EXHIBIT 99.1

For Information
Brent A. Collins
303-861-8140

FOR IMMEDIATE RELEASE

ST. MARY REPORTS RESULTS FOR SECOND QUARTER OF 2009


·  
Quarterly production of 28.2 BCFE exceeds guidance of 26.5 – 28.0 BCFE

·  
Reported expenses for lease operating, transportation, DD&A, and total general and administrative all below guidance

·  
Adjusted net income of $15.2 million or $0.24 per diluted share

·  
Non-cash charges and impairments result in a GAAP net loss of ($8.3 million), or ($0.13) per diluted share


DENVER, August 3, 2009 – St. Mary Land & Exploration Company (NYSE: SM) today reports financial results from the second quarter of 2009.


MANAGEMENT COMMENTARY

Tony Best, CEO and President, remarked, “St. Mary had a strong second quarter.  We beat our production targets and performed well against our cost guidance.  The Company successfully tested the Eagle Ford shale on its high working interest acreage in South Texas and continued to advance its other resource plays.    We continue to execute well on the business plan that we set out at the beginning of the year.”

SECOND QUARTER 2009 RESULTS

St. Mary posted a net loss for the second quarter of 2009 of ($8.3 million), a loss of ($0.13) per diluted share.  This compares to net income of $32.5 million, or $0.52 per diluted share, for the same period in 2008.  Adjusted net income for the quarter, which adjusts for significant non-recurring or unusual non-cash items, was $15.2 million, or $0.24 per diluted share, versus $80.5 million, or $1.28 per diluted share, for the second quarter of 2008.  A summary of the adjustments made to arrive at adjusted net income (loss) is presented in the table below.


 
 
 
 


   For the Three Months Ended June 30,
 
2009
     2008*  
Weighted-average diluted share count (in millions)
      62.4             62.7  
                         
 
$ in millions
Per Diluted Share
   
$ in millions
 
Per Diluted Share
 
Reported net income (loss)
$ (8.3 ) $ (0.13 )   $ 32.5   $ 0.52  
                           
After-tax adjustments, assuming effective tax rate for respective period
               
Change in Net Profits Plan liability
$ 1.5   $ 0.02     $ 43.3   $ 0.69  
Unrealized derivative (gain) loss
  7.0     0.11       (0.8 )   (0.01 )
Gain on sale of proved properties
  (0.8 )   (0.01 )     (1.9 )   (0.03 )
Loss related to hurricanes
  3.1     0.05       -     -  
Impairment of proved properties
  3.7     0.06       6.1     0.10  
Abandonment & impairment of unproved properties
  7.2     0.12       1.3     0.02  
Impairment of materials inventory
  1.7     0.03       -     -  
                           
Adjusted net income (loss)
$ 15.2   $ 0.24     $ 80.5   $ 1.28  
                           
NOTE: Totals may not add due to rounding
                         
                           
* On January 1, 2009, the Company adopted FASB Staff Position APB 14-1, "Accounting for Convertible Debt Instruments That May Be Settled in Cash Upon Conversion (Including Partial Cash Settlement)." This accounting pronouncement requires that its provisions be adopted retrospectively. Accordingly, the consolidated financial statements for presented prior periods have been restated to conform with this new accounting standard.
 

Discretionary cash flow decreased to $117.7 million for the second quarter of 2009 from $222.4 million in the same period last year.  Net cash provided by operating activities decreased to $116.6 million for the second quarter of 2009 from $173.8 million in the same period in 2008.  A major driver of the decrease year over year in each of these metrics was the significant decrease in oil and natural gas prices between those periods which is described in more detail below.

Adjusted net income and discretionary cash flow are non-GAAP financial measures – please refer to the respective reconciliation in the accompanying Financial Highlights section at the end of this release.

St. Mary reported quarterly production of 28.2 BCFE for the second quarter of 2009, which was above the guidance range of 26.5 to 28.0 BCFE.  The primary driver for this outperformance was better than projected results from the Company’s drilling program.  Production for the same period last year was 28.6 BCFE, which included 1.3 BCFE of production from assets that were later disposed of in 2008. Sequentially, production in the second quarter of 2009 was essentially flat with the preceding quarter.
 
