- Production of 196.2 MMcfe/d, a 61% increase year-over-year
- Cash G&A from continuing operations decreased by 11% from fourth quarter 2014
- Liquids production of 11.4 Mboe/d, a 84% increase year-over-year
- Last 18 Marcellus, Upper Devonian Burkett and Ohio Utica wells completed with higher sand concentrations continue to meet or exceed respective type curves
- Increasing full year 2015 production guidance due to increased performance from recently completed wells with higher sand concentrations
- Completed four-well Renick pad in Moraine East
- Recently entered into two LNG supply agreements to transport gas to the Gulf Coast
STATE COLLEGE, Pa., May 5, 2015 (GLOBE NEWSWIRE) -- Rex Energy Corporation (Nasdaq:REXX) announced its first quarter 2015 operational and financial results.
“Through sharp focus on the technical side, the Rex Energy team continues to improve operational performance while maintaining financial discipline,” said Tom Stabley, Chief Executive Officer of Rex Energy. “We’ve enhanced completion designs, increased sand concentration, and realized drilling and service efficiencies to improve well performance, and increase IP rates and EURs. With these enhancements and our current CAPEX budget, we expect to grow 2015 production by approximately 25%.
“Pricing continues to be pressured, but we are navigating this lower commodity price cycle by selectively deploying capital on higher return projects and actively managing our hedge book,” Mr. Stabley continued. “I’m also pleased to report that we’ve secured access to additional gas markets in the Gulf Coast through new firm transportation and marketing arrangements. These arrangements, which are expected to commence in late 2016, will support our development of Moraine East and strengthen our marketing options for the Butler Operated Area. They are important components of our strategy to build a diversified portfolio for our natural gas markets – both from a geographic and price sensitivity perspective.”
First Quarter Financial Results
Operating revenues from continuing operations for the three months ended March 31, 2015 were $54.1 million. Commodity revenues, including settlements from derivatives, were $64.7 million with commodity revenues from oil and natural gas liquids (NGLs), including settlements from derivatives, representing 48% of total commodity revenues for the three months ended March 31, 2015.
Including the effects of cash settled basis differential derivatives, the company’s basis differential for its Appalachian Basin assets averaged approximately ($0.49) off the average Henry Hub settlement price of $2.98 for the three months ended March 31, 2015.
LOE from continuing operations was $29.1 million, or $1.65 Mcfe for the first quarter of 2015, a 9% decrease from the first quarter of 2014. Cash G&A expenses from continuing operations, a non-GAAP measure, were $6.7 million for the first quarter of 2015, a 47% decrease on a per unit basis from the first quarter of 2014. The decrease in per unit cash G&A expense is a result of a reduction in workforce and other cost reduction measures.
Net loss attributable to common shareholders for the three months ended March 31, 2015 was $20.2 million, or $0.38 per basic share. Adjusted net loss, a non-GAAP measure, for the three months ended March 31, 2015 was $5.7 million, or $0.11 per share.
EBITDAX from continuing operations, a non-GAAP measure, was $29.3 million for the first quarter of 2015.
Reconciliations of adjusted net income (loss) to GAAP income (loss) from continuing operations before income taxes, EBITDAX to GAAP net income (loss) and G&A to cash G&A for the three months ended March 31, 2015, as well as a discussion of the uses of each measure, are presented in the appendix of this release.
Production Results and Price Realizations
First quarter 2015 production volumes were 196.2 MMcfe/d, an increase of 61% over the first quarter of 2014, consisting of 127.8 MMcf/d of natural gas and 11.4 Mboe/d of oil, condensate and NGLs (including 2.1 Mboe/d of ethane). Oil, condensate and NGLs (including ethane) accounted for 35% of net production during the first quarter of 2015.
Including the effects of cash-settled derivatives, realized prices for the three months ended March 31, 2015 were $51.42 per barrel for oil and condensate, $2.92 per Mcf for natural gas, $26.21 per barrel for NGLs (C3+) and $6.70 per barrel for ethane. Before the effects of hedging, realized prices for the three months ended March 31, 2015 were $39.54 per barrel for oil and condensate, $2.46 per Mcf for natural gas, $23.25 per barrel for NGLs (C3+) and $6.58 per barrel for ethane.
