St. Mary Reports Record Results for Second Quarter 2007, Announces Agreement to Purchase Additional South Texas Assets and Provides Guidance and Operational Update

St. Mary Land & Exploration Company (NYSE:SM) today reports record net income of $59.2 million, or $0.91 per diluted share, for the second quarter of 2007. The Company also announces that it has entered into an agreement for the acquisition of additional oil and natural gas assets in South Texas for $153.1 million. "In the second quarter of 2007, St. Mary set new quarterly records for net income, discretionary cash flow and production. Importantly, these were records both in absolute terms and on a per share basis. These financial results emphasize the benefits we derive from our balanced oil and natural gas portfolio, while our production results demonstrate our focus on executing our 2007 business plan,” commented Tony Best, President and CEO. "The South Texas acquisition we are announcing is a great fit with our existing South Texas assets. The assets will be acquired at an attractive cost and provide us with meaningful running room in an area where we are increasing our presence. I am pleased with what we have accomplished during this quarter and the first half of 2007, and am looking forward to what I believe will be a successful second half of 2007.” SECOND QUARTER RESULTS St. Mary announces second quarter 2007 earnings of $59.2 million or $0.91 per diluted share. Second quarter 2006 earnings were $40.1 million or $0.61 per diluted share. Year over year, the second quarter of 2007 benefited from a higher average realized equivalent price than the comparable quarter last year. Total lease operating and transportation expense was flat between the two periods. General and administrative expense increased as a result of increased headcount and the recognition of compensation expense attributable to vesting of equity compensation costs in the quarter. Depletion and depreciation expense rose significantly from the second quarter of 2006 to the second quarter of 2007 as properties that have been drilled or acquired in a higher finding cost environment become a larger portion of our production. The largest variance between the second quarters of 2006 and 2007 was the significant charge related to the change in the Net Profits Plan liability in the second quarter of 2006. In the second quarter of 2007, the Company recognized a slight benefit related to the change in the Net Profits Plan liability as a result of higher operating costs impacting the underlying reserves attributed to the program. Adjusted net income, which adjusts for significant non-cash and non-recurring items, was $55.3 million or $0.85 per diluted share for the second quarter of 2007 compared to $47.8 million or $0.73 per diluted share for the comparable period in 2006. Revenues for the second quarter of 2007 were $247.2 million, which includes $6.3 million of gain related to our global settlement with insurers for properties damaged or destroyed by Hurricane Rita in 2005. Revenues in the second quarter of 2006 were $193.4 million and included $6.4 million related to the sale of proved properties. Discretionary cash flow increased to $163.6 million in the second quarter of 2007 from $135.5 million in the same period of the preceding year, an increase of 21 percent. Net cash provided by operating activities increased to $156.2 million in the second quarter of 2007 from $87.1 million in the second quarter of 2006. Adjusted net income and discretionary cash flow are non-GAAP financial measures – please refer to the respective reconciliations to their nearest comparable GAAP financial measures in the Financial Highlights section at the end of this release for explanations as to why the Company believes these non-GAAP measures are meaningful. Oil and gas production during the second quarter