected to be approximately $135.0 million, or $.20 per
       diluted share, in 2009, and $55.0 million, or $.08 per diluted share,
       in 2010.

About Republic Services, Inc.

Republic Services, Inc. is a leading provider of services in the domestic, non-hazardous solid waste industry. We provide solid waste collection, transfer, disposal and recycling services for commercial, industrial, municipal and residential customers through 400 collection companies in 40 states and Puerto Rico. We also own or operate 242 transfer stations, 213 solid waste landfills and 78 recycling facilities. Republic serves millions of residential customers under contracts with more than 3,000 municipalities for waste collection and residential services. For more information, visit the Republic Services web site at www.republicservices.com.



                             REPUBLIC SERVICES, INC.
                 UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
                     (in millions, except per share amounts)

                                                 December 31,  December 31,
                                                      2008         2007
    Assets
    Current Assets -
      Cash and cash equivalents                      $68.7         $21.8
      Accounts receivable, net of allowance
       for doubtful accounts of $65.7
       and $14.7, respectively                       945.5         298.2
      Prepaid expenses and other current assets      174.7          68.5
      Deferred tax assets                            136.8          25.3
        Total Current Assets                       1,325.7         413.8
        Restricted cash                              281.9         165.0
    Property and equipment, net                    6,738.2       2,164.3
    Goodwill and other intangible assets, net     11,085.6       1,582.2
    Other assets                                     490.0         142.5
        Total Assets                             $19,921.4      $4,467.8

    Liabilities and Stockholders' Equity
    Current Liabilities -
      Accounts payable, deferred revenue
       and other current liabilities              $2,061.8        $626.4
      Notes payable and current maturities
       of long-term debt                             504.0           2.3
        Total Current Liabilities                  2,565.8         628.7

    Long-term debt, net of current maturities      7,198.5       1,565.5
    Accrued landfill and environmental
     costs, net of current portion                 1,197.1         279.2
    Other long-term liabilities                    1,678.6         690.6
    Commitments and Contingencies
    Stockholders' Equity -
      Preferred stock, par value $.01 per
       share; 50.0 shares authorized;
       none issued                                       -             -
      Common stock, par value $.01 per
       share; 750.0 shares authorized;
       393.4 and 195.7 shares
       issued, including shares
       held in treasury, respectively                  3.9           2.0
      Additional paid-in capital                   6,260.1          38.7
      Retained earnings                            1,477.2       1,572.3
      Treasury stock, at cost (14.9 and
       10.3 shares, respectively)                   (456.7)       (318.3)
      Accumulated other comprehensive
       income (loss), net of tax                      (3.1)          9.1
        Total Stockholders' Equity                 7,281.4       1,303.8
        Total Liabilities and Stockholders'
         Equity                                  $19,921.4      $4,467.8



                             REPUBLIC SERVICES, INC.
              UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF INCOME
                     (in millions, except per share amounts)

                                        Three Months Ended Twelve Months Ended
                                            December 31,       December 31,
                                           2008     2007     2008      2007
    Revenue                              $1,244.4  $796.0  $3,685.1  $3,176.2
    Expenses:
      Cost of operations                    863.2   497.2   2,416.7   2,003.9
      Depreciation, amortization and
       depletion                            127.2    71.6     354.1     305.5
      Accretion                              10.4     4.5      23.9      17.1
      Selling, general and administrative   182.7    82.8     434.7     313.7
      Asset impairments                      89.8     -        89.8       -
      Restructuring charges                  82.7     -        82.7       -
    Operating income (loss)                (111.6)  139.9     283.2     536.0
    Interest expense                        (66.8)  (23.7)   (131.9)    (94.8)
    Interest income                           1.7     3.3       9.6      12.8
    Other income (expense), net              (0.9)   11.5      (1.6)     14.1
    Income (loss) before income taxes      (177.6)  131.0     159.3     468.1
      Provision (benefit) for income taxes  (46.0)   48.9      85.4     177.9
      Minority interests                      0.1     -         0.1       -
        Net income (loss)                 $(131.7)  $82.1      73.8    $290.2

    Basic Earnings Per Share:
      Basic earnings per share             $(0.55)  $0.44     $0.38     $1.53
      Weighted average common shares
        outstanding                         239.1   186.2     196.7     190.1

    Diluted Earnings Per Share:
      Diluted earnings per share           $(0.55)  $0.44     $0.37     $1.51
      Weighted average common and common
        equivalent shares outstanding       239.1   188.2     198.4     192.0

    Cash dividends per common share         $0.19   $0.17     $0.72     $0.55

REPUBLIC SERVICES, INC.

UNAUDITED SUMMARY DATA SHEET - STATEMENT OF OPERATIONS DATA

(in millions, except percentages)

    The following information should be read in conjunction with our audited
    consolidated financial statements and notes thereto appearing in our Form
    10-K as of and for the year ended December 31, 2007.  It should also be
    read in conjunction with our unaudited condensed consolidated financial
    statements and notes thereto appearing in our Form 10-Q as of and for the
    nine months ended September 30, 2008.


                                        Three Months Ended Twelve Months Ended
                                            December 31,       December 31,
                                            2008     2007     2008      2007
    Collection:
      Residential                          $332.6  $203.4    $966.0    $802.1
      Commercial                            398.9   242.6   1,161.4     944.4
      Industrial                            235.1   157.3     711.4     645.6
      Other                                   7.0     4.8      23.2      19.5
        Total collection                    973.6   608.1   2,862.0   2,411.6

    Transfer and disposal                   456.8   293.0   1,343.4   1,192.5
    Less: Intercompany                     (228.3) (150.4)   (683.5)   (612.3)
      Transfer and disposal, net            228.5   142.6     659.9     580.2

    Other                                    42.3    45.3     163.2     184.4

    Total revenue                        $1,244.4  $796.0  $3,685.1  $3,176.2


    The following table reflects our revenue growth for the three and twelve
    months ended December 31, 2008 and 2007:



                                        Three Months Ended Twelve Months Ended
                                            December 31,       December 31,
                                           2008     2007      2008     2007
    Core price                              4.1 %    4.3 %    4.0 %    4.2 %
    Fuel surcharges                         1.1      0.6      1.8      0.2
    Environmental fees                      0.7      -        0.4      0.2
    Commodities                            (1.3)     1.1      0.1      0.9
      Total price                           4.6      6.0      6.3      5.5

    Core volume                            (6.4)    (1.5)    (3.9)    (1.5)
    Non-core volume                        (0.2)     0.2      0.1     (0.1)
      Total volume                         (6.6)    (1.3)    (3.8)    (1.6)

    Total internal growth                  (2.0)     4.7      2.5      3.9

    Acquisitions, net of divestitures      58.0     (0.7)    13.4     (0.5)
    Taxes                                   0.3     (0.1)     0.1       -

    Total revenue growth                   56.3 %    3.9 %   16.0 %    3.4 %


    The increase in our revenue and our revenue growth for the three months
    ended December 31, 2008 is primarily due to our acquisition of
    Allied Waste Industries, Inc. (Allied) on December 5, 2008.



                             REPUBLIC SERVICES, INC.
           UNAUDITED SUMMARY DATA SHEET - STATEMENT OF OPERATIONS DATA
                         (in millions, except as noted)

    SUMMARY OF CHARGES

    We incurred various charges and costs during the three and twelve months
    ended December 31, 2008 and 2007 that are reported within our unaudited
    consolidated statements of income and are reflected in the following
    table:

                                        Three Months Ended Twelve Months Ended
                                            December 31,      December 31,
                                            2008    2007     2008     2007
    Expenses:
      Cost of operations (1)                $87.8   $-      $153.9    $49.1
      Depreciation, amortization and
       depletion (1) (2) (3)                  8.4    -         8.4      3.6
      Selling, general and administrative
       (1) (4) (5) (6)                       46.8    -        48.7      1.5
      Asset impairments (7)                  89.8    -        89.8        -
      Restructuring charges (8)              82.7    -        82.7        -
    Operating loss                         (315.5)   -      (383.5)   (54.2)
    Interest expense (9)                    (10.1)   -       (10.1)       -
    Other income (expense), net (1)            -     -        (1.0)    (0.7)
    Income (Loss) before income taxes     $(325.6)  $-     $(394.6)  $(54.9)


    (1) During the three months ended December 31, 2008, we recorded $65.9
        million and $21.9 million of remediation and related charges
        related to our Countywide disposal facility in Ohio and our closed
        disposal facility in Contra Costa County, California, respectively.
        During the twelve months ended December 31, 2008, we recorded $99.9
        million, $21.9 million and $35.0 million of remediation and related
        charges related to our Countywide facility, our Contra Costa County
        facility and the Sunrise Landfill in Nevada.  Of the $99.9 million
        charge recognized for the Countywide facility, $98.0 million and $1.9
        million were recorded in cost of operations and selling, general and
        administrative expenses, respectively.  The $21.9 million charge for
        our Contra Costa County facility was recorded to cost of operations.
        Of the $35.0 million charge recognized for the Sunrise landfill, $34.0
        million and $1.0 million were recorded in cost of operations and other
        income (expense), respectively.

        During the twelve months ended December 31, 2007, we recorded $45.3
        million of remediation charges for our Countywide disposal facility,
        of which $41.0 million was recorded in cost of operations, $2.1
        million was recorded in depreciation, amortization and depletion, $1.5
        million was recorded in selling, general and administrative expenses,
        and $.7   million was recorded to other income (expense), net. Also
        during the   twelve months ended December 31, 2007, we recorded a $9.6
        million   charge related to our Contra Costa County disposal facility,
        of which   $8.1 million was recorded in cost of operations and $1.5
        million was   recorded in depreciation, amortization and depletion.

    (2) During the three and twelve months ended December 31, 2008, we
        recorded $2.8 million of incremental landfill amortization expense as
        compared to the amortization expense Allied would have recorded for
        the same period.  The increase in the landfill amortization expense is
        the result of conforming Allied's policies for estimating the costs
        and timing for capping, closure and post-closure obligations to
        Republic's.

    (3) During the three and twelve months ended December 31, 2008, we
        recorded $5.6 million of intangible asset amortization expense related
        to the intangible assets we recorded in the purchase price allocation
        for the acquisition of Allied.

    (4) During the three and twelve months ended December 31, 2008, we
        recorded $14.2 million of bad debt expense related to conforming
        Allied's methodology for recording allowance for doubtful accounts
        with our methodology and $5.4 million to provide for specific
        bankruptcy exposures.

    (5) During the three and twelve months ended December 31, 2008, we
        recorded $24.3 million of settlement charges related to our estimates
        of the outcome of various legal matters.

    (6) During the three and twelve months ended December 31, 2008, we
        recorded $2.9 million to accrue for the synergy incentive plan pro
        rata over the periods earned.

    (7) During the three and twelve months ended December 31, 2008, we
        recorded $89.8 million of asset impairment charges, which consist
        primarily of $75.9 million related to our Countywide facility, $6.0
        million related to our former corporate headquarters in Florida and
        $6.1 million related to losses on the expected sales of Department of
        Justice required divestitures as a result of our merger with Allied.

    (8) During the three and twelve months ended December 31, 2008, we
        recorded $82.7 million of restructuring charges primarily related to
        severance and other employee termination and relocation benefits
        attributable to integrating our operations with Allied.

    (9) During the three and twelve months ended December 31, 2008, we
        incurred $10.1 million of non-cash interest expense primarily
        associated with amortizing the discount on the debt we acquired from
        Allied that was recorded at fair value in purchase accounting.


                           REPUBLIC SERVICES, INC.
                  SUPPLEMENTAL UNAUDITED FINANCIAL INFORMATION

MERGER WITH ALLIED

We completed our acquisition of Allied effective December 5, 2008. We issued approximately 195.8 million shares of common stock to Allied stockholders, representing 52% of the outstanding common stock of the combined company on a diluted basis. The total purchase price paid for Allied, including the value of common stock issued, our acquisition of Allied's debt and other costs, totaled approximately $11.5 billion. We have allocated the preliminary purchase price to the assets and liabilities acquired based upon their estimated fair values as of the acquisition date and recorded the resulting goodwill, which represents the excess of purchase price over the net assets acquired, of $9.0 billion. Until we have completed our valuation process for the assets and liabilities acquired, there may be adjustments, which we believe will be relatively small compared to our preliminary estimates of the fair values and the resulting purchase price allocation.

    Our allocation of purchase price included allocating values to intangible
assets other than goodwill.  The purchase price assigned to each of these
intangible assets and the life over which these assets will be amortized is as
follows:



    Other Intangibles:                                Amount    Estimated Life
                                                                    (years)
    Customer relationships                            $420.0         10.0
    Franchise agreements                                60.0          9.0
    Other municipal agreements                          30.0          3.0
    Non-compete agreements                               1.0          2.0
    Tradename                                           30.0          5.0
          Total                                       $541.0

Amortization expense for 2009 arising from the $541.0 million of other intangible assets recorded is expected to be approximately $65.0 million.

