Ultra Petroleum Announces Third Quarter 2009 Financial Results, Record
Production and Industry-Leading Returns


    



    
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<p><location>HOUSTON</location>, <chron>Oct. 30</chron> /CNW/ -- Ultra Petroleum Corp. (NYSE:   UPL) continued to deliver strong financial and operating performance for the third quarter of 2009. Highlights for the quarter include:</p>
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    --  Record natural gas and crude oil production of 45.9 Bcfe, an increase
        of 27 percent from third quarter 2008
    --  Operating cash flow(1) of $172.6 million
    --  Earnings of $85.8 million, or $0.57 per diluted share - adjusted
    --  Per unit all-in costs of $2.48 per Mcfe, down 22 percent from the same
        period in 2008

    --  Superior returns in third quarter (adjusted): 71 percent cash flow
        margin, 35 percent net income margin, 59 percent return on equity, and
        26 percent return on capital


    
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<p>For the third quarter of 2009, production of natural gas and crude oil increased 27 percent to a record 45.9 billion cubic feet equivalent (Bcfe) as compared to 36.3 Bcfe during the third quarter of 2008. Ultra Petroleum's third quarter 2009 production levels were the highest quarterly levels ever achieved by the company. The company's production for the third quarter was comprised of 43.9 billion cubic feet (Bcf) of natural gas and 341.5 thousand barrels of condensate (MBbls).</p>
<p/>
<p>Ultra Petroleum reported operating cash flow(1) for the third quarter of <money>$172.6 million</money>. Adjusted net income was <money>$85.8 million</money>, or <money>$0.57</money> per diluted share for the quarter. Due to a non-cash unrealized mark-to-market charge of <money>$145.0 million</money> (<money>$94.1 million</money> after tax) on the company's financial commodity contracts, the company reported a loss of <money>$8.3 million</money>, or (<money>$0.06</money>) per diluted share. The unrealized loss on commodity derivative contracts is typically excluded by the investment community in published estimates.</p>
<p/>
<p>"Once again, Ultra Petroleum's profitable growth strategy delivers. The company organically grew production by 27 percent while simultaneously decreasing all-in costs 22 percent to <money>$2.48</money> per Mcfe from the same quarter in 2008. While the industry continued to experience low natural gas prices during the quarter, our returns and margins remain similar to ones achieved last year in a more robust commodity price environment. This is a true testament to our world-class legacy asset coupled with our industry-leading low-cost structure," stated Michael D. Watford, Chairman, President and Chief Executive Officer.</p>
<p/>
<p>During the third quarter of 2009, Ultra Petroleum's average realized natural gas price was <money>$5.13</money> per thousand cubic feet (Mcf), including realized gains and losses on commodity derivatives. The company's average price for natural gas was <money>$3.09</money> per Mcf, excluding realized gains and losses on commodity derivatives. The realized condensate price in the third quarter of 2009 was <money>$57.47</money> per barrel (Bbl).</p>
<p/>
<p>Natural gas and crude oil production for the nine month period ended <chron>September 30, 2009</chron> increased to 132.5 Bcfe compared to 104.6 Bcfe for the nine month period ended <chron>September 30, 2008</chron>, a 27 percent increase. Production for the first nine months of 2009 was comprised of 126.5 Bcf of natural gas and 990.7 MBbls of condensate. Operating cash flow(1) for the nine month period was <money>$465.3 million</money>. Adjusted earnings for the nine month period ended <chron>September 30, 2009</chron> were <money>$203.7 million</money> or <money>$1.35</money> per diluted share.</p>
<p/>
<p>The realized natural gas price during the nine month period was <money>$4.89</money> per Mcf, including realized gains and losses on commodity derivatives. The company's average price for natural gas was <money>$3.24</money> per Mcf, excluding realized gains and losses on commodity derivatives. The realized condensate price was <money>$44.42</money> per Bbl.</p>
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    Wyoming - Operational Highlights

