Feb 21, 2012 (GlobeNewswire via COMTEX) — – Full-year 2012 capital expenditure plan reduced by 18% — Dry-gas capital expenditures reduced by 65% — Voll Compressor Station commissioned, increases Sarsen Plant capacity to 40 MMcf/d — first Utica Shale well in the Warrior Prospect expected to be spud in April — Cheeseman #1H Utica Shale well recently connected to pipeline, first sales expected March 1st — ASP injection of Perkins-Smith Unit on schedule for second quarter
STATE COLLEGE, Pa., Feb. 21, 2012 (GLOBE NEWSWIRE) — Rex Energy Corporation (Rex Energy or the company) /quotes/zigman/107011/quotes/nls/rexx REXX +0.87% today announced its fourth quarter 2011 and full-year 2011 operational and financial results and provided its updated 2012 capital budget and revised guidance.
Fourth Quarter Operational and Financial Results
Operating revenue from continuing operations was $31.7 million for the fourth quarter 2011, which is an increase of 63% over the same period of 2010. Commodity revenues, including cash settled derivatives, were $33.2 million, of which 57% was attributable to oil and natural gas liquids and 43% was attributable to natural gas. Realized prices for oil, including cash-settled derivatives, were $90.32 per barrel. Realized prices for natural gas, including cash-settled derivatives, were $4.57 per Mcf and realized prices for NGLs were $54.10 per barrel, which was 58% of the average quoted NYMEX price for the fourth quarter.
Production and lease operating expenses from continuing operations for the fourth quarter 2011 were $9.1 million, which is an increase of 40% over the fourth quarter 2010. The increase in production and lease operating expense is primarily the result of growth in the number of producing wells in the Appalachia Basin. Cash general and administrative expenses from continuing operations were $4.7 million, a 12% increase over the fourth quarter of 2010.
Net income from continuing operations for the fourth quarter 2011 was $1.1 million, or $0.03 per share. Loss from discontinued operations for the fourth quarter 2011 was $4.3 million, or $0.10 per share. EBITDAX from continuing operations, a non-GAAP measure, was $19.8 million for the fourth quarter. This was an increase of 3% over the third quarter of 2011 and an increase of 139% over the fourth quarter 2010. A reconciliation between EBITDAX and GAAP net income is presented in the financial highlights attached to this release.
The company incurred impairment expenses of $11.7 million from continuing operations in the fourth quarter 2011 related to the write-down of the company’s legacy conventional shallow-well natural gas properties in the Appalachia Basin.
Full-Year 2011 Financial and Operational Results
Operating revenues from continuing operations for the full-year 2011 were $114.6 million, which is an increase of 67% over full year 2010 operating revenues. Commodity revenues, including cash-settled derivatives, were $118.1 million for the full year 2011, of which 62% was attributable to oil and natural gas liquids and 38% was attributable to natural gas. Realized prices for oil, including cash-settled derivatives were $90.50 per barrel. Realized prices for natural gas, including cash-settled derivatives were $5.05 per Mcf and realized prices for NGLs were $53.66 per barrel, which was 56% of the average quoted NYMEX oil price for 2011.
for the full-year 2011, production and lease operating expenses from continuing operations were $33.1 million, which is an increase of 34% over full year 2010. The increase is attributable to the company’s growing number of producing wells in the Appalachia Basin. Cash general and administrative expenses from continued operations were $22.0 million, increasing from $16.2 million in 2010.
Net income from continuing operations for the full-year 2011 was $18.1 million, or $0.41 per share. Loss from discontinued operations for the full-year 2011 was $33.5 million, or $0.76 per share. EBITDAX from continuing operations, a non-GAAP measure, was $64.5 million for the full year 2011, representing an increase of 139% over the full-year 2010.
2011 Capital Expenditures
Capital expenditures for the full-year 2011 totaled $302.4 million with $24.0 million attributable to discontinued operations in the company’s Niobrara shale area. This is above the company’s previously issued guidance of $270.0 million. The increase above previous guidance was due to the acceleration of leasing activity in the Warrior Prospect, additional costs related to drilling and completion in the Appalachia Basin and capital expenditures related to the Niobrara shale area.
