Oasis Petroleum Inc. Announces Quarter Ended March 31, 2015 Earnings

HOUSTON, May 6, 2015 /PRNewswire/ -- Oasis Petroleum Inc. (NYSE: OAS) ("Oasis" or the "Company") today announced financial results for the quarter ended March 31, 2015 and provided an operational update.

Highlights include:

  • Exceeded production guidance range and increased average daily production to 50,446 barrels of oil equivalent per day ("Boepd"), an 18% increase over the first quarter of 2014 and a 1% sequential quarter increase.
  • Invested capital expenditures ("CapEx") of $271.1 million in the first quarter of 2015, compared to a CapEx budget of $271.1 million.
  • Completed and placed on production 23 gross (19.2 net) operated wells in the first quarter of 2015.
  • Decreased lease operating expenses ("LOE") per barrel of oil equivalent ("Boe") to $8.62, a 17% decrease from the first quarter of 2014 and an 11% sequential quarter decrease.
  • Reported Adjusted EBITDA of $208.9 million in the first quarter of 2015. For a definition of Adjusted EBITDA and a reconciliation of net income and net cash provided by operating activities to Adjusted EBITDA, see "Non-GAAP Financial Measures" below.
  • Completed a public offering of 36.8 million shares, raising $463.1 million of net proceeds for the Company on March 9, 2015.

"Oasis exceeded production guidance of 47,000 to 49,000 Boepd in the first quarter of 2015, as new wells brought on during the first quarter exceeded production expectations with over 60% of the wells completed with high intensity stimulation," said Thomas B. Nusz, Oasis' Chairman and Chief Executive Officer. "Based on our first quarter performance, we expect to produce between 47,000 and 49,000 Boepd in the second quarter of 2015 and to produce between 46,000 and 49,000 Boepd for the full year 2015. Additionally, CapEx tracked in line with our budget, with drilling and completion capital coming in at $216.6 million, or $8.3 million below our budget. There were some timing differences on a few non-drilling and completion items, and we remain on track to spend our $705 million CapEx budget for 2015. Well costs are trending below our original 2015 estimates, as the team has driven down the cost for high intensity completions to approximately $9.0 million per well."

Mr. Nusz added, "The White Unit in Wild Basin, our first multi-slickwater test, continues to outperform the high-end of our type curve. The test included seven wells in a portion of a single DSU, all completed with slickwater completions. The Middle Bakken well has produced approximately 256,000 Boe through 216 days and the wells in the first bench of the Three Forks have produced on average 167,000 Boe through 192 days.  Additionally, we completed our first high volume proppant test in Alger, which is the 17,000 net acre southern subsection of South Cottonwood where we have 18 DSUs included in our core inventory. The Helling Trust has two new Middle Bakken wells that have produced on average 139,000 Boe through 88 days and a well completed in the first bench of the Three Forks wells that has produced 104,000 Boe through 87 days.  All of the Middle Bakken and Three Forks wells in both the White Unit and the Helling Trust have early time production that is trending over double our corresponding production data for our 750,000 Boe Middle Bakken type curve and our 600,000 Boe Three Forks type curve, respectively. The continued outperformance of both of these high intensity completion tests continues to provide us with confidence in our plans to target our core area with high intensity completions."

Taylor Reid, Oasis' President and Chief Operating Officer added, "We have driven LOE down to $8.62 per Boe, the lowest level we have delivered since our acquisition during 2013 and 15% below 2014 levels. We have been successful at lowering operating costs as we focus completions in areas with existing salt water pipeline and disposal infrastructure as well as improving run time on our producing wells. We increased connectivity to our OMS infrastructure in the first quarter of 2015 and now have 58% of our wells connected. We are updating our LOE guidance for the year to $9.00 to $10.00, based on confidence around recent performance."

"We also continue to increase our financial flexibility completing a $463 million equity offering in early March as well as amending our credit facility to increase the term to five years and to increase the committed level to $1.525 billion.  We have over $1.3 billion of liquidity even as we drill within cash flow for the remainder of the year," said Mr. Reid.

Operational and Financial Update

During the quarter ending March 31, 2015, the Company brought 23 gross (19.2 net) operated and 0.9 net non-operated wells on production in the Williston Basin, in line with its budget. As of March 31, 2015, the Company had five rigs running and 91 gross operated wells awaiting completion in the Williston Basin.