2
 
 
 
 
 
Revenues for the quarter were $205.2 million compared to $356.9 million for the same period in 2008.  In the second quarter of 2009, the Company’s average equivalent price per MCFE, net of hedging, was $6.68 per MCFE, which is a decrease of 42% from the $11.61 per MCFE realized in the comparable period in 2008.  Average realized prices, excluding hedging activities, were $3.07 per Mcf of natural gas and $53.96 per barrel of oil during the quarter.  These prices were 72% and 55% lower, respectively, than those in the second quarter of 2008.  Average realized prices, inclusive of hedging activities, were $5.19 per Mcf of natural gas and $56.72 per barrel of oil in the second quarter of 2009, which is a decrease of 48% and 36%, respectively, from the same period a year ago.

Lease operating expense of $1.26 per MCFE in the second quarter of 2009 was below the Company’s guidance of $1.49 to $1.54 per MCFE.  This represents a 12% decrease from the $1.43 per MCFE in the comparable period last year.  Sequentially, lease operating expense declined 13% or $0.19 per MCFE in the second quarter of 2009 from the first quarter.  The Company is experiencing decreases in operating costs across most of its operating areas as a result of lower levels of activity in the industry as well as the broader economy.

Transportation expense of $0.16 per MCFE in the second quarter of 2009 was below guidance of $0.19 to $0.24 per MCFE.  The reported per unit expense was a decrease from $0.20 per MCFE for the comparative period in 2008.  Transportation expense was also down $0.03 per MCFE from the first quarter of 2009.

Significant commodity price decreases over the past year for both oil and natural gas resulted in year over year declines in production taxes, both on a per MCFE basis and in absolute dollars.   Between the second quarters of 2009 and 2008, production taxes on a per MCFE basis decreased 65% from $0.95 to $0.33.  Production taxes increased sequentially from $0.32 per MCFE in the first quarter to $0.33 per MCFE in the second quarter of 2009.  The Company’s results for the second quarter were within the guidance range of $0.28 to $0.33 per MCFE provided for the quarter.

Total general and administrative expense for the second quarter of 2009 was $0.64 per MCFE, representing a 17% decrease from the $0.77 per MCFE recognized in the comparable quarter a year ago.  The guidance range for total G&A expense for the quarter was $0.71 to $0.78 per MCFE.  The decrease year over year relates primarily to smaller payments to participants in the legacy Net Profits Plan, which was affected by lower commodity prices realized in the second quarter of 2009.  Offsetting a portion of these decreases were increases between the periods in costs associated with higher headcount, such as salary and office space, related to personnel additions made throughout 2008.

Depletion and depreciation expense decreased to $2.49 per MCFE in the second quarter of 2009, which was well below the Company’s guidance range of $2.90 to $3.10 per MCFE.  DD&A in the comparable period of 2008 was $2.67 per MCFE.  
 
3
 
 
 
 

Sequentially, DD&A decreased 23% from $3.23 per MCFE in the first quarter of 2009.  The decrease in DD&A in the second quarter is largely a function of the Company’s decision to market for sale certain non-strategic natural gas properties.  These properties have a higher per unit DD&A than the Company’s average DD&A per MCFE.  Accounting rules do not permit assets held for sale to be depleted, and as a result the entity-wide DD&A per MCFE rate went down.  Additionally, property impairments recognized in prior quarters have meaningfully lowered the cost basis of the Company’s properties, which also puts downward pressure on DD&A.
 
St. Mary recognized $6.0 million before income taxes in non-cash impairments for proved properties in the second quarter of 2009.  The majority of the proved property impairments related to offshore Gulf platforms in which St. Mary is relinquishing its ownership interests.  The Company also recognized $11.6 million for unproved properties in the second quarter of 2009, compared to $2.1 million in the same period in 2008.  The largest portion of the unproved property impairments in the current year related to Floyd Shale acreage located in Mississippi.  The Company also recognized an impairment of materials inventory for $2.7 million related to the write-down of tubular goods purchased in 2008 to current market value.