of 2007 averaged 286.1 million cubic feet of gas equivalent per day (MMCFE/d), an increase of 15% from 248.3 MMCFE/d in the comparable 2006 period and 1% higher than the 283.1 MMCFE/d in the first quarter of 2007. This is the sixth consecutive quarter in which the Company has increased production. Average prices realized, inclusive of hedging activities, during the quarter were $7.68 per Mcf and $59.97 per barrel, 10% and 1% higher, respectively, than the realized prices in the second quarter of 2006. Average prices excluding hedging activities were $7.09 per Mcf and $61.11 per barrel during the quarter, which are 14% higher and 4% lower, respectively, than the same quarter last year. SOUTH TEXAS ACQUISITION St. Mary has entered into an agreement for the acquisition of additional oil and natural gas properties in South Texas for $153.1 million. The transaction is scheduled to close in early October of 2007. The properties target natural gas in the Olmos formation and are adjacent to our recently acquired Catarina Field assets located in Webb and Dimmit Counties, Texas. Highlights of the acquisition are as follows: Purchase price of $153.1 million to be funded with cash on hand and bank borrowings under the Company’s existing credit facility. Average working interest of 98% and average net revenue interest of 77%. Net leasehold of 56,799 net acres. 259 producing wells with current net daily production of 9.2 MMCFE/d (97% natural gas). Significant inventory of proved drilling locations, with probable and possible upside potential as follows: Resource Category GrossLocations Est. NetResource(BCFE)   PROVED DEVELOPED 259 37.8 PROVED UNDEVELOPED 151   57.0 TOTAL PROVED 410 94.8     PROBABLE 48 41.1 POSSIBLE 58   24.9 TOTAL 3P 516   160.8 Estimated completed well cost of $0.6 million per well with $1.55 per MCFE in operating costs, inclusive of severance taxes. Capital expenditure related to drilling activity in 2007 is expected to be approximately $6.0 million. The acquisition is expected to add approximately 0.7 BCFE to our 2007 production forecast, resulting in an increase of our production guidance for the year, to a range of 104.5 BCFE to 106.5 BCFE. Consistent with historical practice, the Company has hedged the first three years of risked natural gas production related to this acquisition using swaps at weighted-average NYMEX prices on a per MMBtu basis of $7.22, $8.54, $8.74, and $8.51 for the remainder of 2007, 2008, 2009, and through August 2010, respectively. Natural gas liquids have been hedged for a period of one year. The initial plan will be to operate one drilling rig in the field for the remainder of 2007 and increasing to two rigs in January of 2008. GUIDANCE UPDATE The Company’s forecasts for the third quarter and the full year 2007 are shown below. This guidance includes the impact of the South Texas acquisition referred to above. 3rd Quarter Year Oil and gas production 25.5 - 27.5 BCFE 104.5 - 106.5 BCFE Lease operating expenses, including transportation $1.36 - $1.41/MCFE $1.37 - $1.43/MCFE Production taxes $0.60 - $0.65/MCFE $0.57 - $0.62/MCFE General and administrative exp. $0.46 - $0.52/MCFE $0.46 - $0.51/MCFE Depreciation, depletion, & amort. $2.17 - $2.22/MCFE $2.13 - $2.18/MCFE St. Mary estimates the basis differential (the difference between estimated realized oil and gas prices, before hedging, and the applicable NYMEX prices) for the third quarter of 2007 will be $5.50 to $6.50 per barrel of oil and $0.60 to $0.70 per Mcf of gas. Below is an updated summary hedging schedule for the Company, which includes hedges associated with the South Texas acquisition mentioned above. All the prices in the table below have been converted to a NYMEX equivalent for ease of comparison using current quality and transportation differentials. The majority of the oil trades are settled against NYMEX. The