First Quarter 2015 Capital Investments
For the first quarter of 2015, the company made operational capital investments of approximately $52.7 million, of which $42.1 million was used to fund Marcellus and Ohio Utica operations and $3.2 million was used to fund conventional drilling, water flood enhancement and facility upgrades in the Illinois Basin. Included in the company's first quarter operational capital investments is approximately $4.0 million related to the Moraine East Area pipeline project. The company will be reimbursed for these expenditures during the second quarter of 2015. The Marcellus and Ohio Utica capital investment funded the drilling of 14.0 gross (7.6 net) wells, fracture stimulation of eight gross (3.5 net) wells, placing 13.0 gross (8.1 net wells) into sales and other projects related to drilling and completing wells in the Appalachian Basin. The company has released two rigs year to date and entered the second quarter of 2015 with a one-rig program in the Appalachian Basin.
Investments for leasing and property acquisition were $12.2 million and capitalized interest was $1.7 million for the first quarter of 2015. Capital expenditures by the company’s water service subsidiary, Keystone Clearwater Services, were $7.4 million for the first quarter of 2015. For the remainder of 2015, the company anticipates minimal capital expenditures related to leasing and Keystone Clearwater Services.
Operational Update
Note: Unless specifically stated otherwise in this operational update, all numbers are gross and all well results assume full ethane recovery.
Appalachian Basin – Legacy Butler Operated Area
In the Butler Operated Area, the company drilled seven gross (3.2 net) wells in the first quarter of 2015, with eight gross (3.5 net) wells fracture stimulated and seven gross (3.5 net) wells placed into sales. The company had nine gross (3.2 net) wells drilled and awaiting completion as of March 31, 2015.
During the first quarter of 2015, the company placed the two-well Burr pad into sales. The two wells on the Burr pad were drilled with an average lateral length of 5,240 feet and completed with an average sand concentration of approximately 2,000 pounds per foot. The two-well Burr pad produced at an average 5-day sales rate per well of approximately 10.5 MMcfe/d.
As previously announced, the company placed into sales the four-well Powell pad and the two-well Upper Devonian Burkett Hamilton pad. The four-well Powell pad was drilled with an average lateral length of approximately 5,500 feet and produced at an average 5-day sales rate per well of approximately 9.3 MMcfe/d, and went on to produce at an average 30-day sales rate per well of approximately 6.0 MMcfe/d. The two wells on the Hamilton pad were drilled with an average lateral length of approximately 4,700 feet and produced at an average 5-day sales rate per well of approximately 7.8 MMcfe/d, and went on to produce at an average 30-day sales rate per well of approximately 5.0 MMcfe/d.
Appalachian Basin – Moraine East Area
In the Moraine East Area, the company has finished completion operations on the four-well Renick pad, consisting of three Marcellus wells and one Upper Devonian Burkett well. The four wells were drilled with an average lateral length of approximately 5,915 feet and were completed in an average of 40 stages. In addition, the four wells on the pad were completed with an average sand concentration of approximately 2,300 pounds per foot.
Appalachian Basin – Ohio Utica Warrior Prospects
In the Ohio Utica Warrior Prospects, the company’s most recent nine wells, the three-well Jenkins pad in Warrior North and the six-well J. Hall pad in Warrior South, were completed with increased sand concentrations and have performed above the company’s initial forecasts. As a result, the company is increasing its type curves for the Warrior North prospect and Warrior South prospect. The new type curves for Warrior North and Warrior South can be found in the company’s updated May 2015 corporate presentation.
Appalachian Basin – Midstream
To further diversify the company’s transportation and marketing outlets, Rex Energy has secured firm transportation for delivery of 130,000 MMbtu/d of gas to the Gulf Coast through projects with Dominion Transmission, Inc. and Texas Gas Transmission, LLC. Recently, the company leveraged these arrangements to enter into two gas supply agreements with separate LNG counterparties, to supply a total of 130,000 MMbtu/d of gas to their respective Freeport LNG projects for liquefaction.
Liquidity Update
As of March 31, 2015, the company had approximately $5.0 million of cash and $38.0 million of its $350 million borrowing base outstanding under its senior secured credit facility. In addition, during the first quarter of 2015, Rex Energy’s bank group unanimously approved an amendment to the company’s senior secured credit facility. The approved amendment includes a new senior secured debt to EBITDAX covenant of 3.0x and permanently removes the total debt to trailing twelve months EBITDAX covenant.