    
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<p>In the third quarter of 2009, 67 Pinedale-Lance wells were placed on production, including 31 operated by Ultra. The average initial production rate (IP) for the 31 Ultra-operated Pinedale wells was 10,356 Mcf per day. The average of all Ultra-interest wells was 8,508 Mcf per day, while the average of the Ultra non-operated wells was 6,917 Mcf per day.</p>
<p/>
<p>The table below details the IP rates for Ultra's operated wells during the third quarter of 2009.</p>
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<p> </p>
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                      Pinedale Well Performance - Ultra Operated
                      ------------------------------------------
        Area               Well Name            IP (Mcf per day)
        ----               ---------            ----------------
        Mesa              MS 5D1-34D                 13,654
        Mesa              MS 6B1-34D                 10,765
        Mesa              MS 16D1-33D                10,261
        Mesa              MS 13D1-27D                 7,902
        Mesa              MS 14C1-27D                11,336
        Mesa              MS 16D1-34D                12,135
        Mesa              MS 8C1-35D                  2,339
        Mesa              MS 16A1-34D                11,028
        Mesa              MS 15A1-34D                13,377
        Mesa              MS 9D1-34D                  8,214
        Mesa              MS 16C1-34D                14,074
        Mesa              MS 16A1-27D                10,524
        Mesa              MS 16D1-27D                11,532
        Riverside         RS 15D1-3D                 14,614
        Riverside         RS 2B2-2D                   7,703
        Riverside         RS 1C1-10D                 10,620
        Riverside         RS 16D1-3D                 10,678
        Riverside         RS 8D1-4D                   4,134
        Riverside         RS 1A1-10D                 14,053
        Riverside         RS 1A1-4D                  12,489
        Riverside         RS 2A1-10D                 13,646
        Riverside         RS 7C2-2D                   7,400
        Riverside         RS 16C1-3D                 14,622
        Riverside         RS 7A2-2D                   9,757
        Riverside         RS 1B1-10D                  8,426
        Riverside         RS 8D1-10D                 11,120
        Riverside         RS 1A1-2D                  10,338
        Riverside         RS 1B1-2D                   7,948
        Riverside         RS 2B2-10D                 12,014
        Riverside         RS 8B1-4D                   4,136
        Riverside         RS 8A1-10D                 10,187
                                                     ------
    Average Q3 2009 IP                               10,356


    
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<p>The increase in IP rates during 2009, as compared to 2008, corresponds to an increase in the average reserve size of Pinedale wells drilled in the year. The larger IPs are a direct benefit of the company gaining year-round access to development areas in better parts of the Pinedale field where the wells are more productive, leading to higher average per-well reserve estimates. The table below details the increase in average estimated ultimate recovery (EUR) of Ultra-operated wells completed, by quarter, since 2008.</p>
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<p> </p>
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                    Ultra-Operated Average EUR (Bcfe)
                 ---------------------------------------
                  Q1          Q2          Q3          Q4
                 ---         ---         ---         ---
    2008         4.1         3.2         4.4         6.7
    2009         6.2         6.9         6.4           -


    
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<p>The third quarter 2009 average drilling days for Ultra-operated wells as measured by spud to total depth (TD) was 18 days. Well costs also decreased to <money>$5.0 million</money>, as compared to <money>$5.6 million</money> in the third quarter of 2008. This 11 percent reduction in well costs is a direct result of fewer drilling days, fewer rig moves associated with pad drilling, and lower cost of services.</p>
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<p> </p>
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                                          Improving Efficiencies
                              ---------------------------------------------
                              2006  2007   2008 Q1 2009    Q2 2009  Q3 2009
                              ----  ----   ---- -------    -------  -------
     Spud to TD (days)         61    35     24      23         21       18
     Rig release to
      rig release (days)       79    48     32      31         24       23
     % wells drilled in
      < 30 days                 0%   36%    84%     78%        84%      92%
     % wells drilled
      < 20 days                 0%    2%    27%     33%        74%      84%
     Well cost - pad ($MM)   $7.0  $6.2   $5.5    $5.5      $5.25     $5.0


    
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<p>"Our well costs continued to decrease during the third quarter. We achieved our year-end goal of <money>$5.0 million</money> per well earlier than targeted. These cost reductions were accomplished while simultaneously drilling deeper wells and completing more frac stages per well," stated Watford.</p>
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    Pennsylvania - Operational Highlights