The Company's average daily production and revenues are detailed in the following table:

 


Quarter Ended:


3/31/2015


12/31/2014


3/31/2014 (1)

Production (Boepd)

50,446



50,143



42,856


Percent Oil

88.6

%


89.4

%


89.4

%

Average oil sales price, without derivative settlements (per Bbl)

$

40.73



$

62.79



$

89.66


Revenues ($ in thousands):






Oil

$

163,813



$

258,913



$

309,231


Natural gas

10,046



14,356



22,616


Well services (OWS)

2,708



22,980



15,827


Midstream (OMS)

3,820



3,423



1,845


Total revenues

$

180,387



$

299,672



$

349,519




(1)

Includes production from certain non-operated properties in and around the Company's Sanish position until the properties were sold in March 2014 (the "Sanish Divestiture").

 

Total revenues for the first quarter of 2015 decreased by 40% compared to the fourth quarter of 2014, primarily due to lower oil and natural gas prices in the first quarter of 2015. In the first quarter of 2015, as NYMEX West Texas Intermediate ("WTI") crude oil prices further declined, the Company's price differentials continued to increase as a percentage of WTI but decreased in terms of the dollar per barrel discount to WTI to an average of $7.85 per barrel of oil during the first quarter of 2015 compared to $9.74 per barrel of oil during the fourth quarter of 2014. The Company expects its price differential to WTI to narrow in the second quarter of 2015 to $6.50 to $7.50 per barrel.

The Company's operating expenses are detailed in the following table:


Quarter Ended:


3/31/2015


12/31/2014


3/31/2014

Operating expenses ($ in thousands):






Lease operating expenses (LOE)

$

39,125



$

44,697



$

39,989


Well services (OWS)

1,054



14,474



10,359


Midstream (OMS)

898



1,167



561


Marketing, transportation and gathering expenses (1)

7,282



6,843



5,932


Non-cash valuation charges

(4)



2,684



(746)


Total operating expenses

$

48,355



$

69,865



$

56,095


Operating expenses ($ per Boe):






Lease operating expenses (LOE)

$

8.62



$

9.69



$

10.37


Marketing, transportation and gathering expenses (1)


1.60




1.48




1.53




(1)

Excludes non-cash valuation charges on pipeline imbalances and linefill inventory.

 

The sequential quarter-over-quarter decrease in LOE per Boe was primarily due to lower water volumes produced as well as more salt water disposal volumes going to Oasis Midstream Services ("OMS") disposal wells, decreased workover costs and lower LOE on non-operated volumes.

Marketing, transportation and gathering expenses, excluding non-cash valuation charges, totaled $7.3 million in the first quarter of 2015, $5.9 million in the first quarter of 2014 and $6.8 million in the fourth quarter of 2014. While transporting volumes through third-party oil gathering pipelines increases marketing, transportation and gathering expenses, it improves oil price realizations by reducing transportation costs included in the Company's oil price differential for sales at the wellhead. Currently, the Company is flowing 79% of its gross operated oil production through these gathering systems.

Production taxes as a percentage of oil and gas revenues were 9.6% in both the first quarters of 2015 and 2014 and 9.8% in the fourth quarter of 2014.

Depreciation, depletion and amortization expenses ("DD&A") totaled $118.5 million in the first quarter of 2015, $91.3 million in the first quarter of 2014 and $116.8 million in the fourth quarter of 2014. DD&A was $26.10 per Boe in the first quarter of 2015, $23.66 per Boe in the first quarter of 2014 and $25.32 per Boe in the fourth quarter of 2014. The increase in the DD&A rate was primarily due to an increase in the drilling program in the Three Forks formation, including lower benches, in the second half of 2014. In addition, during the first two months of 2014, the Company had production from the wells sold in the Sanish Divestiture, but these wells were not depreciated because the assets were held for sale, which lowered DD&A by $0.78 per Boe in the first quarter of 2014.

General and administrative ("G&A") expenses totaled $23.3 million in the first quarter of 2015, $23.5 million in the first quarter of 2014 and $24.1 million in the fourth quarter of 2014. G&A expenses were $5.14 per Boe in the first quarter of 2015, $6.10 per Boe in the first quarter of 2014 and $5.23 per Boe in the fourth quarter of 2014. Amortization of stock-based compensation, which is included in G&A expenses, was $7.6 million, or $1.68 per Boe, in the first quarter of 2015 as compared to $4.5 million, or $1.17 per Boe, in the first quarter of 2014 and $5.5 million, or $1.20 per Boe, in the fourth quarter of 2014.