The debt we acquired from Allied was recorded at fair value. At the date of the merger, the fair value of Allied's variable rate debt approximated its book value. However, because of the tightening of the credit markets, the fair value of Allied's fixed rate debt was significantly below its book value, which resulted in the recognition of a $624.3 million discount. Non-cash interest expense for 2009 arising from amortizing the discount of Allied's debt is expected to be approximately $90.7 million. This discount will generally be amortized into interest expense over the terms of the related debt instruments. The estimated fair value and discount for each fixed rate debt instrument acquired from Allied is as follows:



    Fixed-Rate Debt:
                                                    Estimated       Discount
                                                    Fair Value
    $350.0 million senior notes due 2010              $332.5          $17.5
    $400.0 million senior notes due 2011               370.0           30.0
    $275.0 million senior notes due 2011               257.1           17.9
    $450.0 million senior notes due 2013               421.9           28.1
    $425.0 million senior notes due 2014               369.8           55.2
    $400.0 million senior notes due 2014               363.0           37.0
    $600.0 million senior notes due 2015               531.0           69.0
    $600.0 million senior notes due 2016               518.0           82.0
    $750.0 million senior notes due 2017               645.0          105.0
    $99.5 million debentures due 2021                   92.8            6.7
    $360.0 million debentures due 2035                 265.9           94.1
    $230.0 million convertible debentures due 2034     201.2           28.8
    Other, maturing 2014 through 2027                  215.3           53.0
       Total                                        $4,583.5         $624.3

In accordance with U.S. generally accepted accounting principles (GAAP), various liabilities acquired from Allied were recorded at their fair values using present value techniques to account for changes in the related liabilities due to the passage of time. The differences between the estimated fair values and the undiscounted values for these liabilities will be amortized into either accretion expense or interest expense, depending on the type of liability recorded, over the expected term of the applicable liability. The estimated fair values, undiscounted values and estimated lives for these liabilities are as follows:



                                   Estimated      Undiscounted    Estimated
                                   Fair Value        Amount      Average Life
                                                                   (years)
    Accrued Capping, Closure, and
     Post-Closure Costs              $813.1        $3,726.0          38.5

    Accrued Environmental
     Remediation                     $208.1          $325.9           5.9

    Self-Insurance Reserves          $172.6          $216.3           3.2



    RECONCILIATION OF CERTAIN NON-GAAP MEASURES

Operating Income before Depreciation, Amortization, Depletion and Accretion


    Operating income before depreciation, amortization, depletion and
accretion, which is not a measure determined in accordance with GAAP, for the
three and twelve months ended December 31, 2008 and 2007 is calculated as
follows:



                                 Three Months Ended       Twelve Months Ended
                                     December 31,             December 31,

                                   2008        2007         2008       2007
    Net income (loss)           $(131.7)      $82.1        $73.8      $290.2
    Provision (benefit) for
     income taxes                 (46.0)       48.9         85.4       177.9


    Minority interests               .1           -           .1           -
    Other (income) expense,
     net                             .9       (11.5)         1.6       (14.1)
    Interest income                (1.7)       (3.3)        (9.6)      (12.8)
    Interest expense               66.8        23.7        131.9        94.8
    Depreciation, amortization
     and depletion                127.2        71.6        354.1       305.5
    Accretion                      10.4         4.5         23.9        17.1
      Operating income before
       depreciation, amortization,
       depletion and accretion    $26.0      $216.0       $661.2      $858.6

We believe that the presentation of operating income before depreciation, amortization, depletion and accretion is useful to investors because it provides important information concerning our operating performance exclusive of certain non-cash costs. Operating income before depreciation, amortization, depletion and accretion demonstrates our ability to execute our financial strategy which includes reinvesting in existing capital assets to ensure a high level of customer service, investing in capital assets to facilitate growth in our customer base and services provided, maintaining our investment grade rating and minimizing debt, paying cash dividends, and maintaining and improving our market position through business optimization. This measure has limitations. Although depreciation, amortization, depletion and accretion are considered operating costs in accordance with GAAP, they represent the allocation of non-cash costs generally associated with long- lived assets acquired or constructed in prior years.

For a discussion of significant items impacting our operating income before depreciation, amortization, depletion and accretion for the periods presented above, see Summary of Charges.

Diluted Earnings per Share

Following is a summary of adjusted diluted earnings per share for the three and twelve months ended December 31, 2008 and 2007:



                                  Three Months Ended   Twelve Months Ended
                                     December 31,         December 31,
                                   2008       2007      2008        2007

    Diluted earnings per share   $(.55)      $.44      $.37         $1.51
    Remediation and related
     charges (1)                    .22         -       .48           .18
    Asset impairments (2)           .23         -       .27             -
    Restructuring charges (3)       .21         -       .25             -
    Landfill amortization
     expense (4)                    .01         -       .01             -
    Intangible amortization
     expense (5)                    .01         -       .02             -
    Bad debt expense (6)            .05         -       .06             -
    Legal settlement reserves (7)   .06         -       .07             -
    Synergy incentive plan (8)      .01         -       .01             -
    Non-cash interest expense (9)   .02         -       .03             -
    Tax impact of non-deductible
     items (10)                     .14         -       .16             -
      Adjusted diluted earnings
       per share                   $.41      $.44     $1.73         $1.69


    (1) Remediation and related charges of $87.8 million during the three
        months ended December 31, 2008 consist primarily of changes to our
        estimates of costs incurred at our Countywide facility in Ohio and our
        closed disposal facility in Contra Costa County, California.
        Remediation and related charges of $156.8 million during the twelve
        months ended December 31, 2008 were attributable to the aforementioned
        disposal facilities as well as the Sunrise Landfill in Nevada.

    (2) During the three and twelve months ended December 31, 2008, asset
        impairments of $89.8 million primarily relate to our Countywide
        facility, our former corporate headquarters in Florida and losses on
        expected sales of Department of Justice required divestitures as a
        result of our merger with Allied.

    (3) During the three and twelve months ended December 31, 2008, we
        incurred restructuring charges of $82.7 million, consisting primarily
        of severance and other employee termination and relocation benefits
        attributable to integrating our operations with Allied.

    (4) During the three and twelve months ended December 31, 2008, we
        recorded $2.8 million of incremental landfill amortization expense as
        compared to the amortization expense Allied would have recorded for
        the same period.  The increase in the landfill amortization expense is
        the result of conforming Allied's policies for estimating the costs
        and timing for capping, closure and post-closure obligations to
        Republic's.

    (5) During the three and twelve months ended December 31, 2008, we
        recorded $5.6 million of intangible asset amortization expense related
        to the intangible assets we recorded in the purchase price allocation
        for the acquisition of Allied.

    (6) During the three and twelve months ended December 31, 2008, we
        recorded bad debt expense of $14.2 million related to conforming
        Allied's methodology for recording the allowance for doubtful accounts
        with our methodology and $5.4 million to provide for specific
        bankruptcy exposures.

    (7) During the three and twelve months ended December 31, 2008, we
        incurred $24.3 million of settlement charges related to our estimates
        of the outcome of various legal matters.

    (8) During the three and twelve months ended December 31, 2008, we
        recorded $2.9 million to accrue for the synergy incentive plan pro
        rata over the periods earned.

    (9) During the three and twelve months ended December 31, 2008, we
        incurred $10.1 million of non-cash interest expense primarily
        with amortizing the discount on the debt we acquired from Allied that
        was recorded at fair value in purchase accounting.

    (10)During the three and twelve months ended December 31, 2008, our
        effective tax rate was impacted by several expenses associated with
        the merger that are not tax deductible.

We believe that the presentation of adjusted diluted earnings per share, which excludes charges for remediation and related costs, asset impairments, restructuring, landfill and intangible asset amortization expense, bad debt expense, legal settlement reserves, the synergy incentive plan, non-cash interest expense and the tax impact of non-deductible items, provides an understanding of operational activities before the financial impact of certain non-operational items and strategic and other decisions made for the long-term benefit of the company. We use this measure, and believe investors will find it helpful, in understanding the ongoing performance of our operations separate from items that have a disproportionate impact on our results for a particular period. Comparable costs have been incurred in prior periods, and similar types of adjustments can reasonably be expected to be recorded in future periods.

Cash Flow

We define free cash flow, which is not a measure determined in accordance with GAAP, as cash provided by operating activities less purchases of property and equipment plus proceeds from sales of property and equipment as presented in our unaudited condensed consolidated statements of cash flows. Our free cash flow for the three and twelve months ended December 31, 2008 and 2007 is calculated as follows (in millions):



                                Three Months Ended       Twelve Months Ended
                                   December 31,             December 31,
                                 2008        2007         2008         2007
    Cash provided by operating
     activities                 $38.0       $190.7       $512.2       $661.3
    Purchases of property and
     equipment                 (122.8)       (76.5)      (386.9)      (292.5)
    Proceeds from sales of
     property and equipment       2.4          1.4          8.2          6.1
       Free cash flow          $(82.4)      $115.6       $133.5       $374.9

Purchases of property and equipment as reflected on our unaudited condensed consolidated statements of cash flows and the free cash flow presented above represent amounts paid during the period for such expenditures. A reconciliation of property and equipment reflected on the unaudited condensed consolidated statements of cash flows to property and equipment received during the period is as follows (in millions):



                                     Three Months Ended    Twelve Months Ended
                                         December 31,            December 31,
                                       2008        2007        2008     2007

    Purchases of property and
     equipment per the unaudited
     condensed consolidated
     statements of cash flows         $122.8       $76.5      $386.9    $292.5
    Adjustments for property and
     equipment received during the
     prior period but paid for
     in the following period, net       11.5        35.5      (14.9)       3.2
      Property and equipment received
       during the current period      $134.3      $112.0     $372.0     $295.7

The adjustments noted above do not affect either our net change in cash and cash equivalents as reflected in our unaudited condensed consolidated statements of cash flows or our free cash flow.

A reconciliation of our projected cash provided by operating activities to the 2009 free cash flow outlook is as follows (in millions):



                                                  2009 Outlook
    Cash provided by operating activities           $1,395.0
    Purchases of property and equipment               (860.0)
    Proceeds from sales of property and equipment       15.0
      Free cash flow                                  $550.0

Free cash flow for 2009 includes approximately $100.0 million of merger- related payments. Excluding these payments, free cash flow for 2009 would be $650.0 million.

We believe that the presentation of free cash flow provides useful information regarding our recurring cash provided by operating activities after expenditures for property and equipment, net of proceeds from sales of property and equipment. It also demonstrates our ability to execute our financial strategy as previously discussed and is a key metric we use to determine compensation. The presentation of free cash flow has material limitations. Free cash flow does not represent our cash flow available for discretionary expenditures because it excludes certain expenditures that are required or that we have committed to such as debt service requirements and dividend payments. Our definition of free cash flow may not be comparable to similarly titled measures presented by other companies.

Capital expenditures include $.6 million and $2.6 million of capitalized interest for the three and twelve months ended December 31, 2008, and $.9 million and $3.0 million of capitalized interest for the three and twelve months ended December 31, 2007.

As of December 31, 2008, accounts receivable was $945.5 million, net of allowance for doubtful accounts of $65.7 million, resulting in days sales outstanding of approximately 40 (or 25 net of deferred revenue).

SHARE REPURCHASE PROGRAM AND DEBT REPAYMENT

During 2008, we repurchased a total of 4.6 million shares of our common stock for $138.4 million. As of December 31, 2008, we were authorized to repurchase up to an additional $248.0 million of common stock under our existing stock repurchase program. We suspended the share repurchase program due to the merger with Allied. During 2009, we intend to use free cash flow to repay debt and to continue paying dividends.

CASH DIVIDENDS

In October 2008, we paid a cash dividend of $34.7 million to stockholders of record as of October 1, 2008. As of December 31, 2008, we recorded a dividend payable of $72.0 million to stockholders of record at the close of business on January 2, 2009, which has been paid. In February 2009, our Board of Directors declared a regular quarterly dividend of $.19 per share payable to stockholders of record as of April 1, 2009, which will be paid on April 15, 2009.