    
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<p>During the third quarter, Ultra drilled 12 horizontal Marcellus wells, with an average lateral length of just over 4,000 feet. Another 15 to 20 horizontal Marcellus Shale wells are planned to be drilled during the fourth quarter. This brings the range of the total number of horizontal Marcellus Shale wells that Ultra plans to drill in 2009 to between 34 to 39.  The company's first production in the Marcellus horizontal program began in late <chron>July 2009</chron>. During the quarter, seven wells were brought on-line with IPs averaging 6,420 Mcf per day. The company's four pipeline interconnects to major interstate pipelines remain on schedule and well ahead of the drilling campaign, with a total capacity of over 300 MMcf per day expected by year-end 2009.</p>
<p/>
<p>"We continue to be very pleased with the early results from our Marcellus program. The handful of horizontal wells that we have completed so far have recorded IP rates ranging from 10,500 Mcf per day to 3,400 Mcf per day, including one of our early wells producing a 30-day average over 7,800 Mcf per day. Our drilling, completion and production activities are ramping up and we are preparing for a 2010 program that will exceed 100 horizontal Marcellus wells. In addition, we expect that our Marcellus production will access the traditionally higher value natural gas markets in the Northeast," stated Watford.</p>
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    Hedges - Derivative Contracts

    
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<p>The total volume of commodity derivative contracts for the remainder of 2009 is 18.8 Bcf at an average price of <money>$5.73</money> per Mcf. In 2010, the total volume is 98.3 Bcf at an average price of <money>$5.49</money> per Mcf and in 2011 the total volume is 73.0 Bcf at an average price of <money>$5.61</money> per Mcf.</p>
<p/>
<p>"Our large hedge position for 2010 and 2011 underpins our excellent economics in Wyoming. Our hedged volumes along with our 73 Bcf of annual firm transportation on Rockies Express, that will access Northeast markets by the end of this year, create a solid foundation for financial success," stated Watford.</p>
<p/>
<p>As of today, Ultra Petroleum has the following positions in place to mitigate its commodity price exposure:</p>
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<p> </p>
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                    Total Volume       Average Price per Mcf
                       (Bcf)             at Point of Sale
                       -----           ---------------------
    
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<p> </p>
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    Q4 2009            18.8                 $5.73  Mcf
    -------            ----
    Total 2009         18.8                 $5.73  Mcf
    
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<p> </p>
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    Q1 2010            21.6                 $5.51  Mcf
    Q2 2010            26.4                 $5.48  Mcf
    Q3 2010            26.7                 $5.48  Mcf
    Q4 2010            23.6                 $5.50  Mcf
    -------            ----
    Total 2010         98.3                 $5.49  Mcf
    
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<p> </p>
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    Q1 2011            18.0                 $5.61  Mcf
    Q2 2011            18.2                 $5.61  Mcf
    Q3 2011            18.4                 $5.61  Mcf
    Q4 2011            18.4                 $5.61  Mcf
    -------            ----
    Total 2011         73.0                 $5.61  Mcf


    Rockies Express Pipeline (REX) Update

    
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<p>The final phase of REX from <location>Lebanon</location>, Ohio to Clarington, Ohio is expected to be in service during <chron>November 2009</chron>. Natural gas delivered to the final phase in Clarington, Ohio is expected to generally receive prices which are referenced to Dominion South pricing. The capacity on the pipeline is 1.8 Bcf per day.</p>
<p/>
<p>The table below provides a historical and future perspective on average annual basis differentials for Wyoming gas (NW Rockies) and premium markets in the Northeast (Dominion South). The basis differential is expressed as a percentage of Henry Hub.</p>
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<p> </p>
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                         Basis Differential as a Percentage (%) of Henry Hub
                    ---------------------------------------------------------
                                            2009       2009
                    2006    2007    2008     YTD     Balance    2010     2011
                    ----    ----    ----   -------  ---------   ----     ----
    NW Rockies        78      57      68       74         94      90       90
    Dominion South   104     106     106      107        107     104      103


    
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<p>"The basis table above highlights the significant improvement in Rockies prices. NW Rockies basis had historically been wide since 2005 and has decreased significantly for the balance of 2009 and more so in 2010 and 2011. Dominion South basis is forecasted to moderate slightly. With our 2010 and 2011 natural gas sales targeted at 50 percent sold into each market, Ultra's effective basis to Henry Hub pricing is expected to be 96 to 97 percent," stated Watford.</p>
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    Production Guidance