Second Quarter and Full Year 2015 Guidance
Rex Energy is providing its initial guidance for the second quarter of 2015 and increasing its previously issued guidance for the full year 2015. The company is increasing its full year 2015 production guidance by 8.0 MMcfe/d at the midpoint to 193.0 – 203.0 MMcfe/d from its previously announced guidance of 185.0 – 195.0 MMcfe/d The increase in full year production guidance is due to the better than expected performance of the company’s recently completed wells with increased sand concentrations.
| 2Q2015 | Full Year 2015 | |
| Production | 199.0 – 205.0 MMcfe/d | 193.0 – 203.0 MMcfe/d |
| Lease Operating Expense | $31.0 - $34.0 million | -- |
| Cash G&A(1) | $6.5 - $7.5 million | -- |
| Operational Capital Expenditures(2) | -- | $135.0 - $145.0 million |
| (1) Cash G&A guidance does not include G&A expenses related to Keystone Clearwater Solutions | ||
| (2) Land acquisition expense and capitalized interest are not included in the operational capital expenditures budget | ||
Conference Call Information
Management will host a live conference call and webcast on Wednesday, May 6, 2015 at 10:00 a.m. Eastern to review first quarter 2015 financial results and operational highlights. All financial results included in this release or discussed on the conference call are preliminary pending the completion by our independent auditors of the first quarter 2015 review. The telephone number to access the conference call is (866) 437-1772. Presentation slides containing reference materials for the call and webcast will be available on the company’s website, www.rexenergy.com, under the Investor Relations tab.
About Rex Energy Corporation
Rex Energy, headquartered in State College, Pennsylvania, 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.
Forward-Looking Statements
Except for historical information, statements made in this release, including those relating to the timing and nature of development plans; drilling and completion schedules; anticipated fracture stimulation activities; expected dates for placement of wells into sales; and our financial guidance for second quarter and full year 2015 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 may contain words such as "expected", "expects", "scheduled", "planned", "plans", "anticipates" or similar words. These statements are based on management's experience and perception of historical trends, current conditions, and anticipated future developments, as well as other factors believed to be appropriate. We believe these statements and the assumptions and estimates contained in this release are reasonable based on information that is currently available to us. However, management's assumptions and the company's future performance are subject to a wide range of business risks and uncertainties, both known and unknown, and we cannot assure that the company can or will meet the goals, expectations, and projections included in this release. Any number of factors could cause our actual results to be materially different from those expressed or implied in our forward looking statements, including (without limitation):
- economic conditions in the United States and globally;
- domestic and global demand for oil, NGLs and natural gas;
- volatility in oil, NGL, and natural gas pricing;
- new or changing government regulations, including those relating to environmental matters, permitting, or other aspects of our operations;
- the geologic quality of the company's properties with regard to, among other things, the existence of hydrocarbons in economic quantities;
- uncertainties inherent in the estimates of our oil and natural gas reserves;
- our ability to increase oil and natural gas production and income through exploration and development;
- drilling and operating risks;
- the success of our drilling techniques in both conventional and unconventional reservoirs;
- the success of the secondary and tertiary recovery methods we utilize or plan to employ in the future;
- the number of potential well locations to be drilled, the cost to drill them, and the time frame within which they will be drilled;
- 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 infrastructure, such as transportation, pipelines, processing and midstream services;
- the effects of adverse weather or other natural disasters on our operations;
- competition in the oil and gas industry in general, and specifically in our areas of operations;
- changes in our drilling plans and related budgets;
- the success of prospect development and property acquisition;
- the success of our business and financial strategies, and hedging strategies;
- conditions in the domestic and global capital and credit markets and their effect on us;
- the adequacy and availability of capital resources, credit, and liquidity including, but not limited to, access to additional borrowing capacity; and
- uncertainties related to the legal and regulatory environment for our industry, and our own legal proceedings and their 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.