The following table shows a breakdown of the company’s 2011 capital expenditures ($ in millions):
Illinois Basin Tertiary Recovery Projects $ 4.0 other Capital Expenditures 9.3 ——- Total Illinois Basin $ 13.3 Appalachia Basin Operated Drilling and Exploitation $ 103.5 Non-Operated Drilling and Exploitation 55.4 Midstream 23.2 other Capital Expenditures 5.2 Leasing and Acreage Acquisitions 76.8 ——- Total Appalachia Basin $ 264.1 Corporate Capital Expenditures $ 1.0 ——- Total Capital Expenditures from Continuing Operations $ 278.4 Rockies Basin other Capital Expenditures $ 22.1 Leasing 1.9 ——- Total Capital Expenditures from Discontinued Operations $ 24.0 Total 2011 Capital Expenditures $ 302.4
Revised 2012 Capital Expenditure Budget
given the recent weakness in natural gas prices, the company is reducing and reallocating its capital expenditure budget for 2012 into its more liquids-rich areas. with the changes outlined below, the company will now have 85% of its total capital budget allocated to its oil and liquids-rich project areas.
In the Butler County operated areas of Pennsylvania, the capital program targeting the dry gas portion of the Utica Shale has been reduced from drilling three gross (2.1 net) wells and completing one gross (0.7 net) well to drilling one gross (0.7 net) Utica Shale well. The capital from the remaining two gross (1.4 net) Utica shale wells will be used to drill two gross (1.4 net) Marcellus Shale wells, which are in the liquids-rich zone. In addition, the company plans to drill and complete one gross (0.7 net) Upper Devonian/Rhinestreet Shale well. The Rhinestreet Shale lies approximately 400 feet above the Burkett Shale and is 130 feet thick in the Butler County area. Based on log analysis, the Rhinestreet Shale appears to be similar to the Marcellus and Burkett Shales in terms of organic carbon content and porosity. Since the Rhinestreet Shale is approximately 400 and 600 feet shallower than the Burkett and Marcellus Shales, respectively, the company anticipates it will produce at a higher liquids content than either of the deeper plays.
In the company’s non-operated areas of Westmoreland, Clearfield and Centre Counties, Pennsylvania, where WPX Energy serves as the operator, the company has reduced the number of wells expected to be drilled from the previously announced 17 gross (6.8 net) wells to 7 gross (2.8 net) wells. Rex Energy has also reduced the number of wells expected to be fracture stimulated in 2012 from the previously announced 16 gross (6.4 net) wells to 1 gross (0.4 net) wells. The number of wells expected to be placed into service during 2012 has also been reduced from the previously announced 16 gross (6.4 net) to zero. The company expects to have 10 gross (4.0 net) wells drilled and awaiting completion in the non-operated area at the end of 2012. Midstream capital in these areas was reduced from $9.0 million to $5.0 million. Total capital in the Westmoreland, Clearfield and Centre County non-operated areas has been reduced from $56.4 million to $22.0 million or 61%.
More information on the 2012 revised capital budget is available in the company’s current corporate presentation, which can be viewed through the company’s website rexenergy.com .
The company has provided a revised operational capital budget in the table below ($ in millions):
Illinois Basin Tertiary Recovery Projects $ 8.4 Development and Drilling 2.0 Facilities and HS&E 10.7 ——- Total Illinois Basin $ 21.1 Appalachia Basin Operated Drilling and Exploitation $ 102.6 Non-Operated Drilling and Exploitation 17.0 Facilities and HS&E 4.1 Midstream 10.0 ——- Total Appalachia Basin $ 133.1 Corporate Capital Expenditures $ 0.5 ——- Total 2012 Capital Expenditures $ 155.3
first Quarter and Revised full Year 2012 Guidance
Rex Energy has provided its revised guidance for the first quarter of 2012 and full year 2012:
Previous full Year Revised full Year $ in Millions 1Q2012 2012 2012 56.0 — 60.0 66.0 — 72.0 63.0 — 68.0 Average Daily Production MMcfe/d MMcfe/d MMcfe/d Lease Operating Expense $11.0 — $12.0 $50.0 — $55.0 $50.0 — $55.0 Cash G&A $5.0 — $6.0 $20.0 — $24.0 $20.0 — $24.0 Capital Expenditures N/A $189.7 $155.3
Appalachia Basin – Butler County, Pennsylvania Operated Area
In the Butler operated area, the company’s midstream partner, Keystone Midstream Services, has commissioned the Voll Compressor Station which will increase the inlet capacity of the Sarsen plant by 6 MMcf/d. This increase of inlet capacity is expected to bring the Sarsen plant to its fully rated capacity of 40 MMcf/d.