gas contracts have been executed to settle against regional delivery points that correspond with production areas of the Company, thereby reducing basis risk. For detailed schedules on the Company’s hedging program, please refer to the Form 10-Q for the period ended June 30, 2007, which is expected to be filed with the Securities and Exchange Commission on or about August 3, 2007. Oil Swaps - NYMEX Equivalent Oil Collars - NYMEX Equivalent   Bbls $/Bbl Bbls $/Bbl $/Bbl 2007 2007 Q3 437,684 $ 62.86 Q3 716,000 $ 51.58 $ 72.78 Q4 474,620 $ 64.68 Q4 689,000 $ 51.58 $ 72.81 2008 1,795,000 $ 69.17 2008 1,668,000 $ 50.00 $ 69.82 2009 1,363,000 $ 67.74 2009 1,526,000 $ 50.00 $ 67.31 2010 1,239,000 $ 66.47 2010 1,367,500 $ 50.00 $ 64.91 2011 1,032,000 $ 65.36 2011 1,236,000 $ 50.00 $ 63.70   Natural Gas Swaps - NYMEX Equivalent Natural Gas Collars - NYMEX Equivalent   MMBTU $/MMBTU MMBTU $/MMBTU $/MMBTU 2007 2007 Q3 4,600,000 $ 8.69 Q3 3,180,000 $ 8.32 $ 10.23 Q4 4,990,000 $ 9.12 Q4 3,000,000 $ 8.34 $ 10.29 2008 14,760,000 $ 8.89 2008 10,920,000 $ 7.34 $ 10.49 2009 12,030,000 $ 8.64 2009 9,110,000 $ 6.00 $ 10.00 2010 4,670,000 $ 8.27 2010 7,825,000 $ 5.87 $ 8.16 2011 880,000 $ 6.93 2011 6,625,000 $ 5.83 $ 7.07   Natural Gas Liquid Swaps - Mont. Belvieu   Bbls $/Bbl 2007 Q3 91,255 $ 38.53 Q4 132,888 $ 39.49 2008 589,081 $ 38.80 2009 292,202 $ 36.17 OPERATIONAL UPDATE St. Mary provided an operational update in its July 16, 2007 press release. Since that update, the Company has had additional results in several of its highlighted plays. In the Arkoma program in the Mid-Continent, one of the four horizontal wells that were completing in the Woodford Shale as of the last operational update has now been completed. The Duncan Shores 1-1 (SM 81% WI) was drilled and completed using a design similar to that used for successful industry wells in the play. The well had an average initial 10-day sales rate of 2.3 MMCFE/d, which compares favorably to the average rates of better wells in the field. The horizontal Woodford Shale program is still in its early stages and the majority of the potential in this play is classified as either probable or possible. The Company is encouraged by the results from this new well and is continuing to work on determining the optimal drilling and completion techniques for the play. Two of the three remaining wells being completed utilize a similar drilling and completion design as the Duncan Shores well and the third is experimenting with an alternative completion design. St. Mary anticipates two operated rigs running in the play for the remainder of the year. In the James Lime play in the ArkLaTex region, the Company continues to realize positive results. In recent months St. Mary has successfully completed wells which validate areas outside of where the Company has traditionally operated in the James Lime trend. The St. Mary operated George Smith 1 well (SM 67% WI) was completed at an average 10-day rate of 3.6 MMCFE/d. The Company-operated Middlebrook 1-H (SM 29% WI) was completed last week and has been producing to sales at an average rate of 4.5 MMCFE/d. The Middlebrook well was completed in fewer days and for less cost than had been budgeted. St. Mary continues to be a leader in this play and is actively working to expand its presence in the trend. Below is an updated schedule as of June 30, 2007 detailing the Company’s 3P Drilling Potential and Estimated Future Gross Locations, which is intended to give visibility to and a sense of scale of some of St. Mary’s larger drilling programs. See the section "Information About Reserves” below for descriptions of these terms. Program Region 3P DrillingPotential(Bcfe) Estimated Future Gross Locations Elm Grove ArkLaTex 173 642 Atoka/Granite Wash Mid-Continent 218 533 James Lime ArkLaTex 92 78 Sweetie Peck Permian 139 248 Olmos Gas Gulf Coast 130 345 Hanging