REX ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS
($ in Thousands, Except Share and Per Share Data)
| ASSETS | March 31, 2015 (Unaudited) | December 31, 2014 | ||||||||||
| Current Assets | ||||||||||||
| Cash and Cash Equivalents | $ | 4,964 | $ | 17,978 | ||||||||
| Accounts Receivable | 33,386 | 43,936 | ||||||||||
| Taxes Receivable | 2 | 504 | ||||||||||
| Short-Term Derivative Instruments | 32,849 | 29,265 | ||||||||||
| Inventory, Prepaid Expenses and Other | 2,737 | 3,403 | ||||||||||
| Assets Held for Sale | 42,696 | 34,257 | ||||||||||
| Total Current Assets | 116,634 | 129,343 | ||||||||||
| Property and Equipment (Successful Efforts Method) | ||||||||||||
| Evaluated Oil and Gas Properties | 1,147,468 | 1,079,039 | ||||||||||
| Unevaluated Oil and Gas Properties | 335,279 | 322,413 | ||||||||||
| Other Property and Equipment | 46,732 | 46,361 | ||||||||||
| Wells and Facilities in Progress | 101,993 | 127,655 | ||||||||||
| Pipelines | 15,657 | 15,657 | ||||||||||
| Total Property and Equipment | 1,647,129 | 1,591,125 | ||||||||||
| Less: Accumulated Depreciation, Depletion and Amortization | (395,337 | ) | (366,917 | ) | ||||||||
| Net Property and Equipment | 1,251,792 | 1,224,208 | ||||||||||
| Deferred Financing Costs and Other Assets - Net | 17,058 | 17,070 | ||||||||||
| Equity Method Investments | 17,692 | 17,895 | ||||||||||
| Long-Term Derivative Instruments | 10,040 | 4,904 | ||||||||||
| Long-Term Deferred Tax Asset | 8,301 | 8,301 | ||||||||||
| Total Assets | $ | 1,421,517 | $ | 1,401,721 | ||||||||
| LIABILITIES AND EQUITY | ||||||||||||
| Current Liabilities | ||||||||||||
| Accounts Payable | $ | 45,116 | $ | 53,340 | ||||||||
| Current Maturities of Long-Term Debt | 1,056 | 1,176 | ||||||||||
| Accrued Liabilities | 56,559 | 59,478 | ||||||||||
| Short-Term Derivative Instruments | 1,393 | 421 | ||||||||||
| Current Deferred Tax Liability | 8,301 | 8,301 | ||||||||||
| Liabilities Related to Assets Held for Sale | 31,519 | 25,115 | ||||||||||
| Total Current Liabilities | 143,944 | 147,831 | ||||||||||
| Long-Term Derivative Instruments | 4,086 | 2,377 | ||||||||||
| Senior Secured Line of Credit and Long-Term Debt | 38,137 | 251 | ||||||||||
| 8.875% Notes Due 2020 | 350,000 | 350,000 | ||||||||||
| 6.25% Senior Notes Due 2022 | 325,000 | 325,000 | ||||||||||
| Premium on Senior Notes, Net | 2,632 | 2,725 | ||||||||||
| Other Deposits and Liabilities | 3,812 | 4,018 | ||||||||||
| Future Abandonment Cost | 39,040 | 38,146 | ||||||||||
| Total Liabilities | $ | 906,651 | $ | 870,348 | ||||||||
| Stockholders’ Equity | ||||||||||||
| Preferred Stock, $.001 par value per share, 100,000 shares authorized and 16,100 issued and outstanding on March 31, 2015 and December 31, 2014 | $ | 1 | $ | 1 | ||||||||
| Common Stock, $.001 par value per share, 100,000,000 shares authorized and 55,266,519 shares issued and outstanding on March 31, 2015 and 54,174,763 shares issued and outstanding on December 31, 2014 | 54 | 54 | ||||||||||
| Additional Paid-In Capital | 620,782 | 617,826 | ||||||||||
| Accumulated Deficit | (110,978 | ) | (90,749 | ) | ||||||||
| Rex Energy Stockholders’ Equity | 509,859 | 527,132 | ||||||||||
| Noncontrolling Interests | 5,007 | 4,241 | ||||||||||
| Total Stockholders’ Equity | 514,866 | 531,373 | ||||||||||
| Total Liabilities and Owners’ Equity | $ | 1,421,517 | $ | 1,401,721 | ||||||||
| REX ENERGY CORPORATION | ||||||||||
| CONSOLIDATED STATEMENTS OF OPERATIONS | ||||||||||
| (Unaudited, in Thousands, Except per Share Data) | ||||||||||
| Three Months Ending March 31, | ||||||||||
| 2015 | 2014 | |||||||||
| OPERATING REVENUE | ||||||||||
| Oil, Natural Gas and NGL Sales | $ | 54,111 | $ | 81,299 | ||||||
| Other Revenue | 11 | 44 | ||||||||
| TOTAL OPERATING REVENUE | 54,122 | 81,343 | ||||||||
| OPERATING EXPENSES | ||||||||||
| Production and Lease Operating Expense | 29,052 | 20,033 | ||||||||
| General and Administrative Expense | 9,651 | 9,562 | ||||||||
| Loss on Disposal of Asset | 65 | 72 | ||||||||
| Impairment Expense | 7,023 | 25 | ||||||||
| Exploration Expense | 518 | 2,060 | ||||||||
| Depreciation, Depletion, Amortization and Accretion | 26,126 | 19,723 | ||||||||
| Other Operating Expense | 5,191 | 83 | ||||||||
| TOTAL OPERATING EXPENSES | 77,626 | 51,558 | ||||||||