Information Regarding Forward-Looking Statements

Certain statements and information included herein constitute "forward- looking statements" within the meaning of the Federal Private Securities Litigation Reform Act of 1995, including statements with respect to the expected results of the integration of our merger with Allied and our anticipated 2009 financial results. Words such as "will", "expect," "anticipate" and similar words and phrases are used in this press release to identify the forward-looking statements. These forward-looking statements, although based on assumptions that we consider reasonable, are subject to risks and uncertainties which could cause actual results, events or conditions to differ materially from those expressed or implied by the forward-looking statements. Although we believe that the expectations reflected in the forward-looking statements are reasonable, we can give no assurance that the expectations will prove to be correct. Among the factors that could cause actual results to differ materially from the expectations expressed in the forward-looking statements are:

    -- whether our estimates and assumptions concerning our selected balance
       sheet accounts, income tax accounts, final capping, closure, post-
       closure and remediation costs, available airspace, and projected costs
       and expenses related to our landfills and property and equipment
       (including our estimates of the fair values of the assets and
       liabilities acquired in our acquisition of Allied), and labor, fuel
       rates, and economic and inflationary trends, turn out to be correct or
       appropriate;

    -- various factors that will impact our actual business and financial
       performance such as competition and demand for services in the solid
       waste industry;

    -- our ability to manage growth;

    -- our ability to successfully integrate Allied's and Republic's
       operations and to achieve synergies or create long-term value for
       stockholders as expected;

    -- our compliance with, and future changes in, environmental regulations;

    -- our ability to obtain approvals from regulatory agencies in connection
       with operating and expanding our landfills;

    -- our ability to obtain financing on acceptable terms to finance our
       operations and growth strategy and to operate within the limitations
       imposed by financing arrangements;

    -- our dependence on key personnel;

    -- general economic and market conditions including, but not limited to,
       the current global economic crisis, inflation and changes in commodity
       pricing, fuel, labor, risk and health insurance, and other variable
       costs that are generally not within our control;

    -- our dependence on large, long-term collection, transfer and disposal
       contracts;

    -- our dependence on acquisitions for growth;

    -- risks associated with undisclosed liabilities of acquired businesses;

    -- risks associated with pending and any future legal proceedings;

    -- severe weather conditions, which could impair our financial results by
       causing increased costs, loss of revenue, reduced operational
       efficiency or disruptions to our operations;

    -- compliance with existing and future legal and regulatory requirements,
       including limitations or bans on disposal of certain types of wastes or
       on the transportation of waste, which could limit our ability to
       conduct or grow our business, increase our costs to operate or require
       additional capital expenditures;

    -- any litigation, audits or investigations brought by or before any
       governmental body;

    -- workforce factors, including potential increases in our costs if we are
       required to provide additional funding to any multi-employer pension
       plan to which we contribute and the negative impact on our operations
       of union organizing campaigns, work stoppages or labor shortages;

    -- the negative effect that trends toward requiring recycling, waste
       reduction at the source and prohibiting the disposal of certain types
       of wastes could have on volumes of waste going to landfills and waste-
       to-energy facilities;

    -- changes by the Financial Accounting Standards Board or other accounting
       regulatory bodies to generally accepted accounting principles or
       policies;

    -- acts of war, riots or terrorism, including the events taking place in
       the Middle East, the current military action in Iraq and the continuing
       war on terrorism, as well as actions taken or to be taken by the United
       States or other governments as a result of further acts or threats of
       terrorism, and the impact of these acts on economic, financial and
       social conditions in the United States; and

    -- the timing and occurrence (or non-occurrence) of transactions and
       events which may be subject to circumstances beyond our control.

Other factors which could materially affect our forward-looking statements can be found in our periodic reports filed with the Securities and Exchange Commission. Stockholders, potential investors and other readers are urged to consider these factors carefully in evaluating our forward-looking statements and are cautioned not to place undue reliance on forward-looking statements. The forward-looking statements made herein are only made as of the date of this press release, and we undertake no obligation to publicly update these forward-looking statements to reflect subsequent events or circumstances.

[Via http://www.prnewswire.com]

Austral Amends Loan Facility

WELLINGTON, New Zealand, Feb. 26 /PRNewswire-FirstCall/ -- Austral Pacific Energy Ltd. (TSX-V: APX; NZSX: APX)

Austral Pacific Energy Ltd. announces that it has agreed with its loan facility provider, Investec Bank (Australia) Ltd, to further extend the maturity date for the current facility to enable the Bank and Austral to finalise the details of a fundamental restructure of the company and further restructuring of the loan facility.

    Web site:    www.austral-pacific.com
    Email:       ir@austral-pacific.com
    Phone:       Thom Jewell, CEO +64 (4) 495 0880

None of the Exchanges upon which Austral Pacific's securities trade have approved or disapproved the contents hereof. This release includes certain statements that may be deemed to be "forward-looking statements" within the meaning of applicable legislation. Other than statements of historical fact, all statements in this release addressing future production, reserve potential, exploration and development activities and other contingencies are forward-looking statements. Although management believes the expectations expressed in such forward-looking statements are based on reasonable assumptions, such statements are not guarantees of future performance, and actual results or developments may differ materially from those in the forward-looking statements, due to factors such as market prices, exploration and development successes, continued availability of capital and financing, and general economic, market, political or business conditions. See our public filings at www.sedar.com and www.sec.gov/edgar/searchedgar/webusers.htm for further information.

[Via http://www.prnewswire.com]

Thursday, February 26, 2009

CanAlaska Uranium Ltd. - Further drill results from uranium zone at Fond du Lac project

VANCOUVER, Feb. 26 /PRNewswire-FirstCall/ - CanAlaska Uranium Ltd. (TSX.V - CVV) ("CanAlaska" or the "Company") has received additional assay results for holes FCL 004-FCL 006 and for infill sampling on holes FCL 001-003. These results for the uranium-mineralized sections of the first six drill holes from CanAlaska's work are detailed in the following table, and indicate good widths and grades of uranium mineralization.

    Table 1: Summary of Initial drill results Fond du Lac Project
    -------------------------------------------------------------------------
    Hole        Rock      From (m)  To (m)  Width (m)    Grade       Lbs/Ton
    Number                                            (% U(3)O(8))  U(3)O(8)
    -------------------------------------------------------------------------
    FCL 002   Sandstone     16.8     42.10    25.30       0.10%        2.0
    -------------------------------------------------------------------------
                incl        17.2     24.85     7.65       0.13%        2.6
    -------------------------------------------------------------------------
    FCL 003   Sandstone    18.10     44.61    26.51       0.15%        3.0
    -------------------------------------------------------------------------
    FCL 004   Sandstone    15.50     17.50     2.00       0.10%        2.0
    -------------------------------------------------------------------------
                 and       36.00     42.80      6.8       0.07%        1.4
    -------------------------------------------------------------------------
    FCL 005   Sandstone    16.00     22.50     6.50       0.07%        1.4
    -------------------------------------------------------------------------
    FCL 006   Sandstone     16.0     30.30    14.30       0.14%        2.8
    -------------------------------------------------------------------------

The Fond du Lac project is located on the northern portion of the Athabasca Basin, Saskatchewan, where the Athabasca sandstone units have minimal thicknesses of 20-75 metres overlying the unconformity. This area was explored by AMOK in the 1960's and AMOK and Eldorado Nuclear in the 1970's and early 1980's. The property is part of the Fond Du Lac Denesuline First Nation Reserve Lands, and CanAlaska is working with the community under an Option to earn a 49% interest in the project.

A small uranium resource (non 43-101compliant) was previously discovered in the sandstone units, immediately above the unconformity, but no significant effort was made to explore for structurally hosted uranium mineralization in the basement rock at that time. However there is historical evidence for basement hosted mineralization in hematised fault zones.

The 2008 drilling and detailed ground geophysics by CanAlaska in January and February 2009 have highlighted a number of strong structural events in the basement rocks. There are patterns of sulphide mineralization and gravity anomalies. The company is preparing for a summer drill program on the property, following the completion of the Company's current four-rig winter drill program.

The uranium mineralization at Fond du Lac is principally within the Manitou Falls Formation of the Athabasca Sandstone sequence, and is characterized by strong fracturing, intense silicification, zones of hematisation and minor clay alteration. In the current area of 2008 drilling, zoning is apparent, with a central highly mineralized-core. The mineralization is evident as disseminations and replacement, both in the sandstone and near the surface (see following plan and drill section).

http://www.canalaska.com/i/maps/2009-02-25FLCFigure1_hres.jpg

http://www.canalaska.com/i/maps/2009-02-25FLCFigure2.pdf

Across the project, there are multiple other zones, currently only loosely-defined by mineralized boulder trains (see attached figure 1 for mineralized boulder trains and geophysical responses).

In the current drilling, a very significant zone of hematite alteration was intersected in basement rocks at the unconformity, under the better-mineralized uranium zone in the drill holes FCL 001-003. This style of iron oxide mineralization is generally caused by oxidization from geothermal activity along fracture zones, and is a common indicator for most basement-hosted uranium deposits. Drill hole FCL 001 intercepted anomalous uranium mineralization in sandstone. Drill hole FCL 004 intercepted two zones of replacement mineralization on the southern edge of the main zone. Holes FCL 005 and FCL 006 intercepted uranium mineralization in the sandstone and strong clay hematite and chlorite alteration, in the basement rocks. Further drilling along strike will be required to define the extent and orientation of the present zone.

http://www.canalaska.com/i/maps/2009-02-25FLCFigure3.pdf

The Company received a work permit for the drilling at Fond du Lac from INAC (Indian and Northern Affairs Canada), with consent from the band and council of the Fond du Lac Denesuline First Nation. This permit allowed the Company to commence exploration on the Reserve lands. By agreement dated October 18th, 2006, the Company acquired from the Fond du Lac Denesuline First Nation an option to earn a 49% economic interest in the minerals resident on Fond du Lac reserve lands. CanAlaska may exercise this option following the incurrence of $2 million in exploration expenditures and the payment of $130,000 and 300,000 Company shares.

Elsewhere in the Athabasca Basin, CanAlaska has two drill crews working at the Cree East Project, located in the southwestern part of the Athabasca basin. A third drill crew is operating at the West McArthur project, on a new geophysical target located north west of Denison's Wheeler River project, and south west of the McArthur River mine.

The Company has just mobilized a fourth crew for a month-long drill program on the Black Lake Project, on the Black Lake Denesuline First Nation Reserve. This drill program will replace the proposed winter program at Fond du Lac, but will test higher priority strong airborne and ground truthed geophysical conductors on the splays of the Black Lake-Platt Lake Faults, on the northern end of the Virgin River mineralized trend. There are multiple targets at shallow depths in this area. These targets have been confirmed by summer boulder sampling and historical mineralized drill core from the vicinity. Drill holes will target both sandstone hosted alteration and basement mineralization in this program.

The Company is very pleased with current operations, and is fully-funded for the summer-fall work programs through its joint venture partnerships and from current treasury.

All of the drill core samples from the Fond du Lac project were submitted to Acme Laboratories Vancouver, an ISO 9001:2000 accredited and qualified Canadian Laboratory, for their Group 4B analysis. These samples were analysed for uranium and multi-element geochemistry by tri-acid digestion and ICP-MS. The samples were collected by CanAlaska field geologists under the supervision of Dr. Karl Schimann, and were shipped in secure containment to the laboratories noted above. Peter Dasler, M.Sc. P Geo. is the qualified technical person responsible for this news release.

About CanAlaska Uranium Ltd. -- www.canalaska.com

CANALASKA URANIUM LTD. (CVV -- TSX.V, CVVUF -- OTCBB, DH7 -- Frankfurt) is undertaking uranium exploration in nineteen 100%-owned and two optioned uranium projects in Canada'sAthabasca Basin. Since September 2004, the Company has aggressively acquired one of the largest land positions in the region, comprising over 2,500,000 acres (10,117 sq. km or 3,906 sq. miles). To-date, CanAlaska has expended over Cdn$45 million exploring its properties and has delineated multiple uranium targets. The Company's geological expertise and high exploration profile has attracted the attention of major international strategic partners. Among others, Mitsubishi Development Pty., a subsidiary of Japanese conglomerate Mitsubishi Corporation, has undertaken to provide CanAlaska C$11 mil. in exploration funding for its West McArthur Project. Exploration of CanAlaska's Cree East Project is also progressing under a C$19 mil. joint venture with a consortium of Korean companies led by Hanwha Corporation, and comprising Korea Electric Power Corp., Korea Resources Corp. and SK Energy Co, Ltd.

    On behalf of the Board of Directors

    (signed)

    Peter Dasler, M.Sc., P.Geo.
    President & CEO, CanAlaska Uranium Ltd.

The TSX Venture has not reviewed and does not accept responsibility for the adequacy or accuracy of this release: CUSIP # 13708P 10 2. This news release contains certain "Forward-Looking Statements" within the meaning of Section 21E of the United States Securities Exchange Act of 1934, as amended. All statements, other than statements of historical fact, included herein are forward-looking statements that involve various risks and uncertainties. There can be no assurance that such statements will prove to be accurate, and actual results and future events could differ materially from those anticipated in such statements. Important factors that could cause actual results to differ materially from the Company's expectations are disclosed in the Company's documents filed from time to time with the British Columbia Securities Commission and the United States Securities & Exchange Commission.

[Via http://www.prnewswire.com]

Continental Resources Ends 2008 With Strong Production and Reserve Growth

2009 Capital Expenditure Budget Reduced in Line with Cash Flow Outlook

ENID, Okla., Feb. 26 /PRNewswire-FirstCall/ -- Continental Resources, Inc. (NYSE: CLR) today reported continued strong growth in production in the fourth quarter ended December 31, 2008, compared with the third quarter of 2008 and the fourth quarter last year. In addition, the Company reported year-end 2008 proved reserves of 159.3 MMboe, an 18 percent increase over the 134.6 MMboe reported at year-end 2007. Combined drilling and proved undeveloped (PUDs) additions of 47.6 MMboe were almost 400 percent of Continental's total production of 12.0 MMboe for 2008.