Woman Basin Rockies 790 ~3,0001 Horizontal Arkoma Mid-Continent 594 537   1 This number could vary significantly depending on implementation of multi-seam completion techniques. CONFERENCE CALL As previously announced, the St. Mary second quarter 2007 earnings teleconference call is scheduled for August 3, 2007 at 8:00 am (MDT). The call participation number is 888-424-5231. A replay of the conference call will be available two hours after the completion of the call, 24 hours per day through August 17 at 800-642-1687, conference number 6480066. International participants can dial 706-634-6088 to take part in the conference call, and can access a replay of the call at 706-645-9291, conference number 6480066. In addition the call will be broadcast live at St. Mary’s website at www.stmaryland.com and this press release and financial highlights attachment will be available before the call at www.stmaryland.com under "News—Press Releases.” An audio recording of the conference call will be available at that site through August 17. 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,” "intend,” "estimate,” "forecast,” ”plan,” "evaluate,” 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 pending nature of the announced acquisition of properties in South Texas as well as the ability to complete this transaction, the uncertain nature of the expected benefits from the acquisition of oil and gas properties and the ability to successfully integrate acquisitions, volatility and level of oil and natural gas prices, unexpected drilling conditions and results, the risks of various exploration and hedging strategies, production rates and reserve replacement, the imprecise nature of oil and gas reserve estimates, drilling and operating service availability, uncertainties in cash flow, the financial strength of hedge contract counterparties, the availability of economically attractive exploration and development and property acquisition opportunities and any necessary financing, competition, litigation, environmental matters, the potential impact of government regulations, the use of management estimates, and other such matters discussed in the "Risk Factors” section of St. Mary’s 2006 Annual Report on Form 10-K/A and subsequent Quarterly Reports on Form 10-Q filed with the SEC. 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. INFORMATION ABOUT RESERVES The SEC permits oil and gas companies to disclose in their filings with the SEC only proved reserves, which are reserve estimates that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. St. Mary uses in this press release the terms "probable”, "possible”, and "3P” reserves, which SEC guidelines prohibit from being included in filings with the SEC. Probable reserves are unproved reserves which are more likely than not to be recoverable. Possible reserves are unproved reserves which are less likely to be recoverable than probable reserves. Estimates of probable and possible reserves which may potentially be recoverable through additional drilling or recovery techniques are by their nature more uncertain than estimates of proved reserves and accordingly are subject to substantially greater risk of not actually being realized by the Company. In addition, our production forecasts and expectations for future periods are dependent upon many assumptions, including estimates of production decline rates from existing wells and the undertaking and outcome of future drilling activity, which may be affected by significant commodity price declines or drilling cost increases. 