    
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<p>Ultra Petroleum's previous annual production guidance for 2009 was 172 to 177 Bcfe. At our current production rate, we expect to exceed the upper end of this range. As a result, production is expected to increase at least 22 percent over 2008's record annual production of 145.3 Bcfe.</p>
<p/>
<p>The company's preliminary production guidance for 2010 and 2011 is 15 to 20 percent per annum growth.</p>
<p/>
<p>"We continue to pursue a conservative and disciplined capital program that is consistent with our long-term strategy of balancing growth and profitability," stated Watford. "Ultra's legacy Wyoming field warrants growth and profitable re-investment throughout the energy cycle. Further, we are excited with early results from our first horizontal Marcellus wells that we have recently brought on production. We own long-term assets and believe that long-term commodity price assumptions drive value, not near-term commodity prices," Watford added.</p>
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    Price Realizations and Differentials Guidance

    
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<p>In the fourth quarter of 2009, the company's realized natural gas price is expected to average 4 to 6 percent below the NYMEX price, before consideration of any hedging activity, due to regional differentials. Realized pricing for condensate is expected to be about <money>$10.00</money> less than the average NYMEX crude oil price.</p>
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    Expense Guidance

    
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<p>The following table presents the company's expected expenses per Mcfe assuming a <money>$4.92</money> per Mcf Henry Hub natural gas price and a <money>$75.40</money> per Bbl NYMEX crude oil price:</p>
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<p> </p>
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    Costs Per Mcfe                             Q4 2009
    --------------                             -------
    Lease operating expenses                 $0.23 - 0.26
    Production taxes                         $0.55 - 0.57
    Gathering fees                           $0.25 - 0.27
    Transportation charges                   $0.34 - 0.36
    Depletion and depreciation               $1.07 - 1.09
    General and administrative - total       $0.12 - 0.13
    Interest and debt expense                $0.21 - 0.22
                                             ------------
    Total costs per Mcfe                     $2.77 - 2.90


    Income Tax Guidance

    
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<p>For the year, Ultra projects a 35.1 percent effective tax rate (based on adjusted net income) with approximately 11 to 13 percent of that amount expected to be currently payable.</p>
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    Conference Call Webcast Scheduled for October 30, 2009

    
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<p>Ultra Petroleum's third quarter 2009 conference call will be available via live audio webcast at <chron>11:00 a.m. Eastern Daylight Time</chron> (<chron>10:00 a.m. Central Daylight Time</chron>) <chron>Friday, October 30, 2009</chron>. To listen to this webcast, log on to <a href="http://www.ultrapetroleum.com">www.ultrapetroleum.com</a>. The webcast replay and podcast will be archived on Ultra Petroleum's website through <chron>February 19, 2010</chron>.</p>
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    About Ultra Petroleum

    
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<p>Ultra Petroleum Corp. is an independent exploration and production company focused on developing its long-life natural gas reserves in the Green River Basin of Wyoming - the Pinedale and <person>Jonah Fields</person>; and is in the early stages of exploration in the Appalachian Basin in Pennsylvania. Ultra is listed on the New York Stock Exchange and trades under the ticker symbol "UPL".  The company had 151,442,194 shares outstanding on <chron>September 30, 2009</chron>.</p>
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<p> </p>
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    Ultra Petroleum Corp.
    Consolidated Statement of Operations (unaudited)
    All amounts expressed in US$000's
    
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<p> </p>
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                        -------------------------     ---------------------
                        For the Nine Months Ended     For the Quarter Ended
                               September 30,               September 30,
                        -------------------------     ---------------------
                            2009           2008          2009         2008
                        -----------     ---------     ----------   --------
    
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<p> </p>
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    Volumes
         Oil liquids
          (Bbls)            990,728        817,272       341,485     287,115
         Natural
          gas (Mcf)     126,533,349     99,739,892    43,851,036  34,558,450
                        -----------     ----------    ----------  ----------
         MCFE -
          Total         132,477,717    104,643,524    45,899,946  36,281,140
                        -----------    -----------    ----------  ----------
    
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<p> </p>
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    Revenues
         Oil sales          $44,012        $83,863       $19,626     $31,054
         Natural
          gas sales         409,446        793,140       135,538     266,573
                            -------        -------       -------     -------
     Total operating
      revenues              453,458        877,003       155,164     297,627
                            -------        -------       -------     -------
    
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<p> </p>
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    Expenses
         Lease operating
          expenses           30,128         27,800         9,741       8,501
         Production
          taxes              45,309         98,336        15,220      31,625
         Gathering fees      33,753         27,621        11,389       8,857
                             ------         ------        ------       -----
     Total lease
      operating costs       109,190        153,757        36,350      48,983
                            -------        -------        ------      ------
    