| INCOME (LOSS) FROM OPERATIONS | (23,504 | ) | 29,785 | |||||||
| OTHER EXPENSE | ||||||||||
| Interest Expense | (12,017 | ) | (6,933 | ) | ||||||
| Gain (Loss) on Derivatives, Net | 17,119 | (9,750 | ) | |||||||
| Other Income (Expense) | 34 | (37 | ) | |||||||
| Loss on Equity Method Investments | (203 | ) | (200 | ) | ||||||
| TOTAL OTHER INCOME (EXPENSE) | 4,933 | (16,920 | ) | |||||||
| INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX | (18,571 | ) | 12,865 | |||||||
| Income Tax (Expense) Benefit | 92 | (4,110 | ) | |||||||
| NET INCOME (LOSS) FROM CONTINUING OPERATIONS | (18,479 | ) | 8,755 | |||||||
| Income From Discontinued Operations, Net of Income Taxes | 1,962 | 1,682 | ||||||||
| NET INCOME (LOSS) | (16,517 | ) | 10,437 | |||||||
| Net Income Attributable to Noncontrolling Interests | 1,297 | 1,569 | ||||||||
| NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY | $ | (17,814 | ) | $ | 8,868 | |||||
| Preferred Stock Dividends | 2,415 | - | ||||||||
| NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS | $ | (20,229 | ) | $ | 8,868 | |||||
| Earnings per common share: | ||||||||||
| Basic – Net Income (Loss) From Continuing Operations Attributable to Rex Energy Common Shareholders | $ | (0.38 | ) | $ | 0.17 | |||||
| Basic – Net Income From Discontinued Operations Attributable to Rex Energy Common Shareholders | 0.01 | 0.00 | ||||||||
| Basic – Net Income (Loss) Attributable to Rex Energy Common Shareholders | $ | (0.37 | ) | $ | 0.17 | |||||
| Basic – Weighted Average Shares of Common Stock Outstanding | 54,370 | 52,984 | ||||||||
| Diluted – Net Income (Loss) From Continuing Operations Attributable to Rex Energy Common Shareholders | $ | (0.38 | ) | $ | 0.17 | |||||
| Diluted – Net Income From Discontinued Operations Attributable to Rex Energy Common Shareholders | 0.01 | 0.00 | ||||||||
| Diluted – Net Income (Loss) Attributable to Rex Energy Common Shareholders | $ | (0.37 | ) | $ | 0.17 | |||||
| Diluted – Weighted Average Shares of Common Stock Outstanding | 54,370 | 53,503 | ||||||||
| REX ENERGY CORPORATION | |||||||||
| CONSOLIDATED OPERATIONAL HIGHLIGHTS | |||||||||
| UNAUDITED | |||||||||
| Three Months Ending | |||||||||
| March 31, | |||||||||
| 2015 | 2014 | ||||||||
| Oil, Natural Gas, NGL and Ethane sales (in thousands): | |||||||||
| Oil and condensate sales | $ | 12,461 | $ | 23,306 | |||||
| Natural gas sales | 28,286 | 40,100 | |||||||
| Natural gas liquid sales (C3+) | 12,119 | 17,893 | |||||||
| Ethane sales | 1,245 | -- | |||||||
| Cash-settled derivatives: | |||||||||
| Crude oil | 3,745 | (421 | ) | ||||||
| Natural gas | 5,273 | (3,339 | ) | ||||||
| Natural gas liquids (C3+) | 1,540 | (1,485 | ) | ||||||
| Ethane | 22 | -- | |||||||
| Total oil, gas, NGL and ethane sales including cash settled derivatives | $ | 64,691 | $ | 76,054 | |||||
| Production during the period: | |||||||||
| Oil and condensate (Bbls) | 315,174 | 250,409 | |||||||
| Natural gas (Mcf) | 11,502,917 | 7,663,368 | |||||||
| Natural gas liquids (C3+) (Bbls) | 521,203 | 305,143 | |||||||
| Ethane (Bbls) | 189,155 | -- | |||||||
| Total (Mcfe)a | 17,656,109 | 10,996,680 | |||||||
| Production – average per day: | |||||||||
| Oil and condensate (Bbls) | 3,502 | 2,782 | |||||||
| Natural gas (Mcf) | 127,810 | 85,149 | |||||||
| Natural gas liquids (C3+) (Bbls) | 5,791 | 3,390 | |||||||
| Ethane (Bbls) | 2,102 | -- | |||||||
| Total (Mcfe)a | 196,179 | 122,185 | |||||||
| Average price per unit: | |||||||||
| Realized crude oil price per Bbl – as reported | $ | 39.54 | $ | 93.07 | |||||
| Realized impact from cash settled derivatives per Bbl | 11.88 | (1.68 | ) | ||||||
| Net realized price per Bbl | $ | 51.42 | $ | 91.39 | |||||
| Realized natural gas price per Mcf – as reported | $ | 2.46 | $ | 5.23 | |||||
| Realized impact from cash settled derivatives per Mcf | 0.46 | (0.43 | ) | ||||||
| Net realized price per Mcf | $ | 2.92 | $ | 4.80 | |||||
| Realized natural gas liquids (C3+) price per Bbl – as reported | $ | 23.25 | $ | 58.64 | |||||
| Realized impact from cash settled derivatives per Bbl | 2.96 | (4.87 | ) | ||||||
| Net realized price per Bbl | $ | 26.21 | $ | 53.77 | |||||
| Realized ethane price per Bbl – as reported | $ | 6.58 | $ | - | |||||
| Realized impact from cash settled derivatives per Bbl | 0.12 | - | |||||||
| Net realized price per Bbl | $ | 6.70 | $ | - | |||||