3P Drilling Potential should be thought of as reserves net to St. Mary and characterized as of June 30, 2007, as either proved undeveloped, probable, or possible reserves that could be produced through future drilling and capital spending. Estimated Future Gross Locations should be thought of as the number of gross drilling locations categorized as either proved undeveloped, probable and possible reserves as of June 30, 2007. ST. MARY LAND & EXPLORATION COMPANY FINANCIAL HIGHLIGHTS June 30, 2007 (Unaudited)   Production Data For theThree MonthsEnded June 30, For theSix MonthsEnded June 30,       2007   2006 Percent Change   2007   2006 Percent Change   Average realized sales price, before hedging: Oil (per Bbl) $ 61.11 $ 63.68 -4% $ 56.85 $ 60.22 -6% Gas (per Mcf) $ 7.09 $ 6.20 14% $ 6.96 $ 6.86 1%   Average realized sales price, net of hedging: Oil (per Bbl) $ 59.97 $ 59.62 1% $ 56.28 $ 56.96 -1% Gas (per Mcf) $ 7.68 $ 6.96 10% $ 7.86 $ 7.59 4%   Production: Oil (MBbls) 1,698 1,429 19% 3,407 2,957 15% Gas (MMcf) 15,848 14,023 13% 31,068 26,812 16% MMCFE (6:1) 26,033 22,595 15% 51,509 44,556 16%   Daily production: Oil (Bbls per day) 18,655 15,698 19% 18,823 16,339 15% Gas (Mcf per day) 174,150 154,102 13% 171,645 148,132 16% MCFE per day (6:1) 286,082 248,292 15% 284,581 246,168 16%   Margin analysis per MCFE: Average realized sales price, before hedging $ 8.30 $ 7.88 5% $ 7.96 $ 8.13 -2%   Average realized price, net of hedging $ 8.58 $ 8.09 6% $ 8.46 $ 8.35 1% Lease operating expense and transportation 1.37 1.37 0% 1.45 1.36 7% Production taxes 0.56 0.54 4% 0.55 0.54 2% General and administrative   0.53   0.46 15%   0.48   0.48 0% Operating margin $ 6.12 $ 5.72 7% $ 5.98 $ 5.97 0% Depletion, depreciation, amortization, and asset retirement obligation liability accretion $ 2.10 $ 1.59 32% $ 2.01 $ 1.58 27% ST. MARY LAND & EXPLORATION COMPANYFINANCIAL HIGHLIGHTSJune 30, 2007(Unaudited)     Consolidated Statements of Operations (In thousands, except per share amounts) For the Three Months For the Six Months Ended June 30, Ended June 30, 2007 2006 2007 2006 Operating revenues: Oil and gas production revenue $ 216,154 $ 177,957 $ 409,860 $ 362,022 Realized oil and gas hedge gain 7,303 4,875 25,987 9,980 Marketed gas system revenue 15,967 3,167 23,826 9,234 Gain on sale of proved properties - 6,432 - 6,432 Other revenue   7,730   950   8,487   (699) Total operating revenues   247,154   193,381   468,160   386,969   Operating expenses: Oil and gas production expense 50,328 43,278 102,648 84,492 Depletion, depreciation, amortization, and asset retirement obligation liability accretion 54,657 35,910 103,616 70,301 Exploration 13,643 15,319 34,412 26,106 Impairment of proved properties - - - 1,289 Abandonment and impairment of unproved properties 1,465 1,262 2,949 2,448 General and administrative 13,697 10,429 24,838 21,215 Change in Net Profits Plan liability (1,160) 14,059 3,805 21,080 Marketed gas system expense 14,940 2,829 22,176 8,016 Unrealized derivative loss 1,200 4,791 5,104 5,261 Other expense   401   419   1,117   990 Total operating expenses   149,171   128,296   300,665   241,198   Income from operations 97,983 65,085 167,495 145,771   Nonoperating income (expense): Interest income 154 540 257 1,364 Interest expense   (3,750)   (1,549)   (9,803)   (2,928)   Income before income taxes 94,387 64,076 157,949 144,207 Income tax expense   (35,152)   (23,996)   (58,764)   (53,601)   Net income $ 59,235 $ 40,080 $ 99,185 $ 90,606   Basic weighted-average common shares outstanding   63,583   57,082   60,316   57,157   Diluted weighted-average common shares outstanding   65,120   66,950   65,015   67,145   Basic net income per common share $ 0.93 $ 0.70 $ 1.64 $ 1.59   Diluted net income per common share $ 0.91 $ 0.61 $ 1.54 $ 1.38 ST. MARY LAND & EXPLORATION COMPANYFINANCIAL HIGHLIGHTSJune 30, 2007(Unaudited)     Consolidated Balance Sheets (In thousands) June 30,2007 December 31,2006 ASSETS Current assets: Cash and cash equivalents $ 26,179 $ 1,464 Short-term investments 1,143 1,450 Accounts receivable 137,333 142,721 Refundable income taxes 6,908 7,684 Prepaid expenses and other 21,587 17,485 Accrued derivative