Exploration expense of $19.5 million was recognized in the second quarter of 2009, compared to $17.4 million in the same period in 2008.  The increase year over year reflects higher levels of geological and geophysical spending.

In the second quarter of 2009, St. Mary recognized a pre-tax non-cash expense of $2.4 million as a result of the increase in the Net Profits Plan liability, compared to $68.1 million in the second quarter of 2008.  This periodic expense is a reflection of change in the liability during the respective periods.  This liability is a significant management estimate and is highly sensitive to a number of assumptions including future commodity prices, production rates, and operating costs.  The last pool created under this legacy compensation plan was in 2007.
 
FINANCIAL POSITION AND LIQUIDITY

As of June 30, 2009, St. Mary had total long-term debt of $537.7 million, comprised of $275.0 million drawn under its existing long-term credit facility and $262.7 million in 3.50% Senior Convertible Notes, net of debt discount.  The credit facility matures in July of 2012 and the Senior Convertible Notes cannot be put to the Company’s until April of 2012.  The Company’s debt-to-book capitalization ratio was 35% as of the end of the quarter.

As of July 28, 2009, St. Mary had $255.0 million drawn on the revolver and had $421.7 million in unused borrowing capacity.  The Company’s next regularly scheduled borrowing base redetermination is scheduled for October of this year.

4
 
 
 
 
 
EARNINGS CALL INFORMATION

The Company has scheduled a teleconference to discuss the second quarter results on August 4, 2009 at 8:00 a.m. Mountain time (10:00 a.m. Eastern time).  The call participation number is 888-811-1227.  An audio replay of the call will be available approximately two hours after the call at 800-642-1687, conference number 16019326.  International participants can dial 706-679-9922 to take part in the conference call and can access a replay of the call at 706-645-9291, conference number 16019326.  Replays can be accessed through August 11, 2009.

In addition, the call will be webcast live and can be accessed at St. Mary’s web site at www.stmaryland.com.  An audio recording of the conference call will be available at that site through August 11, 2009.

INFORMATION ABOUT FORWARD LOOKING STATEMENTS

This release contains forward looking statements within the meaning of securities laws, including forecasts and projections.  The words “will,” “believe,” “budget,” “anticipate,” “plan,” “intend,” “estimate,” “forecast,” and “expect” and similar expressions are intended to identify forward looking statements.  These statements involve known and unknown risks, which may cause St. Mary’s actual results to differ materially from results expressed or implied by the forward looking statements.  These risks include such factors as the volatility and level of oil and natural gas prices, the uncertain nature of the expected benefits from the acquisition and divestiture of oil and gas properties, uncertainties inherent in projecting future rates of production from drilling activities and acquisitions, the ability of purchasers of production to pay for those sales, the availability of debt and equity financing, the ability of the banks in the Company’s credit facility to fund requested borrowings, the ability of hedge counterparties to settle hedges in favor of the Company, the imprecise nature of estimating oil and gas reserves, the availability of additional economically attractive exploration, development, and property acquisition opportunities for future growth and any necessary financings, unexpected drilling conditions and results, unsuccessful exploration and development drilling, drilling and operating service availability, the risks associated with the Company’s hedging strategy, and other such matters discussed in the “Risk Factors” section of St. Mary’s 2008 Annual Report on Form 10-K and subsequent quarterly reports filed on Form 10-Q.  Although St. Mary may from time to time voluntarily update its prior forward looking statements, it disclaims any commitment to do so except as required by securities laws.
 