(Logo: http://www.newscom.com/cgi-bin/prnh/20080505/LAM014LOGO)

Despite challenging economics in the final quarter of 2008, Continental completed a record year for net income and cash flow growth. Net income increased 74 percent to $321.0 million and EBITDAX increased 61 percent to $757.7 million, compared with full-year 2007 results. For the Company's definition and reconciliation of EBITDAX to Generally Accepted Accounting Principles, see "Non-GAAP Financial Measures" at the end of this press release. Net income for 2007 is pro forma for income taxes as if the Company had been a subchapter C corporation prior to its initial public offering in May 2007.

For the fourth quarter ended December 31, 2008, the Company reported net income of $416,000, or $0.00 per diluted share, compared with net income of $60.9 million, or $0.36 per diluted share, for the fourth quarter of 2007. Falling commodity prices reduced fourth quarter revenue and earnings compared to the fourth quarter of 2007.

For the fourth quarter of 2008, Continental achieved total production of 36,018 boepd, an eight percent increase over the third quarter of 2008 and a 19 percent increase over the fourth quarter last year. The Company exited the fourth quarter with average production of 37,954 boepd for December 2008, an increase of 27 percent over December 2007. Production growth strengthened despite the Company significantly scaling back its drilling program as commodity prices declined in the fourth quarter of 2008. Continental has reduced its operated drilling rig count from 32 in early October to seven rigs currently and plans to drop additional rigs as drilling contracts expire later in 2009.

With energy prices remaining low, Continental plans to reduce capital expenditures to preserve capital and the value of its assets. "Our first priority is the integrity of our balance sheet," said Harold Hamm, Chairman and Chief Executive Officer. "We plan to restrain spending until we see commodity prices begin to recover. We remain committed to financing our growth with cash flow and will not use debt to fund a high level of drilling activity, especially in an environment of low energy prices."

"I'm proud that we achieved our operating goals for 2008, finishing the year with strong fourth quarter production growth and increased reserves," he said. "The Company's accomplishments are a strong indicator of the value of our assets and our ability to accelerate growth when the economy and industry conditions rebound."

The Company has revised its 2009 capital expenditures budget to $275 million, which includes $211 million for drilling and related activities and $58 million for land and seismic, and $6 million for other capital needs. Based on the new budget, 2009 production is expected to be in a range of 12.5 MMboe to 13.0 MMboe, which would constitute growth of up to eight percent over 2008. Under this revised capex budget, Continental expects to average approximately five operated drilling rigs during the year.

Oil and natural gas sales were $130.7 million for the fourth quarter of 2008, compared with oil and gas sales of $183.8 million for the fourth quarter of 2007. The Company's average sales price per barrel of crude oil equivalent was $38.80 for the fourth quarter of 2008, compared with $68.84 for the fourth quarter of 2007.

Crude oil price differentials averaged $14.45 per barrel for the fourth quarter of 2008 and $9.50 for 2008 as a whole. This compares with $13.05 per barrel in the fourth quarter of 2007 and $8.85 per barrel for the full year. Continental noted that the differential has been improving in the first quarter of 2009.

EBITDAX for the fourth quarter of 2008 was $92.7 million, compared with EBITDAX of $137.4 million for the fourth quarter of 2007.

At December 31, 2008, the Company's balance sheet included $5.2 million in cash and $376.4 million in long-term debt. Commitments under the Company's revolving credit facility were recently increased to $672.5 million, compared with $552.5 million at December 31, 2008 and $400.0 million at September 30, 2008. With debt outstanding currently of $474.4 million, the Company has $198.1 million in availability under its revolving credit facility.

Increased Reserves

Continental's 2008 reserves growth was primarily the result of increased drilling activity in the North Dakota Bakken and in Oklahoma's Arkoma Woodford in the first nine months of the year.

The Company increased its proved reserves by 24.6 MMboe to a total of 159.3 MMboe. Total proved reserve additions were comprised of 12.7 MMboe in drilling additions, 35.0 MMboe of PUD reserve additions, and 2.2 MMboe in acquisitions. Additions were offset by 13.3 MMboe in downward revisions, of which 64 percent were related to low energy prices at year-end 2008.

Future net cash flows from the year-end 2008 proved reserves, before income taxes, were $3.1 billion, with a present value discounted at 10 percent (PV10) of $1.5 billion. In terms of crude oil/natural gas mix, crude oil reserves were 106.2 million barrels, or 67 percent, of total proved reserves at year-end 2008. Proved developed reserves represented 67 percent of total reserves at year-end 2008.

Operations Update

The following table contains financial and operating highlights for the three months and year ended December 31, 2008 compared to the same periods in 2007.


                                    Three months ended       Year ended
                                    ------------------       ----------
                                       December 31,          December 31,
                                       ------------          ------------
                                     2008       2007       2008       2007
                                    ------     ------     ------     ------
    Average daily production:
      Oil (Bopd)                    26,857     24,309     24,993     23,832
      Natural gas (Mcfd)            54,963     36,362     46,861     31,599
      Oil equivalents (Boepd)       36,018     30,369     32,803     29,099
    Average prices: (1)
      Oil ($/Bbl)                   $43.89     $77.53     $88.87     $63.55
      Natural gas ($/Mcf)             3.93       5.99       6.90       5.87
      Oil equivalents ($/Boe)        38.80      68.84      77.66      58.31
    Production expense ($/Boe) (1)    7.83       6.85       8.40       7.35
    EBITDAX (in thousands)          92,680    137,412    757,708    469,885
    Net income (in thousands) (2)      416     60,892    320,950    184,002
    Diluted net income per share      0.00       0.36       1.89       1.11

    (1) Average prices and per-unit production expense are calculated
    based on sales volumes. Crude oil sales volumes exceeded production in
    the fourth quarter and full-year 2008 by 54 MBbls and 97 MBbls,
    respectively. Crude oil production volumes exceeded oil sales in the
    fourth quarter and full year 2007 by 125 MBbls and 221 MBbls,
    respectively.

    (2) Net income and diluted net income per share for full-year 2007
    are after pro forma adjustments (i) to provide for income taxes as if
    the Company had been a subchapter C corporation prior to the completion
    of its initial public offering, and (ii) to eliminate the $198.4 million
    charge recorded to recognize deferred taxes upon its conversion from a
    nontaxable subchapter S corporation to a taxable subchapter C
    corporation in conjunction with the Company's May 2007 initial public
    offering.



    The following table presents average daily production for the Company's
    principal operating areas for the quarters ended December 31, 2008,
    September 30, 2008 and December 31, 2007.


    (boe per day)                    Q4 2008      Q3 2008      Q4 2007
                                     -------      -------      -------
    Red River Units                   14,058       13,375       14,374
    Montana Bakken                     6,410        6,187        7,244
    North Dakota Bakken                4,401        3,444        1,382
    Other Rockies                      2,507        2,275        1,600
    Arkoma Woodford                    3,276        2,627        1,338
    Other Mid-Continent                4,751        4,895        3,767
    Gulf Coast                           615          494          664
                                     -------      -------      -------
    Total                             36,018       33,297       30,369

Production growth continued to accelerate in the North Dakota Bakken and the Arkoma Woodford plays in the fourth quarter of 2008. Based on capital expenditure re-allocations and its revised 2009 budget, production in the Red River Units is expected to be flat or to decline slightly through the first nine months of 2009, then resume growing in the fourth quarter. Continental expects to generate most of its 2009 production growth in the North Dakota Bakken and the Arkoma Woodford plays.

Red River Units

Production in the Red River Units was 14,058 boepd in the fourth quarter of 2008, accounting for 39 percent of Continental's production in the quarter. This was a five percent increase over the third quarter of 2008, but down slightly from the fourth quarter last year.

The Units accounted for 37 percent of year-end 2008 proved reserves, compared with 50 percent of reserves at the end of 2007.

During fourth quarter 2008, the Company continued to convert producer wells to injectors and to expand its secondary recovery program, but the pace of the secondary recovery program was considerably reduced in November and December.

The Company currently has one operated rig drilling in the Units. Under the revised 2009 capital expenditures budget, Continental has allocated $46 million to the Units, with plans to drill four producer wells, two disposal wells, a sixth water supply well, and converting producer and air injector wells to water injectors.

As noted above, production is expected to resume growing in the Red River Units in late 2009. The Company does not expect changes in the timing of capex funding to reduce total production or ultimate reserve recovery in the Units. The Company expects production to peak at just over 17,000 boepd in the Units in 2010.

Bakken Shale

Production in the Bakken Shale of North Dakota and Montana was 10,811 boepd in the fourth quarter of 2008, or 30 percent of Continental's production in the quarter. This was a 12 percent increase over the third quarter of 2008 and a 25 percent increase over production for the fourth quarter last year.

Total proved reserves in the Bakken were 45.7 MMboe at December 31, 2008, or 29 percent of the Company's year-end 2008 reserves. This constituted an increase of 38 percent over proved reserves of 33.2 MMboe in the Bakken Shale at December 31, 2007.

In the North Dakota part of the Bakken play, total proved reserves were 17.5 MMboe at December 31, 2008, or 11 percent of the Company's total year-end 2008 reserves. This represented growth of 187 percent over reserves of 6.1 MMboe in the North Dakota Bakken at December 31, 2007.

The Company currently has four operated rigs drilling in North Dakota and none in Montana, compared with 10 rigs in North Dakota and three in Montana at the beginning of the fourth quarter of 2008.

During the fourth quarter, Continental participated in the completion of 33 gross wells (8.9 net) in North Dakota. These wells had an average rate of 546 boepd during their seven-day production period tests. All initial production period test results in this press release are seven consecutive day averages.

Since the beginning of the fourth quarter of 2008, notable completions of Company-operated wells targeting the Three Forks/Sanish (TFS) formation in North Dakota are shown below with average production period test results in gross barrels:

    -- Morris 1-23H (29% WI) in Dunn Co. - 1,185 boepd;
    -- Blegen 1-13H (26% WI) in McKenzie Co. - 1,028 boepd;
    -- Mittelstadt 1-20H (44% WI) in Dunn Co. - 998 boepd;
    -- Skachenko 1-31H (34% WI) in Dunn Co. - 809 boepd;
    -- Hamlet 1-11H (39% WI) in Williams Co. - 450 boepd;
    -- Glasoe 1-18H (45% WI) in Divide Co. - 441 boepd;
    -- Arvid 1-34H (42% WI) in Divide Co. - 340 boepd;
    -- Elveida 1-33H (46% WI) in Divide Co. - 302 boepd.

Notable recent well completions in North Dakota targeting the Middle Bakken formation include:

    -- Malcolm 1-29H (45% WI) in Williams Co. - 693 boepd;
    -- Shonna 1-15H (44% WI) in Divide Co. - 436 boepd;
    -- Marlene 1-10H (53% WI) in Williams Co. - 427 boepd;
    -- Viola 1-7H (54% WI) in Divide Co. - 391 boepd.

In the Montana Bakken, the Company continued to implement its 320-acre infield and field-extension program in the fourth quarter of 2008.

Notable completions in Richland County, MT in the fourth quarter of 2008 included the Prevost 3-16H (83% WI), which had a production period test rate of 507 boepd, and the Rita 3-19H (79% WI), which had production period test rate of 412 boepd. Production results have continued to improve in Richland County as the Company implemented multi-stage fracture stimulation technology that it developed in North Dakota.

Continental recently completed its first Montana TFS test well, the Joann 1-32H (89% WI), in Richland County. The well exhibited poor oil shows and reservoir rock quality during drilling, and in its initial production test period yielded an average 60 boepd.

The Company has commenced a pilot carbon dioxide injection project to evaluate the potential for enhanced recovery of oil in the Elm Coulee field. Utilizing the huff-and-puff technique, carbon dioxide was injected in January and will continue to be injected through March. After letting the carbon dioxide soak in for approximately 30 days, the carbon dioxide and associated fluids will be flowed back and analyzed for performance and economics.

Under its revised 2009 capital expenditures budget, Continental has allocated $72 million to drilling-related activity in North Dakota and $7 million to Montana. Another $36 million in land and seismic capex was allocated for the Bakken play in the two states, primarily to extend leases in the play.

Continental plans to participate in 86 gross wells (20.2 net) in North Dakota and no new wells in Montana in 2009. Drilling activity in North Dakota will focus on the Three Forks/Sanish formation.

Arkoma Woodford

Production in the Arkoma Woodford shale play in southeast Oklahoma was 3,276 boepd in the fourth quarter of 2008, accounting for 9 percent of Continental's production in the period. This was a 25 percent increase over the third quarter of 2008, and was more than double production for the fourth quarter last year.