| LOE/Mcfe | $ | 1.65 | $ | 1.82 | |||||
| Cash G&A/Mcfe | $ | 0.38 | $ | 0.72 | |||||
| a Oil and natural gas liquids are converted at the rate of one barrel of oil equivalent to six Mcfe | |||||||||
| REX ENERGY CORPORATION | ||||||||
| COMMODITY DERIVATIVES – HEDGE POSITION AS OF 5/1/2015 | ||||||||
| 2015 | 2016 | |||||||
| Oil Derivatives (Bbls) | ||||||||
| Swap Contracts | ||||||||
| Volume | 10,000(1) | -- | ||||||
| Price | $ | 95.76 | $ | -- | ||||
| Collar Contracts | ||||||||
| Volume | 170,000 | 60,000 | ||||||
| Ceiling | $ | 62.97 | $ | 63.81 | ||||
| Floor | $ | 52.68 | $ | 53.75 | ||||
| Collar Contracts with Short Puts | ||||||||
| Volume | 400,000 | -- | ||||||
| Ceiling | $ | 72.50 | $ | -- | ||||
| Floor | $ | 65.00 | $ | -- | ||||
| Short Put | $ | 50.00 | $ | -- | ||||
| Put Spread Contracts | ||||||||
| Volume | 60,000 | 120,000 | ||||||
| Floor | $ | 83.33 | $ | 65.00 | ||||
| Short Put | $ | 73.08 | $ | 50.00 | ||||
| Natural Gas Derivatives (Mcf) | ||||||||
| Swap Contracts | ||||||||
| Volume | 20,350,000(2) | 12,030,000(3) | ||||||
| Price | $ | 3.58 | $ | 3.68 | ||||
| Swaption Contracts | ||||||||
| Volume | 2,300,000 | -- | ||||||
| Price | $ | 3.54 | $ | -- | ||||
| Put Spread | ||||||||
| Volume | 3,900,000 | 2,100,000 | ||||||
| Floor | $ | 3.32 | $ | 3.00 | ||||
| Short Put | $ | 2.56 | $ | 2.25 | ||||
| Collar Contracts | ||||||||
| Volume | -- | 900,000 | ||||||
| Ceiling | $ | -- | $ | 4.04 | ||||
| Floor | $ | -- | $ | 3.20 | ||||
| Collar Contracts with Short Puts | ||||||||
| Volume | 3,200,000 | 8,850,000 | ||||||
| Ceiling | $ | 3.92 | $ | 4.29 | ||||
| Floor | $ | 3.34 | $ | 3.42 | ||||
| Short Put | $ | 2.66 | $ | 2.66 | ||||
| Call Contracts | ||||||||
| Volume | 2,500,000 | 7,320,000 | ||||||
| Ceiling | $ | 3.95 | $ | 4.35 | ||||
| Natural Gas Liquids (Bbls) | ||||||||
| Swap Contracts | ||||||||
| Propane (C3) | ||||||||
| Volume | 438,000 | 255,000 | ||||||
| Price | $ | 29.40 | $ | 24.78 | ||||
| Butane (C4) | ||||||||
| Volume | 64,000 | 48,000 | ||||||
| Price | $ | 29.74 | $ | 31.63 | ||||
| Isobutane (IC4) | ||||||||
| Volume | 32,000 | 24,000 | ||||||
| Price | $ | 30.37 | $ | 31.88 | ||||
| Natural Gasoline (C5+) | ||||||||
| Volume | 112,000 | 120,000 | ||||||
| Price | $ | 48.26 | $ | 51.95 | ||||
| Ethane | ||||||||
| Volume | 253,500 | 120,000 | ||||||
| Price | $ | 8.40 | $ | 7.98 | ||||
| Natural Gas Basis (Mcf) | ||||||||
| Swap Contracts | ||||||||
| Dominion Appalachia4 | ||||||||
| Volume | 7,140,000 | 12,500,000 | ||||||
| Price | $ | (0.81 | ) | $ | (0.80 | ) | ||
| (1) Includes 10,000 Bbls of call-protected swaps | ||||||||
| (2) Includes 5.2 Bcf of enhanced swaps | ||||||||
| (3) Includes 3.6 Bcf of enhanced swaps | ||||||||
| (4) Financial derivatives only | ||||||||
APPENDIX
REX ENERGY CORPORATION
NON-GAAP MEASURES
EBITDAX
“EBITDAX” means, for any period, the sum of net income for such period plus the following expenses, charges or income to the extent deducted from or added to net income in such period: interest, income taxes, DD&A, unrealized losses from financial derivatives, non-recurring gains and losses, exploration expenses and other similar non-cash charges, minus all non-cash income, including but not limited to, income from unrealized financial derivatives and gains on asset dispositions, added to net income. EBITDAX, as defined above, is used as a financial measure by our management team and by other users of its financial statements, such as our commercial bank lenders to analyze such things as:
- Our operating performance and return on capital in comparison to those of other companies in our industry, without regard to financial or capital structure;
- The financial performance of our assets and valuation of the entity without regard to financing methods, capital structure or historical cost basis;
- Our ability to generate cash sufficient to pay interest costs, support our indebtedness and make cash distributions to our stockholders; and
- The viability of acquisitions and capital expenditure projects and the overall rates of 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) (the most directly comparable GAAP financial measure) in measuring our performance, nor should it be used as an exclusive measure of cash flows, 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 our consolidated statements of cash flows.