Keystone Midstream also remains on schedule to commission the Bluestone cryogenic processing plant in may of this year. Bluestone will have a full inlet capacity of 50 MMcf/d and will not require additional field compression.
Rex Energy has completed pipeline construction to its first Utica Shale test well in Butler County, the Cheeseman #1H. The well is expected to have first sales by March 1st. Updated well information will be provided on the company’s first quarter call.
The company has recently fracture stimulated and placed into service the remaining four wells on the seven well Grosick pad. The company expects to provide an update on the Grosick pad during its first quarter conference call. The company has also completed drilling activities on the two well Plesniak pad, and the wells are currently awaiting completion.
Appalachia Basin – Warrior Prospect, Carroll County, Ohio
In the Warrior Prospect, Rex Energy is expecting to spud its first Utica Shale well in April and anticipates completion results to be available during the second quarter conference call in August. The locations of the first two wells have been disclosed in the company’s current corporate presentation under its Warrior Prospect section.
To date the company has closed on approximately 13,700 net acres of the previously announced 15,000 net acres. The remaining acreage is expected to close during the first quarter of the year.
Appalachia Basin – Westmoreland, Clearfield, and Centre Counties Non-Operated Area
In the company’s non-operated area in Westmoreland County, Pennsylvania, where WPX Energy serves as the operator, WPX has completed drilling operations on the three well Corbett pad. The drilling rig is currently moving onto the Gera pad, where it will drill one well. there are currently no additional completion operations planned.
In the Westmoreland County non-operated area, the seven previously announced wells on the Marco #1 pad and the National Metals #1 pad had combined average 60 day sales rates of 4.1 MMcf/d per well. These results are approximately 41% above the company’s current 30 day rate (3.1 MMcf/d) and 56% above the company’s current 60 day rate (2.6 MMcf/d) given for a 4.2 Bcf well type curve for this area. WPX continues to increase sales rates in the Westmoreland County area, with average gross sales rates of approximately 65.2 MMcf/d in the Westmoreland field during the month of January.
Illinois Basin – ASP Project Update
In Rex Energy’s ASP project areas in the Illinois Basin, the company continues to move forward with its expansion into the 58 acre Perkins-Smith area. The company expects to begin ASP flooding of the Perkins-Smith project in the second quarter. In the 351 acre high impact Delta Unit, the company is in the process of completing technical work in preparation for its planned tracer injection surveying in the third quarter and ASP injection in the second quarter of 2013.
Midstream and Niobrara Asset Divestiture
The company is progressing with its divestiture plans for its Rockies assets and Butler midstream assets. The company expects these sales to close during the first half of 2012 and provide the company with an estimated $90-$110 million of liquidity.
Conference call Information
Management will host a live conference call and webcast on Wednesday, February 22, 2012 at 10:00 a.m. ET to review fourth quarter and full year 2011 financial results and operational highlights. The company’s independent auditors are completing their audit for full year 2011 and, accordingly, all financial results contained in this release and discussed on the fourth quarter conference call will remain subject to their review. The telephone number to access the conference call is (877) 849-6312. Presentation slides containing reference materials for the call and webcast will be available on the company’s website, rexenergy.com . Once on the homepage, select “Investor Relations” and then “Events and Presentations.” The replay of the event and reference materials will be available on the company’s website through March 23, 2012.
About Rex Energy Corporation
Rex Energy is headquartered in State College, Pennsylvania and is an independent oil and gas exploration and production company operating in the Appalachian and Illinois Basins within the United States. The company’s strategy is to pursue its higher potential exploration drilling prospects while acquiring oil and natural gas properties complementary to its portfolio.
The operational updates in the press release are reflected in the company’s March 2012 corporate presentation, which is available on the Rex Energy website rexenergy.com under the Events & Presentations section of the Investor Relations homepage.