Total proved reserves in the Arkoma Woodford were 30.7 MMboe at December 31, 2008, or 19 percent of the Company's year-end 2008 reserves. This represented growth of 245 percent over reserves of 8.9 MMboe in the Arkoma Woodford at December 31, 2007.

During the fourth quarter of 2008, Continental continued to develop its simultaneous fracture stimulation technology in the Arkoma Woodford, most notably with the Pasquali, Luna-Pratt and Wilson simul-fracs in the Ashland development section of the play.

After the simul-frac, the seven Pasquali wells flowed at an average 2,440 Mcfpd during their production period test, with the most prolific well flowing at 3,599 Mcfpd. The six Luna-Pratt wells flowed at an average 3,761 Mcfpd, with the most prolific flowing at 4,576 Mcfpd. The two wells in the Wilson simul-frac flowed at 8,569 Mcfpd and 5,982 Mcfpd, for an average rate of 7,276 Mcfpd.

The Company currently has one operated rig drilling in the Arkoma Woodford, compared to six rigs at the beginning of the fourth quarter of 2008. Under its revised 2009 capital expenditures budget, Continental has allocated $56 million to drilling-related activity in the play, as well as $7 million in land and seismic capex. In 2009, the Company plans to participate in 63 gross wells (8.0 net) in the Arkoma Woodford.

Emerging Plays

In the Anadarko Woodford shale of western Oklahoma, Continental is currently completing two test wells, the Brown 1-2H (100% WI) in Dewey Co. and the McCalla 1-11H (90% WI) in Grady Co.

In Ellis County, OK, the Company completed its initial test well in the Atoka shale play, the Shrewder 1-22H (100% WI), which flowed at 1.3 MMcfpd from a short, 1,300-foot lateral. The Jones-Trust 1-168H (100% WI), completed in Lipscomb Co., TX in the western part of the play, flowed at 700 Mcf per day in its initial production period test.

The Company currently has no operated rig drillings in the Anadarko Woodford or the Atoka, compared to one in each play at the beginning of the fourth quarter of 2008. Under its revised 2009 capital expenditures budget, Continental has allocated $12 million to drilling-related activity in its emerging plays, as well as $6 million in land and seismic. In 2009, the Company plans to participate in six gross wells (1.8 net) in its emerging plays.

Capital Budget and Guidance

Continental's regional allocations of capital expenditures in 2009 are listed below. Operational capex includes drilling, work-over and facilities capital expenditures.


                                     2009 Capex Budget
                                     -----------------
                                         (in millions)       Net Wells
                                     -----------------       ---------
    North Dakota Bakken                            $72            20.2
    Arkoma Woodford                                 56             8.0
    Red River Units                                 46             3.8
    Emerging plays                                  12             1.8
    Montana Bakken                                   7             0.0
    Other                                           18             3.9
                                     -----------------       ---------
          Operational capex                        211            37.7

    Land and seismic                                58
    Other capital expenditures                       6
                                     -----------------       ---------
          Total capex                             $275

Continental announced its previously issued operating and financial guidance for 2009 has been revised and is as follows. As forward-looking information, this guidance is subject to a variety of risks and uncertainties, including adjustments related to fluctuations in commodity prices. Risk factors are discussed further at the end of this press release and in the Company's filings with the Securities and Exchange Commission.


                                                           Year Ended
                                                       December 31, 2009
                                                        -----------------
    Production volumes:
      Oil (MMbls)                                             8.8 - 9.1
      Gas (MMcf)                                             22.5 - 23.4
      Oil equivalent (MMboe)                                 12.5 - 13.0

    Price differentials(1) :
      Oil (Bbl)                                             $8.00 - $10.00
      Gas (Mcf)                                             $1.50 - $2.25

    Operating expenses:
      Production expense (per boe)                          $7.75 - $8.50
      Production tax (percent of sales)                     6.25% - 6.75%
      Depreciation, depletion, amortization and
       accretion (per boe)                                 $15.00 - $18.00
      General and administrative expense (per boe)(2)       $1.75 - $2.25

      Non-cash stock-based compensation (per boe)           $0.70 - $1.00

    Income tax rate (percent of pre-tax income)                  38%
    Percent of income tax deferred                               90%

    (1) Differential to calendar month average NYMEX futures price for oil
    and to average of last three trading days of prompt NYMEX futures
    contract for gas.

    (2) Excludes non-cash stock-based compensation.

Conference Call Information

Continental Resources will host a conference call on Thursday, Feb. 26, 2009, at 10:00 a.m. ET (9 a.m. CT) to discuss its fourth quarter 2008 results. Interested parties may listen to the conference call via the Company's website at http://www.contres.com or by phone:

    Dial in:           (888) 713-4217
    Intl. dial in:     (617) 213-4869
    Pass code:         65130417

    Replay number:     (888) 286-8010
    Intl. replay:      (617) 801-6888
    Pass code:         18971146

Conference Presentations

Continental management is currently scheduled to present at the Raymond James & Associates 30th Annual Institutional Investors Conference in Orlando (March 8-11, 2009) and at the Howard Weil 37th Annual Energy Conference in New Orleans (March 22-26, 2009).

Continental Resources is a crude-oil concentrated, independent oil and natural gas exploration and production company with operations in the Rocky Mountain, Mid-Continent and Gulf Coast regions of the United States. The Company focuses its operations in large new and developing resource plays where horizontal drilling, advanced fracture stimulation and enhanced recovery technologies provide the means to economically develop and produce oil and natural gas reserves from unconventional formations.

This press release includes forward-looking information that is subject to a number of risks and uncertainties, many of which are beyond the Company's control. All information, other than historical facts included in this press release, regarding strategy, future operations, drilling plans, estimated reserves, future production, estimated capital expenditures, projected costs, the potential of drilling prospects and other plans and objectives of management are forward-looking information. All forward-looking statements speak only as of the date of this press release. Although the Company believes that the plans, intentions and expectations reflected in or suggested by the forward-looking statements are reasonable, there is no assurance that these plans, intentions or expectations will be achieved. Actual results may differ materially from those anticipated due to many factors, including oil and natural gas prices, industry conditions, drilling results, uncertainties in estimating reserves, uncertainties in estimating future production from enhanced recovery operations, availability of drilling rigs and other services, availability of crude oil and natural gas transportation capacity, availability of capital resources and other factors listed in reports we have filed or may file with the Securities and Exchange Commission.

    CONTACT:  Continental Resources, Inc.
         J. Warren Henry              Brian Engel
         Investors                    Media
         (580) 548-5127               (580) 249-4731
     


    Condensed Consolidated Statements of Income
     (in thousands, except          Three months ended       Year ended
      share data)                   ------------------       -----------
                                      December 31,          December 31,
                                      ------------          ------------
                                     2008       2007       2008       2007
                                     ----       ----       ----       ----

    Revenues:
    Oil and natural gas sales      $130,668   $183,780   $939,906   $606,514
    Loss on mark-to-market
     derivatives                          -    (30,476)    (7,966)   (44,869)
    Oil and natural gas
     service operations               5,128      5,690     28,550     20,570
                                    ----------------------------------------
    Total revenues                  135,796    158,994    960,490    582,215

    Operating costs and expenses:
    Production expense               26,362     18,288    101,635     76,489
    Production tax                   10,199     10,251     58,610     32,562
    Exploration expense              13,882      2,499     40,160      9,163
    Oil and gas service operations    2,391      3,942     18,188     12,709
    Depreciation, depletion,
     amortization and accretion      53,074     26,326    148,902     93,632
    Property impairments             11,227      4,887     28,847     17,879
    General and administrative (1)    7,907      5,148     35,719     32,802
    Gain on sale of assets             (488)      (650)      (894)      (988)
                                    ----------------------------------------
    Total operating costs and
     expenses                       124,554     70,691    431,167    274,248

    Income from operations           11,242     88,303    529,323    307,967
    Interest expense and other       (2,743)    (2,543)   (10,793)   (11,190)
                                    ----------------------------------------
    Net income before income
     tax expense                      8,499     85,760    518,530    296,777
    Income tax expense                8,083     24,868    197,580    268,197
                                    ----------------------------------------
    Net income                         $416    $60,892   $320,950    $28,580

    Basic net income per share        $0.00      $0.36      $1.91      $0.17
    Diluted net income per share       0.00       0.36       1.89       0.17

    Basic weighted average
     shares outstanding             168,335    167,590    168,087    164,059
    Diluted weighted average
     shares outstanding             169,231    169,255    169,392    165,422

    (1) Includes non-cash charges for stock-based compensation of
        $2.6 million and $0.7 million for the three months ended December 31,
        2008 and 2007, respectively, and $9.1 million and $12.8 million for
        the years ended December 31, 2008 and 2007, respectively.



    Condensed Consolidated Balance Sheets         December 31,  December 31,
    (in thousands)                                -----------   -----------
                                                      2008         2007
                                                      ----         ----


    Assets:
    Cash and cash equivalents                        $5,229       $8,761
    Receivables                                     229,079      163,090
    Inventories and other                            43,387       33,713
    Net property and equipment                    1,935,143    1,157,926
    Other assets                                      3,041        1,683
                                                  ----------------------
    Total assets                                 $2,215,879   $1,365,173
                                                  ----------------------

    Liabilities and shareholders' equity:
    Current liabilities                            $403,594     $266,106
    Long-term debt                                  376,400      165,000
    Other noncurrent liabilities                    487,177      310,935
    Shareholders' equity                            948,708      623,132
                                                  ----------------------
    Total liabilities and shareholders' equity   $2,215,879   $1,365,173
                                                  ----------------------



                                                            Year ended
    Condensed Consolidated Statements of Cash Flows         ----------
    (in thousands)                                          December 31,
                                                            ------------
                                                          2008        2007
                                                          ----        ----

    Net income                                          $320,950     $28,580
    Adjustments to reconcile net income to net cash
     provided by operating activities:
    Non-cash expenses                                    363,801     416,977
    Changes in assets and liabilities                     35,164     (54,909)
                                                         -------------------
    Net cash provided by operating activities            719,915     390,648

    Net cash used in investing activities               (927,617)   (483,498)

    Net cash provided by financing activities            204,170      94,568

    Effect of exchange rate on change in cash and cash
     equivalents                                               -          25
                                                         -------------------

    Net change in cash and cash equivalents               (3,532)      1,743
    Cash and cash equivalents at beginning of period       8,761       7,018
                                                         -------------------
    Cash and cash equivalents at end of period            $5,229      $8,761

Non-GAAP Financial Measures

EBITDAX represents earnings before interest expense, income taxes, depreciation, depletion, amortization and accretion, property impairments, exploration expense, unrealized derivative gains and losses, and non-cash compensation expense. EBITDAX is not a measure of net income or cash flow as determined by generally accepted accounting principles (GAAP). EBITDAX should not be considered as an alternative to, or more meaningful than, net income or cash flow as determined in accordance with GAAP or as an indicator of a Company's operating performance or liquidity. Certain items excluded from EBITDAX are significant components in understanding and assessing a company's financial performance, such as a company's cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of EBITDAX. The Company's computations of EBITDAX may not be comparable to other similarly titled measures of other companies. The Company believes that EBITDAX is a widely followed measure of operating performance and may also be used by investors to measure its ability to meet future debt service requirements, if any. The Company's credit facility requires that it maintain a total funded debt to EBITDAX ratio, as defined therein, of no greater than 3.75 to 1 on a rolling four-quarter basis. The credit facility defines EBITDAX consistently with the definition of EBITDAX utilized and presented by the Company. The following table represents a reconciliation of the Company's net income to EBITDAX.


                                  Three months ended        Year ended
    (in thousands)                   December 31,          December 31,
                                    --------------        ---------------
                                    2008       2007       2008       2007
                                    ----       ----       ----       ----
                                                (unaudited)

    Net income                      $416     $60,892   $320,950    $28,580
    Loss on mark-to-market
     derivatives                       -      14,160          -     26,703
    Income tax expense             8,083      24,868    197,580    268,197
    Interest expense               3,406       3,085     12,188     12,939
    Depreciation, depletion,
     amortization and accretion   53,074      26,326    148,902     93,632
    Property impairments          11,227       4,887     28,847     17,879
    Exploration expense           13,882       2,499     40,160      9,163
    Equity compensation            2,592         695      9,081     12,792
                                 -----------------------------------------
    EBITDAX                      $92,680    $137,412   $757,708   $469,885

[Via http://www.prnewswire.com]

Noble Group to Report Fourth Quarter and Full Year 2008 Financial Results on 26 February 2009

HONG KONG, Feb. 26 /PRNewswire/ -- Noble Group Limited (SGX: NOBL), a leading global supply chain manager of agricultural, industrial and energy products, today announced that it will report its financial results for the fourth quarter and the full year 2008, after the Singapore market closes on 26 February 2009. Noble's management will hold an earnings conference call and webcast on 26 February 2009 at 18:30 Hong Kong / Singapore time (05:30 ET, 10:30 UK time, 11:30 Berlin, Germany / Bern, Switzerland time and 19:30 Australia EST -- Sydney, Melbourne).