We have reported EBITDAX because it is a financial measure used by our 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 our computations of EBITDAX. While we have disclosed EBITDAX to permit a more complete comparative analysis of our operating performance and debt servicing ability relative to other companies, you are cautioned that EBITDAX as reported by us may not be comparable in all instances to EBITDAX as reported by other companies. EBITDAX amounts may not be fully available for management’s discretionary use, due to requirements to conserve funds for capital expenditures, debt service and other commitments.
We believe that EBITDAX assists our lenders and investors in comparing our performance on a consistent basis without regard to certain expenses, which can vary significantly depending upon accounting methods. Because we may borrow money to finance our operations, interest expense is a necessary element of our costs. In addition, because we use capital assets, DD&A are also necessary elements of our costs. Finally, we are required to pay federal and state taxes, which are necessary elements of our costs. Therefore, any measures that exclude these elements have material limitations.
To compensate for these limitations, we believe it is important to consider both net income determined under GAAP and EBITDAX to evaluate our performance.
For purposes of consistency with current calculations, we have revised certain amounts relating to prior period EBITDAX. The following table presents a reconciliation of our net income to EBITDAX for each of the periods presented.
| Three Months Ended March 31, | |||||||
| ($ in Thousands) | 2015 | 2014 | |||||
| Net Income (Loss) From Continuing Operations | $ | (18,479 | ) | $ | 8,755 | ||
| Add Back Non-Recurring Costs1 | 5,022 | — | |||||
| Add Back Depletion, Depreciation, Amortization and Accretion | 26,126 | 19,723 | |||||
| Add Back Non-Cash Compensation Expense | 2,961 | 1,650 | |||||
| Add Back Interest Expense | 12,017 | 6,933 | |||||
| Add Back Impairment Expense | 7,023 | 25 | |||||
| Add Back Exploration Expenses | 518 | 2,060 | |||||
| Add Back Loss on Disposal of Assets | 65 | 72 | |||||
| Add Back (Less) Loss (Gain) on Financial Derivatives | (17,119 | ) | 9,750 | ||||
| Add Back (Less) Cash Settlement of Derivatives | 11,079 | (4,877 | ) | ||||
| Add Back (Less) Income Tax Expense (Benefit) | (92 | ) | 4,110 | ||||
| Add Back Non-Cash Portion of Equity Method Investments | 203 | 200 | |||||
| EBITDAX From Continuing Operations | $ | 29,324 | $ | 48,401 | |||
| Net Income From Discontinued Operations | $ | 1,962 | $ | 1,682 | |||
| Income Attributable to Noncontrolling Interests | (1,297 | ) | (1,569 | ) | |||
| Income From Discontinued Operations Attributable to Rex Energy | 665 | 113 | |||||
| Add Back Depletion, Depreciation, Amortization and Accretion | 39 | 701 | |||||
| Add Back Interest Expense | 191 | 202 | |||||
| Less Gain on Disposal of Assets | (32 | ) | — | ||||
| Less Non-Cash Portion of Noncontrolling Interests | (79 | ) | (364 | ) | |||
| Add Back Income Tax Expense | 435 | 82 | |||||
| Add EBITDAX From Discontinued Operations | $ | 1,219 | $ | 734 | |||
| EBITDAX (Non-GAAP) | $ | 30,543 | $ | 49,135 | |||
| 1 Non-Recurring costs as of March 31, 2015 include approximately $5.0 million in fees incurred to terminate two drilling rig contracts earlier than their original term; the company has the option to recapture approximately 50% of the fees if the rig is utilized by the company or another party. | |||||||
Adjusted Net Income
“Adjusted Net Income” means, for any period, the sum of net income (loss) from continuing operations before income taxes 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, disposals of assets, impairment and other one-time or non-recurring charges, minus all gains from unrealized financial derivatives, disposal of assets and deferred income tax benefits, added to net income. Adjusted Net Income 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. Adjusted Net Income 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 reports Adjusted Net Income 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 Adjusted Net Income as reported by Rex Energy may not be comparable in all instances to that reported by other companies.