asset   29,454   56,136 Total current assets   222,604   226,940   Property and equipment (successful efforts method), at cost: Proved oil and gas properties 2,320,523 2,063,911 Less - accumulated depletion, depreciation, and amortization (709,217) (630,051) Unproved oil and gas properties, net of impairment allowance of $9,790 in 2007 and $9,425 in 2006 110,471 100,118 Wells in progress 150,765 97,498 Other property and equipment, net of accumulated depreciation of $10,734 in 2007 and $9,740 in 2006   8,487   6,988   1,881,029   1,638,464   Noncurrent assets: Goodwill 9,452 9,452 Accrued derivative asset 4,932 16,939 Other noncurrent assets   13,614   7,302 Total noncurrent assets   27,998   33,693   Total Assets $ 2,131,631 $ 1,899,097   LIABILITIES AND STOCKHOLDERS' EQUITY Current liabilities: Accounts payable and accrued expenses $ 226,080 $ 171,834 Short-term note payable - 4,469 Accrued derivative liability 24,669 13,100 Deferred income taxes   2,713   14,667 Total current liabilities   253,462   204,070   Noncurrent liabilities: Long-term credit facility 96,000 334,000 Senior convertible notes 287,500 99,980 Asset retirement obligation 81,205 77,242 Net Profits Plan liability 164,388 160,583 Deferred income taxes 246,508 224,518 Accrued derivative liability 95,480 46,432 Other noncurrent liabilities   8,284   8,898 Total noncurrent liabilities   979,365   951,653   Stockholders' equity: Common stock, $0.01 par value: authorized - 200,000,000 shares; issued: 63,648,218 shares in 2007 and 55,251,733 shares in 2006; outstanding, net of treasury shares: 63,424,510 shares in 2007 and 55,001,733 shares in 2006     636 553 Additional paid-in capital 156,022 38,940 Treasury stock, at cost: 223,708 shares in 2007 and 250,000 shares in 2006 (3,350) (4,272) Retained earnings 791,269 695,224 Accumulated other comprehensive income (loss)   (45,773)   12,929 Total stockholders' equity   898,804   743,374   Total Liabilities and Stockholders' Equity $ 2,131,631 $ 1,899,097 ST. MARY LAND & EXPLORATION COMPANY FINANCIAL HIGHLIGHTS June 30, 2007 (Unaudited)   Consolidated Statements of Cash Flows (In thousands) For the Three Months For the Six Months Ended June 30, Ended June 30, 2007 2006 2007 2006 Reconciliation of net income to net cash provided by operating activities: Net income $ 59,235 $ 40,080 $ 99,185 $ 90,606 Adjustments to reconcile net income to net cash provided by operating activities:   Gain on insurance settlement (6,325) - (6,325) - Gain on sale of proved properties - (6,432) - (6,432) Depletion, depreciation, amortization, and asset retirement obligation liability accretion 54,657 35,910 103,616 70,301 Exploratory dry hole expense 1,651 3,394 11,220 3,640 Impairment of proved properties - - - 1,289 Abandonment and impairment of unproved properties 1,465 1,262 2,949 2,448 Unrealized derivative loss 1,200 4,792 5,104 5,261 Change in Net Profits Plan liability (1,160) 14,059 3,805 21,080 Stock-based compensation expense 3,312 3,195 6,279 6,392 Deferred income taxes 31,220 20,853 52,457 34,683 Other (2,571) (737) (2,696) (603) Changes in current assets and liabilities: Accounts receivable 4,745 22,782 12,507 49,681 Refundable income taxes 775 (18,332) 775 (18,332) Prepaid expenses and other (7,439) (9,094) (5,120) (8,678) Accounts payable and accrued expenses 18,330 (12,790) 2,327 (20,748) Income tax benefit from the exercise of stock options   (2,849)   (11,832)   (3,762)   (14,236) Net cash provided by operating activities   156,246   87,110   282,321   216,352   Cash flows from investing activities: Proceeds from insurance settlement 7,049 - 7,049 - Proceeds from sale of oil and gas properties - 182 324 182 Capital expenditures (143,800) (94,262) (278,983) (181,565) Acquisition of oil and gas properties (29,864) (4,500) (31,050) (4,771) Deposits to short-term investments available-for-sale (1,138) - (1,138) - Receipts