Dial-in details for the conference call are as follows:

US Toll Free - +1.800.901.5231

US Toll - +1.617.786.2961

Hong Kong Toll - (852) 3002 1672

Singapore Toll Free - (65) 800 1301 175

Switzerland Toll Free - (41) 0 800 56 4442

Germany Toll Free - (49) 0 800 181 3857

Australia Toll Free - (61) 1 800 002 971

UK Toll Free - (44) 00 800 280 02002

(Please dial the US Toll Number if you are in a country outside those listed above.)

Passcode for all regions: "Noble Group"

In addition to the live broadcast, an archive will be available at http://www.thisisnoble.com.

About Noble Group

Noble Group (SGX: NOBL) is a market leader in managing the global supply chain of agricultural, industrial and energy products. We operate from over 100 offices in more than 40 countries, serving 4000+ customers. Noble manages a diversified portfolio of essential raw materials, integrating the sourcing, marketing, processing, financing and transportation.

With annual revenues exceeding US$20 billion, Noble continues its transition to owning and managing more strategic assets, sourcing from low cost producers such as Brazil, Australia and Indonesia and supplying to high growth demand markets including China, India and the Middle East. Today Noble owns coal and iron ore mines, grain crushing facilities, sugar and ethanol plants, vessels, ports and other infrastructure to ensure high quality products are delivered in the most efficient and timely manner to its customers.

In 2008, Noble debuted on the Fortune Global 500 (#349), was included in the new 30 security Straits Times Index, gained a top ten placing in the ACCA/CFO Asia "Regional Corporate Transparency Index (CTI)" and received a BBB- rating (investment grade) from Fitch. Noble was placed on the Forbes Global 2000 and Forbes Fab 50 while being included in the S&P Global Challengers and The Asset's Best 60 Corporate Governance Award. Noble also received the Corporate Governance Recognition Award: Classes Of 2006 - 2008 - by Corporate Governance Asia and was chosen as one of FinanceAsia's Best Companies. In 2005, Noble joined the MSCI Singapore Index. During this period, the Group was recognized as one of BusinessWeek's Stars of Asia and a Best Employer by Hewitt Associates.

    For further details please contact:
    Mr. Stephen Brown
    Noble Group Limited
    Tel: +852 2250 2060
    Fax: +852 2861 0018
    Email: stephenbrown@thisisnoble.com

    Mr. Brad Smolar
    Smolar Limited
    Tel: +852 6339 3396
    Fax: +852 2573 2473
    Email: reputation@smolar.com

[Via http://www.prnewswire.com]

Integrys Energy Group Reports 2008 Fourth Quarter Financial Results and Its Strategy to Fully or Partially Divest and/or Scale Back Its Nonregulated Energy Services Business Segment

CHICAGO, Feb. 25 /PRNewswire-FirstCall/ -- Integrys Energy Group, Inc. (NYSE: TEG) recognized income available for common shareholders on a GAAP (generally accepted accounting principles) basis of $25.6 million ($0.33 diluted earnings per share) for the quarter ended December 31, 2008, compared with income available for common shareholders on a GAAP basis of $85.1 million ($1.11 diluted earnings per share) for the quarter ended December 31, 2007.

    Highlights:

    -- For the quarter ended December 31, 2008, income available for common
       shareholders included net after-tax non-cash accounting losses of $41.9
       million, compared with net after-tax non-cash accounting gains of $47.2
       million for the quarter ended December 31, 2007. This negative $89.1
       million after-tax change in non-cash activity quarter-over-quarter was
       related to derivative and inventory accounting activities at Integrys
       Energy Services, Inc. Integrys Energy Services expects to recover non-
       cash accounting losses related to derivative fair value adjustments and
       inventory valuation adjustments when the related electric and natural
       gas transactions are physically settled.

    -- Although not readily apparent when including the non-cash activity
       discussed above, Integrys Energy Services had another strong quarter
       from an economic value perspective, evidenced by the growth in its
       forward book value. Energy prices sequentially declined approximately
       20% during the fourth quarter of 2008, following the approximate 40%
       decline in energy prices during the third quarter of 2008. The lower
       energy prices provided attractive risk mitigation opportunities for
       Integrys Energy Services' customers, who returned to longer-term, more
       typical contract practices. Forward contracted retail electric volumes
       increased approximately 33%, while forward contracted retail natural
       gas volumes were unchanged from December 31, 2007 to December 31, 2008.
       When compared to previous years, these reduced retail electric and
       natural gas volumetric growth rates resulted from Integrys Energy
       Services' focus on higher quality business within existing markets, in
       addition to the effect of applying high credit standards under current
       market conditions.

    -- Aided by a retail natural gas distribution rate increase at The Peoples
       Gas Light and Coke Company (Peoples Gas), an interim retail natural gas
       distribution rate increase at Minnesota Energy Resources Corporation,
       and colder weather conditions, earnings at the natural gas segment
       improved $7.9 million (28.1%) quarter-over-quarter.

    -- Higher operating and maintenance expenses in the fourth quarter of
       2008, compared with the same quarter in 2007, drove a $3.9 million
       (21.8%) quarter-over-quarter decrease in electric segment earnings.

Details regarding Integrys Energy Group's financial results for the quarters ended December 31, 2008 and 2007 are as follows:



    Integrys Energy Group's GAAP Results
    (Millions, except share amounts)
                                              2008       2007    Change

    Income from continuing operations        $21.8      $91.9    (76.3%)
    Basic earnings per share from
     continuing operations                   $0.27      $1.19    (77.3%)
    Diluted earnings per share from
     continuing operations                   $0.27      $1.19    (77.3%)

    Income available for common shareholders $25.6      $85.1    (69.9%)
      Basic earnings per share               $0.33      $1.11    (70.3%)
      Diluted earnings per share             $0.33      $1.11    (70.3%)

    Average shares of common stock
      Basic                                   76.7       76.5       0.3%
      Diluted                                 77.0       76.6       0.5%

Significant factors impacting the change in earnings and earnings per share were as follows:

    -- Financial results at Integrys Energy Services decreased $76.7 million,
       from earnings of $49.1 million for the quarter ended December 31, 2007,
       to a net loss of $27.6 million for the same quarter in 2008, driven by
       the following:
       -- An $89.1 million after-tax decrease in Integrys Energy Services'
          margin quarter-over-quarter related to non-cash activity, of which
          $81.8 million was related to non-cash activity associated with
          electric operations, with the remaining $7.3 million related to non-
          cash activity associated with natural gas operations. An overview
          of this non-cash activity has been provided below.

          Non-cash electric operations:

          The 20% decline in energy prices during the fourth quarter of 2008
          drove a $58.0 million net after-tax non-cash loss, compared with a
          $23.8 million net after-tax non-cash gain recognized in the fourth
          quarter of 2007, related to a 5% increase in energy prices during
          the fourth quarter of 2007. The non-cash unrealized gains and
          losses recognized resulted from the application of derivative
          accounting rules to Integrys Energy Services' portfolio of
          derivative electric customer supply contracts, requiring that these
          derivative instruments be adjusted to fair market value. The
          derivative instruments are utilized to economically hedge the price,
          volume, and ancillary risks associated with related electric
          customer sales contracts. The associated electric customer sales
          contracts are not adjusted to fair value, as they do not meet the
          definition of derivative instruments under GAAP, creating an
          accounting mismatch. As such, the non-cash unrealized gains
          and losses related to the electric customer supply contracts will
          vary each period, with non-cash unrealized gains being recognized in
          periods of increasing energy prices and non-cash unrealized losses
          being recognized in periods of declining energy prices, and will
          ultimately reverse when the related customer sales contracts settle.

          Non-cash natural gas operations:

          The spot price of natural gas decreased significantly during the
          fourth quarter of 2008 (below the average cost of natural gas in
          inventory which Integrys Energy Services had injected into storage
          earlier in 2008), which resulted in a lower-of-cost-or-market
          adjustment, as required by GAAP. This adjustment contributed a
          $32.8 million quarter-over-quarter decrease in the non-cash natural
          gas margin, driven by non-cash inventory write-downs in the fourth
          quarter of 2008. The negative impact on realized margin related to
          these inventory adjustments was offset by $44.8 million of net
          after-tax non-cash unrealized gains recognized in the fourth quarter
          of 2008, primarily related to derivative instruments utilized to
          mitigate the price risk on natural gas inventory underlying natural
          gas storage transactions. In the fourth quarter of 2007, natural
          gas derivative instruments resulted in the recognition of $19.3
          million of net after-tax non-cash unrealized gains. Similar to the
          electric operations discussed above, non-cash gains and losses
          related to derivative natural gas sales and customer supply
          contracts will vary each period, and will ultimately reverse when
          the physical contracts settle, or when natural gas is withdrawn from
          inventory.

       -- The recognition of $5.1 million of after-tax earnings from Integrys
          Energy Services' investment in a synthetic fuel production facility
          during the three months ended December 31, 2007. Production and
          sale of synthetic fuel by Integrys Energy Services ended when
          Section 29/45K of the Internal Revenue Code, which provided for
          Section 29/45K federal tax credits from the production and sale of
          synthetic fuel, expired effective December 31, 2007. As such, there
          were no earnings from this facility in the fourth quarter of 2008.

       -- A $9.3 million ($5.6 million after-tax) increase in operating and
          maintenance expense, primarily due to an increase in payroll and
          benefits expense, increased broker commissions driven by higher
          transacted volumes, and an increase in bad debt expense.

The above decreases in Integrys Energy Services financial results were partially offset by the following:

       -- A $16.7 million ($10.0 million after-tax) increase in realized
          natural gas margins, primarily related to realized gains on
          wholesale natural gas storage transactions. Quarter-over-quarter,
          Integrys Energy Services increased its natural gas storage
          withdrawals, which drove this increase in realized natural gas
          margins.

       -- A $10.0 million positive year-over-year after-tax impact on earnings
          related to the recognition of investment tax credits on solar
          projects completed in the fourth quarter of 2008.

       -- A $3.7 million after-tax increase in earnings related to
          discontinued operations at Integrys Energy Services. In the third
          quarter of 2008, Integrys Energy Services sold its Stoneman
          generation facility located in southwestern Wisconsin, but the
          transaction did not have a material impact on earnings. However, in
          the fourth quarter of 2008, Integrys Energy Services recognized a
          $3.8 million after-tax gain on the sale of this facility in
          discontinued operations when a previously contingent payment was
          paid by the buyer. This contingent payment resulted from
          legislation that passed in the fourth quarter of 2008, which
          extended the production tax credits available for certain biomass
          facilities.

    -- Due to the seasonal nature of the natural gas distribution business,
       the regulated natural gas utilities typically experience the majority
       of their income in the first and fourth quarters, as customers require
       natural gas for heating purposes during the winter months. During the
       fourth quarter of 2008, earnings recognized by the regulated natural
       gas segment were $36.0 million, which represented a $7.9 million
       (28.1%) increase over earnings of $28.1 million recognized during the
       same quarter in 2007. This change was driven by the following:

       -- A rate increase at Peoples Gas, which was effective in the first
          quarter of 2008, and an interim rate increase at Minnesota Energy
          Resources, which was effective October 1, 2008, had an approximate
          $21 million ($12.6 million after-tax) positive quarter-over-quarter
          impact on the natural gas utility margin.

       -- A 10.7% increase in natural gas throughput volumes to residential
          and commercial and industrial natural gas customers, driven by
          colder quarter-over-quarter weather conditions, partially offset by
          the negative impact that the general economic slowdown had on
          quarter-over-quarter natural gas sales volumes, drove an approximate
          $2.4 million net positive after-tax quarter-over-quarter impact on
          the natural gas utility segment margin.

       -- An approximate $5 million ($3.0 million after-tax) increase in bad
          debt and customer collection expense. The higher bad debt expense
          was driven by the impact of higher average quarter-over-quarter
          energy prices on overall accounts receivable balances, higher
          throughput volumes as a result of colder quarter-over-quarter
          weather conditions, and an increase in the number of past due
          accounts related to worsening economic conditions. Higher customer
          collection expense resulted from more customer accounts being turned
          over to collection agencies and other third parties for collection.

       -- A $1.1 million ($0.7 million after-tax) quarter-over-quarter
          increase in street restoration costs at Peoples Gas.

       -- Higher employee benefit expenses.

    -- The winter months, which basically comprise the first and fourth
       quarters, are generally the least profitable months for the regulated
       electric utility segment as the air conditioning load for customers is
       generally lowest during this period. During the fourth quarter of
       2008, the regulated electric utility segment experienced earnings of
       $14.0 million, which represented a $3.9 million (21.8%) decline over
       the $17.9 million of earnings recognized in the same quarter of 2007.
       The change was driven by the following:

       -- A $3.3 million ($2.0 million after-tax) increase in depreciation
          expense related to Weston 4, which was placed in service for
          accounting purposes in April 2008.