The Rex Energy Corporation logo is available at globenewswire.com/newsroom/prs/?pkgid=5489
Forward-Looking Statements
Except for historical information, statements made in this release, including those relating to the company’s plans and expectations for its 2012 capital expenditures budget, first quarter 2012 and full year 2012 financial guidance and projections, timing and design of the Bluestone cryogenic processing plant, timing of sales from the Cheeseman well, timing and nature of Utica Shale development plans, drilling and completion schedules for 2012, anticipated fracture stimulation activities, the ASP pilot and expansion plans in the Illinois Basin, and anticipated timing of, and estimated proceeds for, the potential divestitures of the company’s midstream and Niobrara assets are 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. Forward-looking statements typically contain words such as “expected”, “expects”, “scheduled”, “planned”, “plans”, “anticipates” and similar words. These statements are based on assumptions and estimates that management believes are reasonable based on currently available information; however, management’s assumptions and the company’s future performance are subject to a wide range of business risks and uncertainties. there is no assurance that these goals and projections can or will be met and investors are cautioned not to rely on these forward-looking statements. A number of factors could cause actual results to differ materially from those in the forward-looking statements, including (without limitation) the following:
— adverse economic conditions in the United States and globally; — the difficult and adverse conditions in the domestic and global capital and credit markets; — domestic and global demand for oil and natural gas; — sustained or further declines in the prices the company receives for oil and natural gas; — the effects of government regulation, permitting and other legal requirements; — the geologic quality of the company’s properties with regard to, among other things, the existence of hydrocarbons in economic quantities; — uncertainties about the estimates of the company’s oil and natural gas reserves; — the company’s ability to increase production and oil and natural gas income through exploration and development; — the company’s ability to successfully apply horizontal drilling techniques and tertiary recovery methods; — the number of well locations to be drilled, the cost to drill and the time frame within which they will be drilled; — the effects of adverse weather on operations; — drilling and operating risks; — the ability of contractors to timely and adequately perform their drilling, construction, well stimulation, completion and production services; — the availability of equipment, such as drilling rigs and transportation pipelines; — changes in the company’s drilling plans and related budgets; — the adequacy of capital resources and liquidity including (without limitation) access to additional borrowing capacity; — uncertainties relating to the potential divestitures of the Niobrara and midstream assets, including the ability to reach agreements with potential purchasers on terms acceptable to the company; and — uncertainties associated with our legal proceedings and the outcome.
The company undertakes no obligation to publicly update or revise any forward-looking statements. Further information on the company’s risks and uncertainties is available in the company’s filings with the Securities and Exchange Commission.
The company’s internal estimates of reserves may be subject to revision and may be different from estimates by the company’s external reservoir engineers at year end. although the company believes the expectations and forecasts reflected in these and other forward-looking statements are reasonable, it can give no assurance they will prove to have been correct. they can be affected by inaccurate assumptions or by known or unknown risks and uncertainties.
for more information, please visit our website or contact: rexenergy.com
Tom StableyChief Executive Officer and Chief Financial Officer(814) 278-7215tstabley@rexenergycorp.com