5
 
 
 
 


 
ST. MARY LAND & EXPLORATION COMPANY
FINANCIAL HIGHLIGHTS
June 30, 2009
                       
                       
Production Data
For the Three Months
     
For the Six Months
   
 
Ended June 30,
     
Ended June 30,
   
 
2009
 
2008
  Percent Change
 
2009
 
2008
 
Percent Change
                       
Average realized sales price, before hedging:
                     
Oil (per Bbl)
 $                   53.96
 
 $              120.20
 
-55%
 
 $                    44.21
 
 $                 106.17
 
-58%
Gas (per Mcf)
                        3.07
 
                   10.83
 
-72%
 
                         3.54
 
                        9.69
 
-63%
                       
Average realized sales price, net of hedging:
                     
Oil (per Bbl)
 $                   56.72
 
 $                88.40
 
-36%
 
 $                    50.45
 
 $                   82.28
 
-39%
Gas (per Mcf)
                        5.19
 
                     9.97
 
-48%
 
                         5.66
 
                        9.33
 
-39%
         
 
         
 
Production:
                     
Oil (MMBbls)
                          1.6
 
                       1.6
 
0%
 
                           3.3
 
                          3.3
 
-1%
Gas (Bcf)
                        18.3
 
                     18.7
 
-2%
 
                         36.8
 
                        37.0
 
0%
BCFE (6:1)
                        28.2
 
                     28.6
 
-1%
 
                         56.6
 
                        56.9
 
-1%
                       
Daily production:
                     
Oil (MBbls per day)
                        18.1
 
                     18.1
 
0%
 
                         18.2
 
                        18.2
 
0%
Gas (MMcf per day)
                      201.4
 
                   205.3
 
-2%
 
                       203.6
 
                      203.4
 
0%
MMCFE per day (6:1)
                      310.1
 
                   313.7
 
-1%
 
                       312.6
 
                      312.6
 
0%
                       
Margin analysis per MCFE:
                     
Average realized sales price, before hedging
 $                     5.15
 
 $                14.01
 
-63%
 
 $                      4.87
 
 $                   12.49
 
-61%
                       
Average realized sales price, net of hedging
  $                     6.68
 
  $                11.61
 
-42%
 
 $                      6.62
 
  $                   10.86
 
-39%
Lease operating expense
                        1.26
 
                     1.43
 
-12%
 
                         1.36
 
                        1.33
 
2%
Transportation
                        0.16
 
                     0.20
 
-20%
 
                         0.18
 
                        0.17
 
6%
Production taxes
                        0.33
 
                     0.95
 
-65%
 
                         0.33
 
                        0.84
 
-61%
General and administrative
                        0.64
 
                     0.77
 
-17%
 
                         0.61
 
                        0.76
 
-20%
Operating margin
 $                     4.29
 
 $                  8.26
 
-48%
 
 $                      4.14
 
 $                     7.76
 
-47%
Depletion, depreciation, amortization, and
                     
asset retirement obligation liability accretion
 $                     2.49
 
 $                  2.67
 
-7%
 
 $                      2.87
 
 $                     2.58
 
11%
 
 
 
 
 
 

 
ST. MARY LAND & EXPLORATION COMPANY
FINANCIAL HIGHLIGHTS
June 30, 2009
                 
NOTE: On January 1, 2009, the Company adopted Financial Accounting Standards Board Staff Position Accounting Principles
 
Board 14-1, “Accounting for Convertible Debt Instruments That May Be Settled in Cash Upon Conversion (Including Partial Cash
 
Settlement)” (“FSP APB 14-1”), which required retrospective application.  As a result, prior period balances presented have been adjusted to
 
reflect the period-specific effects of applying FSP APB 14-1.
             
                 
Consolidated Statements of Operations
               
(In thousands, except per share amounts)
For the Three Months
 
For the Six Months
 
 
Ended June 30,
 
Ended June, 30,
 
 
2009
 
2008
 
2009
 
2008
 
     
(As adjusted)
     
(As adjusted)
 
Operating revenues and other income:
               
Oil and gas production revenue
$ 145,279   $ 399,961   $ 275,696   $ 710,393  
Realized oil and gas hedge gain (loss)
  43,279     (68,396 )   98,899     (92,346 )
Gain on sale of proved properties
  1,244     3,038     645     59,055  
Marketed gas system and other operating revenue
  15,396     22,339     29,178     41,942  
Total operating revenues and other income
  205,198     356,942     404,418     719,044  
                         
Operating expenses:
                       