       -- A $3.2 million ($1.9 million after-tax) increase in regulated
          electric transmission expense primarily related to higher rates
          charged by the Midwest Independent System Operator and American
          Transmission Company due to additional transmission investment.

       -- An approximate $1 million ($0.6 million after-tax) increase in bad
          debt expense at the electric utility segment, primarily as a result
          of worsening economic conditions.

       -- A $1.7 million ($1.0 million after-tax) quarter-over-quarter
          decrease in miscellaneous income, driven by $1.5 million of interest
          income recognized in the fourth quarter of 2007 related to the
          completion of transmission facilities Wisconsin Public Service
          Corporation was funding on American Transmission Company's behalf
          before the start-up of Weston 4.

       -- Fuel and purchased power costs at Wisconsin Public Service that were
          approximately $3 million ($1.8 million after-tax) lower than what
          was recovered in rates during the quarter ended December 31, 2008,
          compared with fuel and purchased power costs that were approximately
          $1 million ($0.6 million after-tax) higher than what was recovered
          in rates during the same quarter in 2007. This drove an approximate
          $4 million ($2.4 million after-tax) offsetting increase in margin
          quarter-over-quarter.

    -- Financial results at the Holding Company and Other segment improved
       $7.1 million, from a net loss of $3.9 million during the quarter ended
       December 31, 2007, to earnings of $3.2 million for the quarter ended
       December 31, 2008, due primarily to the following:

       -- An $11.0 million ($6.6 million after-tax) decrease in operating and
          maintenance expenses quarter-over-quarter, primarily related to
          reductions in consulting fees, compensation and benefits, and
          contractor costs.

       -- A $2.9 million ($1.8 million after-tax) increase in earnings from
          Integrys Energy Group's approximate 34% ownership interest in
          American Transmission Company, from earnings of $13.8 million ($8.3
          million after-tax) in the fourth quarter of 2007, to earnings of
          $16.7 million ($10.1 million after-tax) in the fourth quarter of
          2008.

    -- In connection with the Peoples Energy merger on February 21, 2007,
       Integrys Energy Group announced its intent to divest of Peoples Energy
       Production Company, its oil and natural gas production subsidiary,
       which was sold in the third quarter of 2007. Discontinued operations
       recorded for Peoples Energy Production were a $6.1 million loss in the
       fourth quarter of 2007. During the quarter ended December 31, 2007,
       the initial after-tax gain recorded in the third quarter of 2007 on the
       sale was reduced by $6.1 million after-tax due to certain post closing
       adjustments, primarily pertaining to working capital.

YEAR-END RESULTS

Integrys Energy Group recognized income available for common shareholders on a GAAP basis of $126.4 million ($1.64 diluted earnings per share) for the year ended December 31, 2008, compared with income available for common shareholders on a GAAP basis of $251.3 million ($3.50 diluted earnings per share) for the year ended December 31, 2007. It is important to note that the financial results of PEC and its subsidiaries were only included in 2007 income available for common shareholders from February 22, 2007 through December 31, 2007, the period following the merger.

Included in income available for common shareholders for the year ended December 31, 2007, was $73.3 million of after-tax income related to discontinued operations (due primarily to earnings pertaining to a partial year of operation of Integrys Energy Group's oil and natural gas business in addition to a gain recorded on the sale of this business in 2007). After-tax income from discontinued operations was $4.7 million in 2008.

For the year ended December 31, 2008, income available for common shareholders also included net after-tax non-cash accounting losses of $90.9 million, compared with net after-tax non-cash accounting gains of $42.7 million for the year ended December 31, 2007. This negative $133.6 million after-tax year-over-year change in non-cash activity was related to derivative and inventory accounting activities at Integrys Energy Services. Integrys Energy Services expects to recover non-cash accounting losses related to derivative fair value adjustments and inventory valuation adjustments when the related electric and natural gas transactions are physically settled.

INTEGRYS ENERGY GROUP'S STRATEGY TO FULLY OR PARTIALLY DIVEST AND/OR SCALE BACK ITS NONREGULATED ENERGY SERVICES BUSINESS SEGMENT

Integrys Energy Group has made a decision to either divest entirely or partially its nonregulated energy services business segment, Integrys Energy Services, or significantly reduce the scope and scale of this business. Integrys Energy Group's short-term strategy will be to reduce and refocus its capital on those aspects of Integrys Energy Services' business that yield the highest return. Longer-term, in the event that a full divestiture of Integrys Energy Services does not occur and a portion of the nonregulated energy services business remains, it will be a smaller segment that requires significantly less capital, parental guaranties and overall financial liquidity support from Integrys Energy Group. Execution of this strategic decision is expected to result in lower earnings contributions from Integrys Energy Services going forward. In return, Integrys Energy Group expects an improved business risk profile and enhanced financial security. Divestiture of the nonregulated business segment, or a reduction in its size and scope, is also expected to allow Integrys Energy Group to eliminate or reduce the credit facilities and other forms of financial support committed to Integrys Energy Services. More details regarding this strategy change will be provided during Integrys Energy Group's earnings conference call scheduled for Thursday, February 26, 2009, at 8 a.m. CST.

EARNINGS FORECAST

Integrys Energy Group continues to manage its portfolio of businesses to achieve long-term growth in its core utility operations, while divesting and/or scaling back the nonregulated business segment. The company utilizes financial tools commonly used in the industry to help mitigate risk for the benefit of both shareholders and customers. In addition, the company's asset management strategy continues to deliver shareholder return from certain asset transactions. Given the current economic environment, turmoil in the global financial markets, and the decision to reduce the size and scope of its nonregulated business segment, the company has reduced its long-term diluted earnings per share growth rate target to 4 to 6 percent, on an average annualized basis, with 2009 as its base year, excluding non-cash derivative accounting and inventory valuation adjustment gains and losses.

The company anticipates generating earnings per diluted share in 2009 within the range of $2.51 to $2.66. This guidance assumes normal weather conditions, the availability of generation units, and reasonable rate relief for certain utilities. The diluted earnings per share guidance excludes the impact of non-cash lower-of-cost-or-market inventory adjustments and derivative accounting mark-to-market volatility for all of 2009 (such mark-to- market volatility is expected to include about $29.6 million of non-cash after-tax gains for all of 2009 relating to contracts terminating in 2009 which had net non-cash after-tax losses recognized in 2008).

The projected guidance range for 2009 diluted earnings per share from continuing operations -- adjusted is anticipated to be between $2.53 and $2.68. Diluted earnings per share from continuing operations -- adjusted guidance provides investors with additional insight into the company's operating performance because it eliminates the effects of certain items that are not comparable from one period to the next. Please see the "Diluted Earnings per Share Information -- Non-GAAP Financial Information" included at the end of this news release and also included with the supplemental data package on the company's Web site (to be available at approximately 6:00 a.m. CDT on February 26, 2009) for a reconciliation of diluted earnings per share from continuing operations to diluted earnings per share from continuing operations -- adjusted.

Integrys Energy Group's management will provide earnings guidance by its four main business segments during its earnings conference call at 8 a.m. CST on February 26.

CONFERENCE CALL

An earnings conference call is scheduled for 8 a.m. CST on Thursday, February 26, 2009. Executive management of Integrys Energy Group will discuss 2008 fourth quarter and full year financial results and prospects for 2009. To access the call, which is open to the public, call 888-690-9634 (toll free) 15 minutes prior to the scheduled start time. Callers will be required to supply EARNINGS as the passcode and MR. STEVEN ESCHBACH as the leader. Callers will be placed on hold with music until the call begins. A replay of the conference call will be available through May 5, 2009, by dialing 866-365-4158 (toll free).

Investors may also listen to the conference live on Integrys Energy Group's corporate Web site at http://www.integrysgroup.com/investor/presentations.aspx. An archive of the Webcast will be available on the company's Web site at http://www.integrysgroup.com/investor/presentations.aspx.

In conjunction with this conference call, Integrys Energy Group will post on its Web site PowerPoint slides that will be referred to within the prepared remarks during the call. The slides will be available at 6:00 a.m. CST on February 26.

FORWARD-LOOKING STATEMENTS

Financial results in this news release are unaudited. In this news release, Integrys Energy Group and its subsidiaries make statements concerning expectations, beliefs, plans, objectives, goals, strategies, and future events or performance. Such statements are "forward-looking statements' within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements are subject to assumptions and uncertainties; therefore, actual results may differ materially from those expressed or implied by such forward-looking statements. Although Integrys Energy Group and its subsidiaries believe that these forward-looking statements and the underlying assumptions are reasonable, they cannot provide assurance that such statements will prove correct.

Forward-looking statements include, among other things, statements concerning management's expectations and projections regarding earnings, regulatory matters, fuel costs, sources of electric energy supply, coal and natural gas deliveries, remediation costs, environmental and other capital expenditures, liquidity and capital resources, trends, estimates, completion of construction projects, and other matters.

Forward-looking statements involve a number of risks and uncertainties. Some risk factors that could cause results to differ from any forward-looking statement include those described in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2008. Other factors include:

    -- Resolution of pending and future rate cases and negotiations (including
       the recovery of deferred costs) and other regulatory decisions
       impacting Integrys Energy Group's regulated businesses;
    -- The impact of recent and future federal and state regulatory changes,
       including legislative and regulatory initiatives regarding deregulation
       and restructuring of the electric and natural gas utility industries
       and possible future initiatives to address concerns about global
       climate change, changes in environmental, tax, and other laws and
       regulations to which Integrys Energy Group and its subsidiaries are
       subject, as well as changes in the application of existing laws and
       regulations;
    -- Current and future litigation, regulatory investigations, proceedings,
       or inquiries, including but not limited to, manufactured gas plant site
       cleanup, reconciliation of revenues from the Gas Charge and related
       natural gas costs, and the contested case proceeding regarding the
       Weston 4 air permit;
    -- The impacts of changing financial market conditions, credit ratings,
       and interest rates on the liquidity and financing efforts of Integrys
       Energy Group and its subsidiaries;
    -- The risks associated with executing Integrys Energy Group's plan to
       significantly reduce the scope and scale of, or divest in its entirety,
       the nonregulated energy services business;
    -- The risks associated with changing commodity prices (particularly
       natural gas and electricity) and the available sources of fuel and
       purchased power, including their impact on margins;
    -- Resolution of audits or other tax disputes with the Internal Revenue
       Service and various state, local, and Canadian revenue agencies;
    -- The effects, extent, and timing of additional competition or regulation
       in the markets in which Integrys Energy Group's subsidiaries operate;
    -- The retention of market-based rate authority;
    -- The risk associated with the value of goodwill or other intangibles and
       their possible impairment;
    -- Investment performance of employee benefit plan assets;
    -- Advances in technology;
    -- Effects of and changes in political and legal developments, as well as
       economic conditions and the related impact on customer demand;
    -- Potential business strategies, including mergers, acquisitions, and
       construction or disposition of assets or businesses, which cannot be
       assured to be completed timely or within budgets;
    -- The direct or indirect effects of terrorist incidents, natural
       disasters, or responses to such events;
    -- The effectiveness of risk management strategies and the use of
       financial and derivative instruments;
    -- The risks associated with the inability of Integrys Energy Group's and
       its subsidiaries' counterparties, affiliates, and customers to meet
       their obligations;
    -- Weather and other natural phenomena, in particular the effect of
       weather on natural gas and electricity sales;
    -- The utilization of tax credit carryforwards;
    -- The effect of accounting pronouncements issued periodically by
       standard-setting bodies; and
    -- Other factors discussed in the 2008 Annual Report on Form 10-K and in
       other reports filed by Integrys Energy Group from time to time with the
       United States Securities and Exchange Commission.

Except to the extent required by the federal securities laws, Integrys Energy Group and its subsidiaries undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

About Integrys Energy Group, Inc.

Integrys Energy Group is a diversified holding company with regulated utility operations operating through six wholly owned subsidiaries, Wisconsin Public Service Corporation, The Peoples Gas Light and Coke Company, North Shore Gas Company, Upper Peninsula Power Company, Michigan Gas Utilities Corporation, and Minnesota Energy Resources Corporation; nonregulated operations serving the competitive energy markets in the United States and Canada through its wholly owned nonregulated subsidiary, Integrys Energy Services; and also a 34% equity ownership interest in American Transmission Company LLC (an electric transmission company operating in Wisconsin, Michigan, Minnesota, and Illinois).

More information about Integrys Energy Group, Inc. is available online at http://www.integrysgroup.com.

                -- Unaudited Financial Statements to Follow --



                           INTEGRYS ENERGY GROUP, INC.