Jesse CarlFinancial Analyst(814) 278-7045jcarl@rexenergycorp.com
REX ENERGY CORPORATION CONSOLIDATED BALANCE SHEETS ($ in Thousands) December 31, December 2011 31, 2010 (Unaudited) ———– ——— ASSETS Current Assets Cash and Cash Equivalents $ 11,796 $ 11,008 Accounts Receivable 17,717 28,849 Short-Term Derivative Instruments 10,404 4,564 Inventory, Prepaid Expenses and other 1,191 1,327 Assets Held for Sale 24,808 47,884 ———– ——— Total Current Assets 65,916 93,632 Property and Equipment (Successful Efforts Method) Evaluated Oil and Gas Properties 349,938 223,558 Unevaluated Oil and Gas Properties 123,241 64,115 other Property and Equipment 43,542 42,178 Wells and Facilities in Progress 66,548 35,054 Pipelines 4,408 4,080 ———– ——— Total Property and Equipment 587,677 368,985 less: Accumulated Depreciation, Depletion and Amortization (107,433) (93,062) ———– ——— Net Property and Equipment 480,244 275,923 Restricted Cash 25 16,111 Intangible Assets and other Assets — Net 3,380 1,570 Equity Method Investments 41,683 18,399 Long-Term Deferred Tax Assets 1,727 — Long-Term Derivative Instruments 8,576 1,450 ———– ——— Total Assets $ 601,551 $ 407,085 =========== ========= LIABILITIES AND EQUITY Current Liabilities Accounts Payable $ 41,558 $ 46,192 Accrued Expenses 15,681 8,691 Short-Term Derivative Instruments 2,363 1,860 Current Deferred Tax Liability 2,141 1,908 Liabilities Related to Assets Held for Sale 1,622 4,686 ———– ——— Total Current Liabilities 63,365 63,337 Senior Secured Line of Credit and Long-Term Debt 225,138 10,120 Long-Term Derivative Instruments 1,275 1,517 Long-Term Deferred Tax Liability 84 5,930 other Deposits and Liabilities 744 4,283 Future Abandonment Costs 18,670 17,222 ———– ——— Total Liabilities $ 309,276 $ 102,409 Stockholders’ Equity Common Stock, $.001 par value per share, 100,000,000 shares authorized and 44,859,220 shares issued and outstanding on December 31, 2011 and 44,306,677 shares issued and outstanding on December 31, 2010. 44 44 Additional Paid-In Capital 376,843 373,856 Accumulated Deficit (84,887) (69,519) ———– ——— Rex Energy Stockholders’ Equity 292,000 304,381 Noncontrolling Interests 275 295 ———– ——— Total Stockholders’ Equity 292,275 304,676 ———– ——— Total Liabilities and Stockholders’ Equity $ 601,551 $ 407,085 =========== ========= REX ENERGY CORPORATION CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited, in Thousands, Except per Share Data) Quarter Ended Year Ended December 31, December 31, ——————– ——————– 2011 2010 2011 2010 ——— ——— ———- ——– OPERATING REVENUE Oil and Natural Gas Sales $ 30,792 $ 18,758 $ 111,879 $ 67,224 other Revenue 889 706 2,727 1,539 ——— ——— ———- ——– TOTAL OPERATING REVENUES $ 31,681 $ 19,464 $ 114,606 $ 68,763 OPERATING EXPENSES Production and Lease Operating Expenses 9,061 6,474 33,116 24,656 General and Administrative Expense 5,032 3,974 23,636 17,141 (Gain) Loss on Disposal of Assets 38 98 502 (16,395) Impairment Expense 11,703 5,295 14,631 8,863 Exploration Expense 304 152 2,507 2,578 Depreciation, Depletion, Amortization and Accretion 8,720 6,595 28,361 21,806 other Operating Expense 1,017 480 2,569 1,341 ——— ——— ———- ——– TOTAL OPERATING EXPENSES $ 35,875 $ 23,068 $ 105,322 $ 59,990 ——— ——— ———- ——– INCOME (LOSS) FROM OPERATIONS $ (4,194) $ (3,604) $ 9,284 $ 8,773 OTHER INCOME (EXPENSE) interest Income — 11 10 68 interest Expense (986) (309) (2,019) (1,070) Gain (Loss) on Derivatives, net 6,128 (3,985) 18,916 6,055 other Income (Expense) 17 (154) 79 (321) Gain (Loss) on Equity Method Investments 246 (158) 81 (200) ——— ——— ———- ——– TOTAL OTHER INCOME (EXPENSE) $ 5,405 $ (4,595) $ 17,067 $ 4,532 INCOME (LOSS) FROM CONTINUIING OPERATIONS BEFORE INCOME TAX 1,211 (8,199) 26,351 13,305 Income Tax (Expense) Benefit (62) 3,086 (8,270) (5,500) ——— ——— ———- ——– INCOME (LOSS) FROM CONTINUING OPERATIONS $ 1,149 $ (5,113) $ 18,081 $ 7,805 Loss from Discontinued Operations, Net of Income Taxes (4,263) (1,447) (33,457) (2,022) ——— ——— ———- ——– NET INCOME (LOSS) (3,114) (6,560) (15,376) 5,783 Net Income (Loss) Attributable to Noncontrolling Interests 7 (45) (7) (253) ——— ——— ———- ——– NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ (3,121) $ (6,515) $ (15,369) $ 6,036 ========= ========= ========== ======== Earnings per common share: Basic — net income (loss) from continuing operations attributable to Rex common shareholders $ 0.03 $ (0.12) $ 0.41 $ 0.18 Basic — net loss from discontinued operations attributable to Rex common shareholders (0.10) (0.03) (0.76) (0.05) ——— ——— ———- ——– Basic – net income (loss) attributable to Rex common shareholders $ (0.07) $ (0.15) $ (0.35) $ 0.13 Basic – weighted average shares of common stock outstanding 44,026 43,447 43,930 43,558 Diluted – net income (loss) from continuing operations attributable to Rex common shareholders $ 0.03 $ (0.12) $ 0.41 $ 0.18 Diluted — net loss from discontinued operations attributable to Rex common shareholders (0.10) (0.03) (0.76) (0.05) ——— ——— ———- ——– Diluted – net income (loss) attributable to Rex common shareholders $ (0.07) $ (0.15) $ (0.35) $ 0.13 Diluted – weighted average shares of common stock outstanding 44,567 43,447 44,476 43,670 REX ENERGY CORPORATION CONSOLIDATED OPERATIONAL HIGHLIGHTS (Unaudited) Quarter Ended Year Ended December 31, December 31, ——————– ——————— 2011 2010 2011 2010 ——— ——— ———- ——— Oil and gas sales (in thousands): Oil sales $ 15,967 $ 14,446 $ 63,515 52,577 Natural gas sales 11,943 3,946 38,161 13,789 Natural gas liquid sales 2,882 366 10,203 859 Cash-settled derivatives: Crude oil (23) (1,532) (670) (3,861) Natural gas 2,419 1,810 6,882 4,667 ——— ——— ———- ——— Total oil and gas sales including cash settled derivatives $ 33,188 $ 19,036 $ 118,091 68,031 Production during the period: Oil (Bbls) 176,529 177,049 694,452 691,574 Natural gas (Mcf) 3,144,088 979,512 8,912,250 3,088,598 Natural gas liquids (Bbls) 53,273 8,615 190,150 25,559 ——— ——— ———- ——— Total (Mcfe)1 4,522,900 2,093,496 14,219,862 7,391,396 Production — average per day: Oil (Bbls) 1,919 1,924 1,903 1,895 Natural gas (Mcf) 34,175 10,647 24,417 8,462 Natural gas liquids (Bbls) 579 94 521 70 ——— ——— ———- ——— Total (Mcfe)1 49,162 22,755 38,959 20,250 Average price per unit: Realized crude oil price per Bbl — as reported $ 90.45 $ 81.59 $ 91.46 $ 76.03 Realized impact from cash settled derivatives per Bbl (0.13) (8.65) (0.96) (5.58) ——— ——— ———- ——— Net realized price per Bbl $ 90.32 $ 72.94 $ 90.50 $ 70.45 Realized natural gas price per Mcf — as reported $ 3.80 $ 4.03 $ 4.28 $ 4.46 Realized impact from cash settled derivatives per Mcf 0.77 1.85 0.77 1.51 ——— ——— ———- ——— Net realized price per Mcf $ 4.57 $ 5.88 $ 5.05 $ 5.97 Realized natural gas liquids price per Bbl — as reported $ 54.10 $ 42.48 $ 53.66 $ 33.60 Realized impact from cash settled derivatives per Bbl — – — – ——— ——— ———- ——— Net realized price per Bbl $ 54.10 $ 42.48 $ 53.66 $ 33.60 LOE/Mcfe1 $ 2.00 $ 3.09 $ 2.33 $ 3.34 1Natural gas is converted at the rate of one Mcf to one Mcfe. Oil and natural gas liquids are converted at a rate of one Bbl to six Mcfe REX ENERGY CORPORATION OIL AND GAS DERIVATIVES — CURRENT HEDGING POSITIONa 2012 2013 ———– ———– Oil Derivatives (Bbl) 550,000 540,000 Volume Bbls Bbls Ceiling $ 111.08 $ 112.56 Floor $ 68.39 $ 72.44 Natural Gas Derivatives (Mcf) Swap Contracts 4,020,000 4,770,000 Volume Mcf Mcf Price $ 4.26 $ 3.92 Swaption Contracts Volume 550,000 Mcf — Price $ 5.25 — Collar Contracts 2,750,000 3,360,000 Volume Mcf Mcf Ceiling $ 5.89 $ 5.68 Floor $ 4.70 $ 4.77 put Contracts Volume — 660,000 Mcf Floor $ — $ 5.00 Collar Contracts with Short Puts 2,420,000 1,920,000 Volume Mcf Mcf Ceiling $ 5.13 $ 5.08 Floor $ 4.48 $ 4.38 Short put $ 3.66 $ 3.53 aHedging position as of February 21, 2012. for more information on hedging position and percentage of production hedged, please see current corporate presentation
The following table has been added to provide clarification on the components of Gain on Derivatives, net under other Income (Expense) on the Consolidated Statements of Operations for each of the periods presented (in thousands):