Oil and gas production expense
  49,465     73,625     105,294     133,101  
Depletion, depreciation, amortization,
                       
and asset retirement obligation liability accretion
  70,391     76,354     162,103     146,708  
Exploration
  19,490     17,401     33,088     31,709  
Impairment of proved properties
  6,043     9,566     153,092     9,566  
Abandonment and impairment of unproved properties
  11,631     2,056     15,533     3,064  
Impairment of materials inventory
  2,719     -     11,335     -  
General and administrative
  18,160     21,867     34,559     43,004  
Bad debt expense
  -     9,951     -     9,942  
Change in Net Profits Plan liability
  2,449     68,142     (20,842 )   81,768  
Marketed gas system expense
  13,609     20,213     26,992     37,958  
Unrealized derivative (gain) loss
  11,288     (1,186 )   13,134     5,231  
Other expense
  5,814     702     11,456     1,402  
Total operating expenses
  211,059     298,691     545,744     503,453  
                         
Income (loss) from operations
  (5,861 )   58,251     (141,326 )   215,591  
 
                       
Nonoperating income (expense):
                       
Interest income
  105     59     127     156  
Interest expense
  (7,663 )   (7,243 )   (13,759 )   (13,836 )
                         
Income (loss) before income taxes
  (13,419 )   51,067     (154,958 )   201,911  
Income tax benefit (expense)
  5,097     (18,598 )   59,013     (74,468 )
                         
Net income (loss)
$ (8,322 ) $ 32,469   $ (95,945 ) $ 127,443  
                         
Basic weighted-average common shares outstanding
  62,418     61,714     62,377     62,287  
                         
Diluted weighted-average common shares outstanding
  62,418     62,749     62,377     63,404  
                         
Basic net income (loss) per common share
$ (0.13 ) $ 0.53   $ (1.54 ) $ 2.05  
                         
Diluted net income (loss) per common share
$ (0.13 ) $ 0.52   $ (1.54 ) $ 2.01  
 
 
 
 
 
 

 
ST. MARY LAND & EXPLORATION COMPANY
FINANCIAL HIGHLIGHTS
June 30, 2009
         
Consolidated Balance Sheets
       
(In thousands, except share amounts)
June 30,
 
December 31,
 
ASSETS
2009
 
2008
 
     
(As adjusted)
 
Current assets:
       
Cash and cash equivalents
$ 10,389   $ 6,131  
Short-term investments
  -     1,002  
Accounts receivable, net of allowance for doubtful accounts
       
of $16,941 in 2009 and $16,788 in 2008
  108,384     157,690  
Refundable income taxes
  -     13,161  
Prepaid expenses and other
  14,111     22,161  
Accrued derivative asset
  67,143     111,649  
Total current assets
  200,027     311,794  
             
Property and equipment (successful efforts method), at cost:
       
Land
  1,371     1,350  
Proved oil and gas properties
  2,916,495     2,969,722  
Less - accumulated depletion, depreciation, and amortization
  (1,047,505 )   (947,207 )
Unproved oil and gas properties, net of impairment allowance
       
of $51,774 in 2009 and $42,945 in 2008
  156,011     168,817  
Wells in progress
  38,079     90,910  
Materials inventory, at lower of cost or market
  37,565     40,455  
Oil and gas properties held for sale less accumulated depletion,
       
depreciation, and amortization
  48,410     1,827  
Other property and equipment, net of accumulated depreciation
       
of $15,652 in 2009 and $13,848 in 2008
  15,274     13,458  
    2,165,700     2,339,332  
             
Other noncurrent assets:
           
Accrued derivative asset
  10,668     21,541  
Restricted cash subject to Section 1031 Exchange
  -     14,398  
Other noncurrent assets
  19,344     10,182  
Total other noncurrent assets
  30,012     46,121  
             
Total Assets
$ 2,395,739   $ 2,697,247  
             
LIABILITIES AND STOCKHOLDERS' EQUITY            
             
Current liabilities:
           
Accounts payable and accrued expenses
$ 207,342   $ 254,811  
Accrued derivative liability
  23,583     501  
Deferred income taxes
  16,938     41,289  
Total current liabilities
  247,863     296,601  
             
Noncurrent liabilities:
           