As a result of its derivative activities and forward oil price changes, the Company incurred a $47.1 million net gain on derivative instruments, including net cash settlement receipts of $109.3 million, for the first quarter of 2015 and a $306.8 million net gain on derivative instruments, including net cash settlement receipts of $31.5 million, for the fourth quarter of 2014. The net cash settlement receipts from derivative instruments of $109.3 million in the first quarter of 2015 included $33.1 million, $41.6 million and $34.6 million from the settlements of contracts in December 2014, January 2015 and February 2015, respectively. The Company's derivative instruments do not qualify for and were not designated as hedging instruments for accounting purposes.

Interest expense was $38.8 million for the first quarter of 2015 compared to $40.2 million for the first quarter of 2014 and $39.8 million for the fourth quarter of 2014. The $1.0 million sequential quarter decrease was primarily due an increase in capitalized interest in the first quarter of 2015. Capitalized interest totaled $3.9 million for the first quarter of 2015, $1.6 million for the first quarter of 2014 and $2.7 million for the fourth quarter of 2014.

For the three months ended March 31, 2015, the Company recorded an income tax benefit of $7.4 million, resulting in a 29.0% effective tax rate as a percentage of its pre-tax loss for the quarter. The Company's income tax expense for the three months ended December 31, 2014 was recorded at 37.6% of pre-tax net income. While the 2014 effective tax rate was consistent with the statutory tax rate applicable to the U.S. and the blended state rate for the states in which the Company conducts business, the rate for the three months ended March 31, 2015 was lower due to permanent differences between the compensation amounts expensed for book purposes versus the amounts deductible for income tax purposes.

Adjusted EBITDA for the first quarter of 2015 was $208.9 million, a 13% decrease from the first quarter of 2014 of $239.8 million, and a decrease of 5% from the fourth quarter of 2014 of $219.5 million. For a definition of Adjusted EBITDA and a reconciliation of net income and net cash provided by operating activities to Adjusted EBITDA, see "Non-GAAP Financial Measures" below.

For the first quarter of 2015, the Company reported a net loss of $18.0 million, or $0.17 per diluted share, as compared to net income of $170.0 million, or $1.70 per diluted share, for the first quarter of 2014. Excluding certain non-cash or non-recurring items and their tax effect in the first quarter of 2015 and 2014, Adjusted Net Income (non-GAAP) was $30.6 million, or $0.28 per diluted share, and $64.8 million, or $0.65 per diluted share, respectively. For a definition of Adjusted Net Income and a reconciliation of net income to Adjusted Net Income, see "Non-GAAP Financial Measures" below.

Capital Expenditures

The following table depicts the Company's total CapEx by category:


1Q 2015

CapEx ($ in thousands):


Exploration and production

$

225,499


OMS

35,778


OWS

2,023


Other CapEx (1)

7,805


Total CapEx (2)

$

271,105




(1)

Other CapEx includes such items as administrative capital and capitalized interest.

(2)

CapEx reflected in the table above differs from the amounts shown in the statement of cash flows in the Company's condensed consolidated financial statements because amounts reflected in the table above include changes in accrued liabilities from the previous reporting period for capital expenditures, while the amounts presented in the statement of cash flows are presented on a cash basis.

Liquidity

On March 9, 2015, the Company completed a public offering of 36.8 million shares, raising $463.1 million of net proceeds. On March 31, 2015, Oasis had total cash and cash equivalents of $10.2 million. As of March 31, 2015, the Company had $165.0 million of borrowings and $5.2 million of outstanding letters of credit issued under its revolving credit facility, resulting in an unused borrowing base capacity of $1,329.8 million.

On April 13, 2015, the Company entered into its third amendment to its revolving credit facility (the "Third Amendment"), which extended the maturity date of the facility to April 13, 2020, provided that the Company's senior unsecured notes due February 1, 2019 are retired or refinanced 90 days prior to their maturity. In connection with the Third Amendment, the lenders completed their regular semi-annual redetermination of the borrowing base scheduled for April 1, 2015. The borrowing base was set at $1,700.0 million. The Company increased the lenders' aggregate elected commitment from $1,500.0 million to $1,525.0 million. The lenders' aggregate commitment can be increased to the full $1,700.0 million borrowing base by increasing the commitment of one or more lenders.