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<p> </p>
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         Transportation
          charges            42,824         33,101        16,284      11,431
         Depletion
          and depreciation  152,002        130,681        46,367      45,652
         Write-down
          of proved
          oil and gas
          properties      1,037,000              -             -           -
         General
          and
          administrative      7,731          8,176         2,325       2,138
         Stock
          compensation        7,623          4,860         2,805       2,104
                              -----          -----         -----       -----
     Total operating
      expenses            1,356,370        330,575       104,131     110,308
                          ---------        -------       -------     -------
    
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<p> </p>
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     Other (expense)
      income, net            (2,925)           783           193          92
     Interest
      and debt
      expense               (26,938)       (14,997)       (9,744)     (5,183)
     Realized
      gain on
      commodity
      derivatives           209,180          3,083        89,620      17,202
     Unrealized (loss)
      gain on commodity
      derivatives          (118,879)        15,765      (145,048)     40,915
                           --------         ------      --------      ------
     (Loss) income
      before income
      taxes                (842,474)       551,062       (13,946)    240,345
    
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<p> </p>
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     Income tax provision
      (benefit) - current     7,695          4,530         7,672       4,723
     Income tax
      (benefit)
      provision
      - deferred           (303,724)       197,350       (13,288)     86,647
                           --------        -------      --------      ------
    
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<p> </p>
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     Net (loss)
      income              $(546,445)      $349,182       $(8,330)   $148,975
                          ---------       --------      --------    --------
    
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<p> </p>
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     Impairment
      of proved
      oil and
      gas
      properties,
      net of tax           $673,013       $      -       $     -    $      -
     Unrealized
      loss
      (gain) on
      commodity
      derivatives,
      net of tax             77,152        (10,231)       94,136     (26,554)
                             ------       --------        ------     -------
     Adjusted
      net
      income               $203,720       $338,951       $85,806    $122,421
                           --------       --------       -------    --------
    
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<p> </p>
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     Operating
      cash
      flows (1)            $465,335       $665,893      $172,600    $242,462
                           --------       --------      --------    --------
    
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<p> </p>
<p>(1) (see non-GAAP reconciliation)</p>
<p> </p>
<p> </p>
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    Weighted average shares -
     basic                                 151,337  152,592  151,441  152,217
    Weighted average shares -
     diluted                               151,337  157,326  151,441  156,072
    
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<p> </p>
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    Earnings per share
         Net income - basic                 ($3.61)   $2.29   ($0.06)   $0.98
         Net income - fully diluted         ($3.61)   $2.22   ($0.06)   $0.95
    
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<p> </p>
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    Adjusted earnings per share
         Adjusted net income - basic         $1.35    $2.22    $0.57    $0.80
         Adjusted net income - fully
          diluted (4)                        $1.35    $2.15    $0.57    $0.78
    
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<p> </p>
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    Realized Prices
         Oil liquids (Bbls)                 $44.42  $102.61   $57.47  $108.16
         Natural gas (Mcf), including
          realized gain (loss) on
          commodity derivatives              $4.89    $7.98    $5.13    $8.21
         Natural gas (Mcf), excluding
          realized gain (loss) on
          commodity derivatives              $3.24    $7.95    $3.09    $7.71
    
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<p> </p>
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    Costs Per MCFE
         Lease operating expenses            $0.23    $0.27    $0.21    $0.23
         Production taxes                    $0.34    $0.94    $0.33    $0.87
         Gathering fees                      $0.25    $0.26    $0.25    $0.24
         Transportation charges              $0.32    $0.32    $0.35    $0.32
         Depletion and depreciation          $1.15    $1.25    $1.01    $1.26
         General and administrative -
          total                              $0.12    $0.12    $0.11    $0.12
         Interest and debt expense           $0.20    $0.14    $0.21    $0.14
                                             -----    -----    -----    -----
                                             $2.61    $3.30    $2.48    $3.18
                                             -----    -----    -----    -----
      Note: Amounts on a per MCFE basis may not total due to rounding.
    