Long-term credit facility
  275,000     300,000  
Senior convertible notes, net of unamortized
           
discount of $24,763 in 2009, and $28,787 in 2008
  262,737     258,713  
Asset retirement obligation
  85,882     108,755  
Asset retirement obligation associated with oil and gas properties held for sale
  9,336     238  
Net Profits Plan liability
  156,524     177,366  
Deferred income taxes
  280,144     354,328  
Accrued derivative liability
  54,198     27,419  
Other noncurrent liabilities
  12,627     11,318  
Total noncurrent liabilities
  1,136,448     1,238,137  
             
Commitments and contingencies
           
             
Stockholders' equity:
           
Common stock, $0.01 par value: authorized - 200,000,000 shares;
       
issued: 62,622,664 shares in 2009 and 62,465,572 shares in 2008;
       
outstanding, net of treasury shares: 62,495,771 shares in 2009
       
and 62,288,585 shares in 2008
  626     625  
Additional paid-in capital
  145,972     141,283  
Treasury stock, at cost:  126,893 shares in 2009 and 176,987 shares in 2008
  (1,256 )   (1,892 )
Retained earnings
  858,135     957,200  
Accumulated other comprehensive income
  7,951     65,293  
Total stockholders' equity
  1,011,428     1,162,509  
             
Total Liabilities and Stockholders' Equity
$ 2,395,739   $ 2,697,247  
 
 
 
 
 
 
 
 
ST. MARY LAND & EXPLORATION COMPANY
FINANCIAL HIGHLIGHTS
June 30, 2009
                 
Consolidated Statements of Cash Flows
               
(In thousands)
For the Three Months
 
For the Six Months
 
 
Ended June 30,
 
Ended June 30,
 
 
2009
 
2008
 
2009
 
2008
 
Cash flows from operating activities:
   
(As adjusted)
     
(As adjusted)
 
Reconciliation of net income (loss) to net cash provided
               
by operating activities:
               
Net income (loss)
$ (8,322 ) $ 32,469   $ (95,945 ) $ 127,443  
Adjustments to reconcile net income (loss) to net cash
                       
provided by operating activities:
                       
Gain on sale of proved properties
  (1,244 )   (3,038 )   (645 )   (59,055 )
Depletion, depreciation, amortization,
                       
and asset retirement obligation liability accretion
  70,391     76,354     162,103     146,708  
Exploratory dry hole expense
  4,573     5,916     4,667     6,606  
Impairment of proved properties
  6,043     9,566     153,092     9,566  
Abandonment and impairment of unproved properties
  11,631     2,056     15,533     3,064  
Impairment of materials inventory
  2,719     -     11,335     -  
Stock-based compensation expense*
  3,733     3,747     7,509     7,057  
Bad debt expense
  -     9,942     -     9,942  
Change in Net Profits Plan liability
  2,449     68,142     (20,842 )   81,768  
Unrealized derivative (gain) loss
  11,288     (1,186 )   13,134     5,231  
Loss related to hurricanes
  5,027     -     7,120     -  
Amortization of debt discount and deferred financing costs
  3,611     2,760     5,703     4,606  
Deferred income taxes
  (7,758 )   5,273     (63,148 )   54,762  
Other
  93     (2,751 )   (736 )   876  
Changes in current assets and liabilities:
                       
Accounts receivable
  5,446     (30,618 )   49,149     (71,854 )
Refundable income taxes
  -     (9,854 )   13,161     (8,921 )
Prepaid expenses and other
  (1,677 )   (6,234 )   (7,091 )   (6,570 )
Accounts payable and accrued expenses
  8,583     19,992     (12,338 )   14,850  
Excess income tax benefit from the exercise of stock options
  -     (8,705 )   -     (9,565 )
Net cash provided by operating activities
  116,586     173,831     241,761     316,514  
                         
Cash flows from investing activities:
                       