Quarter Ended Year Ended December 31, December 31, ——————– ——————- 2011 2010 2011 2010 ——— ——— ——– ——— Realized Gains (Losses) from Financial Derivatives: Crude Oil Derivatives $ (23) $ (1,532) $ (670) $ (3,861) Natural Gas Derivatives 2,419 1,810 6,882 4,667 interest Rate Derivatives — (123) — (711) ——— ——— ——– ——— Total Realized Gains from Financial Derivatives $ 2,396 $ 155 $ 6,212 $ 95 Unrealized Gains (Losses) from Financial Derivatives: Crude Oil Derivatives $ (5,636) $ (2,528) $ 362 $ 2,963 Natural Gas Derivatives 9,368 (1,784) 12,342 2,286 interest Rate Derivatives — 172 — 711 ——— ——— ——– ——— Total Unrealized Gains (Losses) from Financial Derivatives $ 3,732 $ (4,140) $ 12,704 $ 5,960 ——— ——— ——– ——— Gain (Loss) on Derivatives, net $ 6,128 $ (3,985) $ 18,916 $ 6,055 ========= ========= ======== =========
Non-GAAP Financial Measures
“EBITDAX” means, for any defined period, the sum of net income for the period plus the following expenses, charges or income, in each case, to the extent deducted from or added to net income in the period: interest, income taxes, depreciation, depletion, amortization, accretion, unrealized losses from financial derivatives, exploration expenses, and other similar non-cash charges, minus all non-cash income (without limitation) income from unrealized financial derivatives, added to net income. EBITDAX is used as a financial measure by Rex Energy’s management team and by other users of its financial statements, such as the company’s commercial bank lenders, to analyze such things as:
— Rex Energy’s operating performance and return on capital in comparison to those of other companies in its industry, without regard to financial or capital structure; — The financial performance of the company’s assets and valuation of the entity, without regard to financing methods, capital structure or historical cost basis; — Rex Energy’s ability to generate cash sufficient to pay interest costs, support its indebtedness and make cash distributions to its stockholders; and — The viability of acquisitions and capital expenditure projects and the overall rates or return on alternative investment opportunities
EBITDAX is not a calculation based on GAAP financial measures and should not be considered as an alternative to net income (loss) in measuring the company’s performance, nor used as an exclusive measure of cash flow, because it does not consider the impact of working capital growth, capital expenditures, debt principal reductions, and other sources and uses of cash, which are disclosed in the company’s statements of cash flows.
Rex Energy has reported EBITDAX because it is a financial measure used by its existing commercial lenders, and because this measure is commonly reported and widely used by investors as an indicator of a company’s operating performance and ability to incur and service debt. You should carefully consider the specific items included in the company’s computations of EBITDAX. while Rex Energy has disclosed its EBITDAX to permit a more complete comparative analysis of its operating performance and debt servicing ability relative to other companies, you are cautioned that EBITDAX as reported by the company may not be comparable in all instances to EBITDAX as reported by other companies. EBITDAX amounts may not by fully available for management’s discretionary use, due to requirements to conserve funds for capital expenditures, debt service and other commitments.
Rex Energy believes that EBITDAX assists its lenders and investors in comparing a company’s performance on a consistent basis without regard to certain expenses, which can vary significantly depending upon accounting methods. because the company may borrow money to finance its operations, interest expense is a necessary element of its costs and ability to generate cash available for distribution. because Rex Energy uses capital assets, depreciation and amortization are also necessary elements of its costs. Additionally, the company is required to pay federal and state taxes, which are necessary elements of its costs. Therefore, any measures that exclude these elements have material limitations.
Rex Energy believes it is important to consider both net income (loss) determined under GAAP and EBITDAX to evaluate its performance.