                        CONSOLIDATED STATEMENTS OF INCOME

                                       Three Months Ended  Twelve Months Ended
                                           December 31         December 31
    (Millions, except per share data)    2008      2007      2008      2007

    Nonregulated revenue               $2,181.5  $2,003.8  $9,737.9  $6,987.0
    Utility revenue                     1,236.8   1,057.8   4,309.9   3,305.4
    Total revenues                      3,418.3   3,061.6  14,047.8  10,292.4

    Nonregulated cost of fuel, natural
     gas, and purchased power           2,184.1   1,872.9   9,654.3   6,676.2
    Utility cost of fuel, natural gas,
     and purchased power                  816.5     685.4   2,744.1   2,044.2
    Operating and maintenance expense     300.5     264.6   1,081.2     922.1
    Goodwill impairment loss                 -         -        6.5        -
    Depreciation and amortization
     expense                               57.6      51.8     221.4     195.1
    Taxes other than income taxes          24.5      22.8      93.6      87.4
    Operating income                       35.1     164.1     246.7     367.4

    Miscellaneous income                   22.8      14.7      87.3      64.1
    Interest expense                      (47.2)    (37.3)   (158.1)   (164.5)
    Minority interest                       0.1        -        0.1       0.1
    Other expense                         (24.3)    (22.6)    (70.7)   (100.3)

    Income before taxes                    10.8     141.5     176.0     267.1
    Provision (benefit) for income
     taxes                                (11.0)     49.6      51.2      86.0
    Income from continuing operations      21.8      91.9     124.8     181.1

    Discontinued operations, net of tax     4.6      (6.0)      4.7      73.3
    Income before preferred stock
     dividends of subsidiary               26.4      85.9     129.5     254.4

    Preferred stock dividends of
     subsidiary                             0.8       0.8       3.1       3.1
    Income available for common
     shareholders                         $25.6     $85.1    $126.4    $251.3

    Average shares of common stock
        Basic                              76.7      76.5      76.7      71.6
        Diluted                            77.0      76.6      77.0      71.8

    Earnings per common share (basic)
        Income from continuing
         operations                       $0.27     $1.19     $1.59     $2.49
        Discontinued operations, net
         of tax                            0.06     (0.08)     0.06     $1.02
        Earnings per common share
         (basic)                          $0.33     $1.11     $1.65     $3.51

    Earnings per common share (diluted)
        Income from continuing
         operations                       $0.27     $1.19     $1.58     $2.48
        Discontinued operations, net
         of tax                            0.06     (0.08)     0.06     $1.02
        Earnings per common share
         (diluted)                        $0.33     $1.11     $1.64     $3.50

    Dividends per common share            $0.67     $0.66     $2.68     $2.56



                           INTEGRYS ENERGY GROUP, INC.

                           CONSOLIDATED BALANCE SHEETS

    At December 31
    (Millions)                                        2008              2007

    Assets
    Cash and cash equivalents                       $254.1             $41.2
    Accounts receivable and accrued
     unbilled revenues, net of reserves
     of $62.5 and $56.0, respectively              2,155.3           1,870.0
    Inventories                                      732.9             663.4
    Assets from risk management activities         2,223.7             840.7
    Regulatory assets                                244.0             141.7
    Other current assets                             280.8             169.3
    Current assets                                 5,890.8           3,726.3

    Property, plant, and equipment, net
     of accumulated depreciation of
     $2,710.0 and $2,602.2, respectively           4,773.3           4,463.8
    Regulatory assets                              1,444.8           1,102.3
    Assets from risk management activities           758.7             459.3
    Goodwill                                         933.9             948.3
    Pension assets                                      -              101.4
    Other                                            471.0             433.0
    Total assets                                 $14,272.5         $11,234.4

    Liabilities and Shareholders' Equity
    Short-term debt                               $1,209.0            $468.2
    Current portion of long-term debt                155.2              55.2
    Accounts payable                               1,534.3           1,331.8
    Liabilities from risk management
     activities                                    2,190.3             813.5
    Regulatory liabilities                            58.8              77.9
    Deferred income taxes                             71.6              13.9
    Other current liabilities                        494.8             487.7
    Current liabilities                            5,714.0           3,248.2

    Long-term debt                                 2,288.0           2,265.1
    Deferred income taxes                            435.7             494.4
    Deferred investment tax credits                   36.9              38.3
    Regulatory liabilities                           275.5             292.4
    Environmental remediation liabilities            640.6             705.6
    Pension and other postretirement
     benefit obligations                             636.5             247.9
    Liabilities from risk management activities      762.7             372.0
    Asset retirement obligations                     179.1             140.2
    Other                                            152.8             143.4
    Long-term liabilities                          5,407.8           4,699.3

    Commitments and contingencies

    Preferred stock of subsidiary with no
     mandatory redemption                             51.1              51.1
    Common stock - $1 par value,
     200,000,000 shares authorized                    76.4              76.4
    Additional paid-in capital                     2,487.9           2,473.8
    Retained earnings                                624.6             701.9
    Accumulated other comprehensive loss             (72.8)             (1.3)
    Treasury stock and shares in deferred
     compensation trust                              (16.5)            (15.0)
    Total liabilities and shareholders'
     equity                                      $14,272.5         $11,234.4



                           INTEGRYS ENERGY GROUP, INC.

                      CONSOLIDATED STATEMENTS OF CASH FLOWS

    Year Ended December 31
    (Millions)                                        2008              2007
    Operating Activities
    Income before preferred stock dividends
     of subsidiary                                  $129.5            $254.4
    Adjustments to reconcile income
     before preferred stock dividends of
     subsidiary to net cash (used for)
     provided by operating activities
       Discontinued operations, net of tax            (4.7)            (73.3)
       Goodwill impairment loss                        6.5               -
       Depreciation and amortization expense         221.4             195.1
       Refund of non-qualified
        decommissioning trust                         (0.5)            (70.6)
       Weston 3 outage expenses                        0.4             (22.7)
       Recovery of MISO Day 2 expenses                19.8               -
       Recoveries and refunds of other
        regulatory assets and liabilities             31.4              32.6
       Amortization of nonregulated
        customer contract intangibles                 13.3              21.0
       Net unrealized gains on
        nonregulated energy contracts                (15.8)            (59.5)
       Nonregulated lower of cost or
        market inventory adjustments                 167.3               7.0
       Bad debt expense                               76.8              39.1
       Pension and other postretirement expense       50.7              67.5
       Pension and other postretirement funding      (40.8)            (35.3)
       Deferred income taxes and
        investment tax credit                         62.4              66.8
       Gain on sale of investments                     -                (2.7)
       (Gain) loss on sale of property,
        plant, and equipment                          (1.2)              1.1
       Equity income, net of dividends               (15.1)              2.4
       Other                                          (3.9)            (22.5)
       Changes in working capital
          Receivables and unbilled revenues, net    (446.9)             51.3
          Inventories                               (312.0)           (172.9)
          Other current assets                      (124.6)              0.9
          Accounts payable                           (53.2)            (96.5)
          Other current liabilities                  (10.8)             55.3
    Net cash (used for) provided by
     operating activities                           (250.0)            238.5

    Investing Activities
    Capital expenditures                            (532.8)           (392.6)
    Proceeds from the sale or disposal of
     property, plant, and equipment                   31.1              15.6
    Purchase of equity investments and
     other acquisitions                              (37.8)            (66.5)
    Cash paid for transaction costs
     related to the PEC merger                         -               (14.4)
    Acquisition of natural gas operations
     in Michigan and Minnesota, net of
     liabilities assumed                               -                 1.9
    Restricted cash for repayment of long-term debt    -                22.0
    Cash paid for transmission interconnection       (17.4)            (23.9)
    Proceeds received from transmission
     interconnection                                  99.7               -
    Other                                              5.0               6.4
    Net cash used for investing activities          (452.2)           (451.5)

    Financing Activities
    Short-term debt, net                             569.7            (463.7)
    Issuance of notes payable                        155.7               -
    Proceeds from sale of borrowed natural gas       530.4             211.9
    Purchase of natural gas to repay
     natural gas loans                              (257.2)           (177.5)
    Issuance of long-term debt                       181.5             125.2
    Repayment of long-term debt                      (58.1)            (26.5)
    Payment of dividends
       Preferred stock                                (3.1)             (3.1)
       Common stock                                 (203.9)           (177.0)
    Issuance of common stock                           -                45.6
    Other                                             (3.7)              5.9
    Net cash provided by (used for)
     financing activities                            911.3            (459.2)

    Change in cash and cash equivalents -
     continuing operations                           209.1            (672.2)
    Change in cash and cash equivalents -
     discontinued operations
       Net cash used for operating activities          -              (109.3)
       Net cash provided by investing activities       3.8             799.5
    Change in cash and cash equivalents              212.9              18.0
    Cash and cash equivalents at
     beginning of year                                41.2              23.2
    Cash and cash equivalents at end of year        $254.1             $41.2



                         Integrys Energy Group, Inc.

   Diluted Earnings Per Share Information - Non-GAAP Financial Information

    Non-GAAP Financial Information

Integrys Energy Group prepares financial statements in accordance with accounting principles generally accepted in the United States (GAAP). Along with this information, we disclose and discuss diluted earnings per share (EPS) from continuing operations -- adjusted, which is a non-GAAP measure. Management uses the measure in its internal performance reporting and for reports to the Board of Directors. We disclose this measure in our quarterly earnings releases, on investor conference calls, and during investor conferences and related events. Management believes that diluted EPS from continuing operations -- adjusted is a useful measure for providing investors with additional insight into our operating performance because it eliminates the effects of certain items that are not comparable from one period to the next. Therefore, this measure allows investors to better compare our financial results from period to period. The presentation of this additional information is not meant to be considered in isolation or as a substitute for our results of operations prepared and presented in conformance with GAAP.



    Actual Quarter and Year Ended December 31, 2008 and 2007

                                  Three Months Ended            Year Ended
                                      December 31               December 31
                                   2008         2007         2008         2007
    Diluted EPS from
     continuing operations        $0.27        $1.19        $1.58        $2.48
    Diluted EPS from
     discontinued operations       0.06       (0.08)         0.06         1.02
      Total Diluted EPS           $0.33        $1.11        $1.64        $3.50
      Average Shares of
       Common Stock - Diluted      77.0         76.6         77.0         71.8


Information on Special Items:

Diluted earnings per share from continuing operations, as adjusted for special items and their financial impact on diluted earnings per share from continuing operations for the three months and year ended December 31, 2008 and 2007 are as follows:

    Diluted EPS from continuing
     operations                     $0.27       $1.19     $1.58      $2.48

    Adjustments (net of taxes):
    Gain on asset sale                  -           -         -     (0.02)
    Goodwill impairment                 -           -      0.08          -
    Integrys Energy Services'
     power contract in Maine
     liquidated in 2005                 -           -         -       0.01
    External transition costs
     related to Peoples
     Energy merger                   0.02        0.05      0.09       0.15
    Impact of purchase accounting
     adjustments due to Peoples
     Energy merger                   0.01        0.08      0.09       0.14
    Synfuel - realized and
     unrealized oil option
     gains/losses, tax credits,
     production costs, premium
     amortization, deferred
     gain recognition, and royalties    -       (0.07)    (0.01)     (0.24)
      Diluted EPS from continuing
       operations - adjusted        $0.30       $1.25     $1.83      $2.52

    Weather impact - regulated
     utilities (as compared
     to normal)
    Electric impact -
     favorable/(unfavorable)        $0.01       $0.01     $0.02      $0.03
    Gas impact -
     favorable/(unfavorable)         0.03       (0.04)     0.14      (0.16)
      Total weather impact          $0.04      $(0.03)    $0.16     $(0.13)



                         Integrys Energy Group, Inc.

   Diluted Earnings Per Share Information - Non-GAAP Financial Information

    2009 Forecast
                                                     Potential 2009 Diluted
                                                           EPS Ranges

                                                       Low           High
                                                    Scenario       Scenario
    Diluted EPS from continuing operations             $2.51          $2.66
    Diluted EPS from discontinued operations               -              -
      Total Diluted EPS                                $2.51          $2.66
      Average Shares of Common Stock - Diluted          77.4           77.4

Information on Special Items:

Diluted earnings per share from continuing operations, as adjusted for special items and their financial impact on the 2009 diluted earnings per share from continuing operations guidance are as follows:

    Diluted EPS from continuing operations             $2.51          $2.66

    Adjustments (net of taxes):
    External transition costs related to
     Peoples Energy merger                              0.04           0.04
    Impact of purchase accounting adjustments
     due to Peoples Energy merger                      (0.02)         (0.02)
      Diluted EPS from continuing
       operations - adjusted                           $2.53          $2.68

    * Key Assumptions for 2009:
    -- Normal weather conditions
    -- Availability of generation units
    -- Reasonable rate relief for certain utilities
    -- Excludes the impact of non-cash lower-of-cost-or-market inventory
       adjustments and derivative accounting mark-to-market volatility for all
       of 2009 (such mark-to-market volatility is expected to include about
       $29.6 million of non-cash after-tax gains for all of 2009 relating to
       contracts terminating in 2009 which had net non-cash after-tax losses
       recognized in 2008)

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