Proceeds from sale of oil and gas properties
  18     24,197     1,081     154,597  
Capital expenditures
  (82,201 )   (168,136 )   (215,826 )   (329,666 )
Acquisition of oil and gas properties
  9     (9,896 )   (44 )   (62,927 )
Receipts from restricted cash
  10,050     -     14,398     -  
Deposits to restricted cash
  -     (25,266 )   -     (25,266 )
Deposits to short-term investments
  1,002     173     1,002     173  
Other
  -     20     -     (9,987 )
Net cash used in investing activities
  (71,122 )   (178,908 )   (199,389 )   (273,076 )
                         
Cash flows from financing activities:
                       
Proceeds from credit facility
  576,000     249,000     1,766,000     638,000  
Repayment of credit facility
  (600,000 )   (230,500 )   (1,791,000 )   (628,000 )
Debt issuance costs related to credit facility
  (11,060 )   -     (11,060 )   -  
Excess income tax benefit from the exercise of stock options
  -     8,705     -     9,565  
Proceeds from sale of common stock
  894     10,356     1,066     10,684  
Repurchase of common stock
  -     -     -     (77,202 )
Dividends paid
  (3,120 )   (3,076 )   (3,120 )   (3,076 )
Net cash provided by (used in) financing activities
  (37,286 )   34,485     (38,114 )   (50,029 )
                         
Net change in cash and cash equivalents
  8,178     29,408     4,258     (6,591 )
Cash and cash equivalents at beginning of period
  2,211     7,511     6,131     43,510  
Cash and cash equivalents at end of period
$ 10,389   $ 36,919   $ 10,389   $ 36,919  
                         
* Stock-based compensation expense is a component of exploration expense and general and administrative expense on the consolidated statements of
 
operations. For the six months ended June 30, 2009, and 2008, approximately $2.9 million and $2.2 million, respectively of stock-based compensation
 
expense was included in exploration expense. For the six months ended June 30, 2009, and 2008, approximately $4.6 million and $4.9 million, respectively
 
of stock-based compensation expense was included in general and administrative expense. For the three months ended June, 30, 2009, and 2008,
 
approximately $1.3 million and $1.1 million, respectively of stock-based compensation expense was included in exploration expense. For the three months
 
ended June, 30, 2009 and 2008, approximately $2.4 million and $2.7 million, respectively of stock-based compensation expense was included in
 
general and administrative expense.
                       

 
 
 
 
 
 
 
ST. MARY LAND & EXPLORATION COMPANY
FINANCIAL HIGHLIGHTS
June 30, 2009
                 
                 
Adjusted Net Income (Loss)
               
(In thousands, except per share data)
               
                 
Reconciliation of Net Income (Loss) (GAAP)
For the Three Months
 
For the Six Months
 
to Adjusted Net Income (Non-GAAP):
Ended June 30,
 
Ended June 30,
 
 
2009
 
2008
 
2009
 
2008
 
     
(As adjusted)
     
(As adjusted)
 
                 
Reported Net Income (Loss) (GAAP)
$ (8,322 $ 32,469   $ (95,945 ) $ 127,443  
                         
Adjustments:
                       
Change in Net Profits Plan liability
  2,449     68,142     (20,842 )   81,768  
Unrealized derivative (gain) loss
  11,288     (1,186 )   13,134     5,231  
Gain on sale of proved properties
  (1,244   (3,038 )   (645 )   (59,055 )
Loss related to hurricanes (1)
  5,027     -     7,120     -  
Tax adjustment at effective rate for period
  (6,655   (23,278 )   470     (10,306 )
                         
Adjusted Net Income (Loss), before impairment adjustments
  2,543     73,109     (96,708 )   145,081  
                         
Non-cash impairments:
                       
Impairment of proved properties
  6,043     9,566     153,092     9,566  
Abandonment and impairment of unproved properties
  11,631     2,056     15,533     3,064  
Impairment of materials inventory
  2,719     -     11,335     -  
Tax adjustment for impairments at effective rate for period
  (7,746   (4,233 )   (68,535 )   (4,658 )
Adjusted Net Income, non-recurring items
                       
& non-cash impairments (Non-GAAP) (2)
$ 15,190   $ 80,498   $ 14,717   $ 153,053  
                         
Adjusted Net Income Per Share (Non-GAAP)
                       
Basic
$ 0.24   $ 1.30   $ 0.24   $ 2.46  
Diluted
$ 0.24   $ 1.28   $ 0.24   $ 2.41  
                         
Average Number of Shares Outstanding
                       
Basic
  62,418     61,714     62,377     62,287  
Diluted
  62,418     62,749     62,377     63,404  
                         
                         
                         
(1) The loss related to hurricanes is included within line item other expense on the consolidated statements of operations.
 