from short-term investments available-for-sale 1,450 - 1,450 - Other   1   -   17   22 Net cash used in investing activities   (166,302)   (98,580)   (302,331)   (186,132)   Cash flows from financing activities: Proceeds from credit facility 273,914 108,000 292,914 108,000 Repayment of credit facility (527,914) (57,000) (530,914) (57,000) Repayment of short-term note payable - - (4,469) - Income tax benefit from the exercise of stock options 2,849 11,832 3,762 14,236 Proceeds from issuance of convertible debt 281,194 - 281,194 - Proceeds from sale of common stock 4,599 12,876 5,378 14,919 Repurchase of common stock - (120,616) - (120,616) Dividends paid   (3,140)   (2,859)   (3,140)   (2,859) Net cash provided by (used in) financing activities   31,502   (47,767)   44,725   (43,320)   Net change in cash and cash equivalents 21,446 (59,237) 24,715 (13,100) Cash and cash equivalents at beginning of period   4,733   61,062   1,464   14,925 Cash and cash equivalents at end of period $ 26,179 $ 1,825 $ 26,179 $ 1,825 ST. MARY LAND & EXPLORATION COMPANYFINANCIAL HIGHLIGHTSJune 30, 2007(Unaudited)     Discretionary Cash Flow (In thousands)   Reconciliation of Discretionary Cash Flow (Non-GAAP) to Net Cash Provided by Operating Activities (GAAP):     For the Three Months Ended June 30, For the Six Months Ended June 30, 2007 2006 2007 2006 Discretionary cash flow (Non-GAAP) (1) $ 163,572 $ 135,466 $ 307,807 $ 258,165   Gain on insurance proceeds (6,325) (6,325) Gain on property sales - (6,432) - (6,432) Exploration expense, excluding exploratory dry hole expense (11,992) (11,924) (23,192) (22,465) Other (2,571) (734) (2,696) (603) Changes in current assets and liabilities   13,562   (29,266)   6,727   (12,313) Net cash provided by operating activities (GAAP) $ 156,246 $ 87,110 $ 282,321 $ 216,352   Net cash used in investing activities $ (166,302) $ (98,580) $ (302,331) $ (186,132)   Net cash provided by (used in) financing activities $ 31,502 $ (47,767) $ 44,725 $ (43,320)   (1) Discretionary cash flow is computed as net income plus depreciation, depletion, amortization, ARO liability accretion, impairments, deferred taxes, exploration expense, stock-based compensation expense, and non-cash changes in the Net Profits Plan liability less the effect of unrealized derivative (gain) loss. 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. Adjusted Net Income (In thousands, except per share data)   Reconciliation of Net Income (GAAP) to Adjusted Net Income (Non-GAAP):     For the Three Months Ended June 30, For the Six Months Ended June 30, 2007 2006 2007 2006   Reported Net Income (GAAP) $ 59,235 $ 40,080 $ 99,185 $ 90,606   Change in Net Profits Plan liability (1,160) 14,059 3,805 21,080 Unrealized derivative loss 1,200 4,791 5,104 5,261 Gain on sale of proved property - (6,432) - (6,432) Hurricane insurance settlement (2) (6,325) - (6,325) -         Total of Adjustments   (6,285)   12,418   2,584   19,909   Benefit (expense) from tax effect on adjustments 2,341 (4,650) (961) (7,400)         Adjusted Net Income (Non-GAAP) (3) $ 55,291 $ 47,848 $ 100,808 $ 103,115   Adjusted Net Income Per Share (Non-GAAP) Basic $ 0.87 $ 0.84 $ 1.67 $ 1.80 Diluted $ 0.85 $ 0.73 $ 1.56 $ 1.56   Average Number of Shares Outstanding Basic   63,583   57,082   60,316   57,157 Diluted   65,120   66,950   65,015   67,145   (2) Included within line item Other revenue on the Consolidated Statements of Operations.   (3) Adjusted net income is calculated as net income adjusted for significant non-cash and non-recurring items. Examples of non-cash charges include non-cash gains or losses resulting from changes in the Net Profit Plan liability and unrealized derivative gains and losses. Examples of non-recurring items include gains from sales of properties and insurance settlements. 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.