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<p> </p>
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    Adjusted Margins
         Adjusted Net Income (2)                31%      39%      35%     39%
         Adjusted Operating Cash Flow
          Margin (3)                            70%      76%      71%     77%
    
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<p> </p>
<p> </p>
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    Ultra Petroleum Corp.
    Supplemental Balance Sheet Data
    All amounts expressed in US$000's
                                                         As of
                                              ---------------------------
                                              September 30,  December 31,
                                              -------------  ------------
                                                   2009         2008
                                                   ----         ----
                                                (unaudited)
    Cash and cash equivalents                     $12,994      $14,157
    Long-term debt
        Bank indebtedness                         195,000      270,000
        Senior notes                              535,000      300,000
                                                  -------      -------
                                                 $730,000     $570,000
                                                 --------     --------



    
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<p> </p>
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    Ultra Petroleum Corp.
    Reconciliation of Cash Flow and Cash Provided by Operating Activities
    (unaudited)
    All amounts expressed in US$000's
    
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<p> </p>
<pre>
    
    The following table reconciles net cash provided by operating activities
    with operating cash flow as derived from the company's financial
    information. These statements are unaudited and subject to adjustment.
    
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<p> </p>
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                              For the Nine Months Ended For the Quarter Ended
                                       September 30,        September 30,
                                     -----------------  ---------------------
                                     2009         2008    2009        2008
                                     ----         ----    ----        ----
    Net cash provided by
     operating activities        $420,769     $708,186  $180,369    $304,846
      Net changes in operating
       assets and liabilities
       and other non-cash items*   44,566      (42,293)   (7,769)    (62,384)
                                 --------     --------  --------    --------
    Cash flow from operations
     before changes in operating
     assets and liabilities      $465,335     $665,893  $172,600    $242,462
                                 --------     --------  --------    --------
    
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<p> </p>
<pre>
    
    (1) Operating cash flow is defined as net cash provided by operating
    activities before changes in operating assets and liabilities. Management
    believes that the non-GAAP measure of operating cash flow is useful as an
    indicator of an oil and gas exploration and production company's ability
    to internally fund exploration and development activities and to service
    or incur additional debt. The company also has included this information
    because changes in operating assets and liabilities relate to the timing
    of cash receipts and disbursements which the company may not control and
    may not relate to the period in which the operating activities occurred.
    Operating cash flow should not be considered in isolation or as a
    substitute for net cash provided by operating activities prepared in
    accordance with GAAP.
    
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<p> </p>
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    (2) Adjusted Net Income Margin is defined as Adjusted Net Income divided
    by the sum of Oil and Natural Gas Sales plus Realized Gain (Loss) on
    Commodity Derivatives.
    
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<p> </p>
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    (3) Operating Cash Flow Margin is defined as Operating Cash Flow divided
    by the sum of Oil and Natural Gas Sales plus Realized Gain (Loss) on
    Commodity Derivatives.
    
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<p> </p>
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    (4) Fully diluted shares includes 2.8 million and 2.9 million potentially
    dilutive instruments that were anti-dilutive due to the net loss for the
    year-to-date and quarter periods ended September 30, 2009, respectively.
    
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<p> </p>
<pre>
    
    *Other non-cash items include excess tax benefit from stock based
    compensation and other.


    This release can be found at http://www.ultrapetroleum.com

    
</pre>
<p>This news release includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. The opinions, forecasts, projections or other statements, other than statements of historical fact, are forward-looking statements. Although the company believes that the expectations reflected in such forward-looking statements are reasonable, we can give no assurance that such expectations will prove to have been correct. Certain risks and uncertainties inherent in the company's businesses are set forth in our filings with the SEC, particularly in the section entitled "Risk Factors" included in our Annual Report on Form 10-K for our most recent fiscal year and from time to time in other filings made by us with the SEC. These risks and uncertainties include increased competition, the timing and extent of changes in prices for oil and gas, particularly in Wyoming, the timing and extent of the company's success in discovering, developing, producing and estimating reserves, the effects of weather and government regulation, availability of oil field personnel, services, drilling rigs and other equipment, and other factors listed in the reports filed by the company with the SEC. Full details regarding the selected financial information provided above will be available in the company's report on Form 10-Q for the quarter ended <chron>September 30, 2009</chron>.</p>
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For further information: For further information: Kelly L. Whitley, Manager Investor Relations of Ultra Petroleum Corp., +1-281-876-0120, Extension 302, info@ultrapetroleum.com Web Site: http://www.ultrapetroleum.com


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