                         
(2) Adjusted net income is calculated as net income (loss) adjusted for significant non-cash and non-recurring items. Non-cash charges and adjustments include
 
change in the Net Profits Plan liability, unrealized derivative (gain) loss, impairment of proved properties, abandonment and impairment of unproved properties, and
 
impairment of materials inventory. Non-recurring items include gain on sale of proved properties, and loss related to hurricanes. The non-GAAP measure of
 
adjusted net income is presented because management believes it provides useful additional information to investors for analysis of St. Mary’s fundamental
 
business on a recurring basis. In addition, management believes that adjusted net income is widely used by professional research analysts and others in the
 
valuation, comparison, and investment recommendations of companies in the oil and gas exploration and production industry, and many investors use the
 
published research of industry research analysts in making investment decisions. Adjusted net income should not be considered in isolation or as a substitute for
 
net income, income from operations, cash provided by operating activities or other income, profitability, cash flow, or liquidity measures prepared under GAAP.
 
Since adjusted net income excludes some, but not all, items that affect net income and may vary among companies, the adjusted net income amounts presented
 
may not be comparable to similarly titled measures of other companies.
                   

 
 
 
 
 

 
ST. MARY LAND & EXPLORATION COMPANY
FINANCIAL HIGHLIGHTS
June 30, 2009
                 
Discretionary Cash Flow
               
(In thousands)
               
                 
Reconciliation of Net Cash Provided by Operating Activities
For the Three Months
 
For the Six Months
 
(GAAP) to Discretionary Cash Flow (Non-GAAP):
Ended June 30,
 
Ended June 30,
 
 
2009
 
2008
 
2009
 
2008
 
     
(As adjusted)
     
(As adjusted)
Net cash provided by operating activities (GAAP)
$ 116,586   $ 173,831   $ 241,761   $ 316,514  
                         
Exploration
  19,490     17,401     33,088     31,709  
Less:  Exploratory dry hole expense
  (4,573 )   (5,916   (4,667 )   (6,606 )
Less:  Stock-based compensation expense included in exploration
  (1,309 )   (1,073   (2,864 )   (2,142 )
Other
  (93 )   2,751     736     (876 )
Changes in current assets and liabilities
  (12,352 )   35,419     (42,881 )   82,060  
Discretionary cash flow (Non-GAAP) (3)
$ 117,749   $ 222,413   $ 225,173   $ 420,659  
                         
                         
                         
(3) Discretionary cash flow is computed as net income (loss) adjusted for gain on sale of proved properties, loss related to hurricanes, depletion,
depreciation, amortization, and asset retirement obligation liability accretion, exploration, impairment of proved properties, abandonment and impairment of
unproved properties, unrealized derivative loss (gain), change in Net Profits Plan liability, stock-based compensation expense, amortization of debt discount,
impairment of materials inventory, and deferred income taxes. The non-GAAP measure of discretionary cash flow is presented since management believes
that it provides useful additional information to investors for analysis of St. Mary's ability to internally generate funds for exploration, development, and
acquisitions. In addition, discretionary cash flow is widely used by professional research analysts and others in the valuation, comparison, and investment
recommendations of companies in the oil and gas exploration and production industry, and many investors use the published research of industry research
analysts in making investment decisions. Discretionary cash flow should not be considered in isolation or as a substitute for net income, income from
operations, net cash provided by operating activities or other income, profitability, cash flow, or liquidity measures prepared under GAAP. Since
discretionary cash flow excludes some, but not all items that affect net income and net cash provided by operating activities and may vary among
companies, the discretionary cash flow amounts presented may not be comparable to similarly titled measures of other companies. See the consolidated
statements of cash flows herein for more detailed cash flow information.