To compensate for these limitations, the company believes it is important to consider both net income determined under GAAP and Adjusted Net Income.
The following table presents a reconciliation of Rex Energy’s net income from continuing operations to its adjusted net income for each of the periods presented ($ in thousands):
| For the Three Months Ended | ||||||||
| March 31, | ||||||||
| 2015 | 2014 | |||||||
| Income (Loss) From Continuing Operations Before Income Taxes, as reported | $ | (18,571 | ) | $ | 12,865 | |||
| (Gain) Loss on Derivatives, Net | (17,119 | ) | 9,750 | |||||
| Cash Settlement of Derivatives | 11,079 | (4,877 | ) | |||||
| Add Back (Less) Unrealized (Gain) Loss from Financial Derivatives | (6,040 | ) | 4,873 | |||||
| Add Back Non-Recurring Costs1 | 5,022 | - | ||||||
| Add Back Impairment Expense | 7,023 | 25 | ||||||
| Add Back Dry Hole Expense | 1 | (86 | ) | |||||
| Add Back Non-Cash Compensation Expense | 2,961 | 1,650 | ||||||
| Add Back (Less) (Gain) Loss on Disposal of Assets | 65 | 72 | ||||||
| Income (Loss) Before Income Taxes, adjusted | $ | (9,539 | ) | $ | 19,399 | |||
| Less Income Tax (Expense) Benefit, adjusted2 | 3,816 | (7,760 | ) | |||||
| Adjusted Net Income (Loss) | $ | (5,723 | ) | $ | 11,639 | |||
| Basic – Adjusted Net Income Per Share | $ | (0.11 | ) | $ | 0.22 | |||
| Basic – Weighted Average Shares of Common Stock Outstanding | 54,370 | 52,984 | ||||||
| 1 Non- Recurring costs as of March 31, 2015 include approximately $5.0 million in fees incurred to terminate two drilling rig contracts earlier than their original term; the company has the option to recapture approximately 50% of the fees if the rig is utilized by the company or another party. | ||||||||
| 2 Assumes an effective tax rate of 40% | ||||||||
Cash General and Administrative Expenses
Cash General and Administrative Expenses (Cash G&A) is the difference between GAAP G&A and non-Cash G&A, which is primarily comprised of non-cash compensation expense. Rex Energy has reported Cash G&A because it believes that this measure is commonly reported and widely used by management and investors as an indicator of overhead efficiency without regard to non-cash expenditures, such as stock compensation. Cash G&A is not a calculation based on GAAP financial measures and should not be considered as an alternative to GAAP G&A in measuring the company’s performance. You should carefully consider the specific items included in the company’s computation of this measure. You are cautioned that Cash G&A as reported by Rex Energy may not be comparable in all instances to that reported by other companies.
To compensate for these limitations, the company believes it is important to consider both Cash G&A and GAAP G&A. The following table presents a reconciliation of Rex Energy’s GAAP G&A to its Cash G&A for each of the periods presented (in thousands):
| Three Months Ended March 31, | |||||||||||||||||
| 2015 | 2014 | ||||||||||||||||
| GAAP G&A | $ | 9,651 | $ | 9,562 | |||||||||||||
| Non-Cash Compensation Expense | (2,961 | ) | (1,650 | ) | |||||||||||||
| Cash G&A | $ | 6,690 | $ | 7,912 | |||||||||||||