The following table presents a reconciliation of the company’s net income (loss) from continuing operations to its EBITDAX from continuing operations for each of the periods presented($ in thousands):
Quarter Ended Year Ended December 31, December 31, ——————- —————— 2011 2010 2011 2010 ——– ——— ——– ——– Net Income (Loss) from Continuing Operations $ 1,149 $ (5,113) $ 18,081 $ 7,805 Add back Depletion, Depreciation, Amortization & Accretion 8,720 6,595 28,361 21,806 Add back (Less) Non-Cash Compensation Expense (Income) 306 (256) 1,601 907 Add back interest Expense 986 309 2,019 1,070 Add back Impairment Expense 11,703 5,295 14,631 8,863 Add back Exploration Expense 304 152 2,507 2,578 less interest Income — (11) (10) (68) Add back Realized Gain on interest Rate Derivatives — 123 — 711 Add back (Less) Loss (Gain) on Disposal of Assets 38 98 502 (16,395) Add back (Less) Unrealized Loss (Gain) from Financial Derivatives (3,732) 4,140 (12,704) (5,960) Add back (Less) Noncontrolling interest Share of Net Loss (Income) (7) 45 7 253 Add back (Less) Equity Method EBITDAX 308 2 1,259 (85) Add back (Less) Income Tax Expense (Benefit) 62 (3,086) 8,270 5,500 ——– ——— ——– ——– EBITDAX from Continuing Operations $ 19,837 $ 8,293 $ 64,524 $ 26,985 Net Loss from Discontinued Operations (4,263) (1447) (33,457) (2,022) Add back Depletion, Depreciation, Amortization & Accretion 8 — 85 1 Add back Non-Cash Compensation Expense (21) 3 24 7 Add back interest Expense — – 1 — Add back Impairment Expense 1,921 — 13,176 — Add back Exploration Expense 2,250 2,118 33,812 2,664 less Income Tax Benefit (229) (873) (15,302) (1,440) ——– ——— ——– ——– EBITDAX from Discontinued Operations (334) (199) (1,661) (790) ——– ——— ——– ——– EBITDAX 19,503 8,094 62,863 26,195 ======== ========= ======== ========
Earnings Comparable with Analyst Estimates
“Earnings Comparable with Analyst Estimates” means, for any period, the sum of net income for the period plus the following expenses, charges or income, in each case, to the extent deducted from or added to net income in the period: unrealized losses from financial derivatives, non-cash compensation expense, dry hole expenses and impairment, minus all gains from unrealized financial derivatives and deferred income tax benefits, added to net income. Earnings Comparable with Analyst Estimates is used as a financial measure by Rex Energy’s management team and by other users of its financial statements, to analyze its financial performance without regard to non-cash deferred taxes and non-cash unrealized losses or gains from oil and gas derivatives. Earnings Comparable with Analyst Estimates is not a calculation based on GAAP financial measures and should not be considered as an alternative to net income (loss) in measuring the company’s performance.
Rex Energy has reported Earnings Comparable with Analyst Estimates because it believes that this measure is commonly reported and widely used by investors as an indicator of a company’s operating performance. You should carefully consider the specific items included in the company’s computation of this measure. You are cautioned that Earnings Comparable with Analyst Estimates as reported by Rex Energy may not be comparable in all instances to that reported by other companies.
Rex Energy believes it is important to consider both net income determined under GAAP and Earnings Comparable with Analyst Estimates.
The following table presents a reconciliation of Rex Energy’s net income (loss) from continuing operations to its Earnings Comparable with Analyst Estimates for each of the periods presented ($ in thousands):
This news release was distributed by GlobeNewswire, globenewswire.com
SOURCE: Rex Energy Corporation
Quarter Ended Year Ended December 31, December 31, ——————- —————— 2011 2010 2011 2010 ——– ——— ——– ——– Income (Loss) from Continuing Operations Before Income Taxes, as reported $ 1,211 $ (8,199) $ 26,351 $ 13,305 Add back (Less) Unrealized Loss (Gain) from Financial Derivatives (3,732) 4,140 (12,704) (5,960) Add back Impairment of Unproved Properties 11,703 5,295 14,631 8,863 Add back Dry Hole Expense — 1 — 3 Add back (Less) Non-Cash Compensation Expense (Income) 306 (256) 1,601 907 Add back (Less) Loss (Gain) on Disposal of Assets 38 98 502 (16,395) Add back (Less) Loss (Income) Attributable to Noncontrolling Interests (7) 45 7 253 ——– ——— ——– ——– Income (Loss) from Continuing Operations Before Income Taxes, adjusted $ 9,519 $ 1,124 $ 30,388 $ 976 less Income Taxes, adjusted a (485) (423) (9,537) (403) ——– ——— ——– ——– Net Income from Continuing Operations Comparable to Analyst Estimates $ 9,034 $ 701 $ 20,851 $ 573 ======== ========= ======== ======== Basic Net Income Comparable to Analyst Estimates per Share $ 0.21 $ 0.02 $ 0.47 $ 0.01 Basic — Weighted average shares of common stock outstanding 44,026 43,447 43,930 43,558 a Income tax adjustment represents the effect of our effective tax rate on Income (Loss) Before Income Taxes, adjusted
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February 21, 2012 – 5:12 am
February 04, 2012, 5:19 PM EST
by “flickr.com/photos/7955505 @ N05/4330176809″> Curious Expeditions