Hedging Activity

As of May 6, 2015, the Company had the following outstanding commodity derivative contracts, all of which are priced off of WTI and settle monthly:



Weighted Average Prices ($/Bbl)





Floor


Ceiling


BOPD

First Half 2015







Swaps


$

90.67



$

90.67



19,000


Two-way collars


$

87.14



$

102.19



7,000


Deferred premium puts(1)


$

87.45





6,000


Total 1H15 hedges (weighted average)


$

89.30



$

93.77



32,000









Second Half 2015







Swaps


$

76.68



$

76.68



18,000


Two-way collars


$

86.00



$

103.42



5,000


Total 2H15 hedges (weighted average)


$

78.71



$

82.49



23,000









First Half 2016







Swaps


$

64.98



$

64.98



2,000


Total 1H16 hedges (weighted average)


$

64.98



$

64.98



2,000









Second Half 2016







Swaps


$

65.10



$

65.10



1,000


Total 2H16 hedges (weighted average)


$

65.10



$

65.10



1,000




(1)

Floor price is net of deferred premium of $2.55.

Conference Call Information

Investors, analysts and other interested parties are invited to listen to the conference call:

Date:


Thursday, May 7, 2015

Time:


10:00 a.m. Central Time

Dial-in:


888-317-6003

Intl. Dial in:


412-317-6061

Conference ID:


7143557

Website:


www.oasispetroleum.com

 

A recording of the conference call will be available beginning at 12:00 p.m. Central Time on the day of the call and will be available until Thursday, May 14, 2015 by dialing:

Replay dial-in:


877-344-7529

Intl. replay:


412-317-0088

Replay code:


10064003

 

The conference call will also be available for replay at www.oasispetroleum.com.

Forward-Looking Statements

This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include the expectations of plans, strategies, objectives and anticipated financial and operating results of the Company, including the Company's drilling program, production, derivative instruments, capital expenditure levels and other guidance included in this press release. These statements are based on certain assumptions made by the Company based on management's experience and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. These include, but are not limited to, changes in oil and natural gas prices, weather and environmental conditions, the timing of planned capital expenditures, availability of acquisitions, uncertainties in estimating proved reserves and forecasting production results, operational factors affecting the commencement or maintenance of producing wells, the condition of the capital markets generally, as well as the Company's ability to access them, the proximity to and capacity of transportation facilities, and uncertainties regarding environmental regulations or litigation and other legal or regulatory developments affecting the Company's business and other important factors that could cause actual results to differ materially from those projected as described in the Company's reports filed with the SEC.

Any forward-looking statement speaks only as of the date on which such statement is made and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.

About Oasis Petroleum Inc.

Oasis is an independent exploration and production company focused on the acquisition and development of unconventional oil and natural gas resources, primarily operating in the Williston Basin. For more information, please visit the Company's website at www.oasispetroleum.com.

 

Oasis Petroleum Inc.

Condensed Consolidated Balance Sheet

(Unaudited)






March 31, 2015


December 31, 2014


(In thousands, except share data)

ASSETS




Current assets




Cash and cash equivalents

$

10,188



$

45,811


Accounts receivable — oil and gas revenues

112,785



130,934


Accounts receivable — joint interest partners

130,384



175,537


Inventory

21,956



21,354


Prepaid expenses

16,954



14,273


Derivative instruments

253,320



302,159


Other current assets

1,000



6,539


Total current assets

546,587



696,607


Property, plant and equipment




Oil and gas properties (successful efforts method)

6,187,638



5,966,140


Other property and equipment

356,940



313,439


Less: accumulated depreciation, depletion, amortization and impairment

(1,215,216)



(1,092,793)


Total property, plant and equipment, net

5,329,362



5,186,786


Derivative instruments



13,348


Deferred costs and other assets

40,988



41,671


Total assets

$

5,916,937



$

5,938,412


LIABILITIES AND STOCKHOLDERS' EQUITY




Current liabilities




Accounts payable

$

9,339



$

20,958


Revenues and production taxes payable

210,478



209,890


Accrued liabilities

314,211



410,379


Accrued interest payable

24,677



49,786


Deferred income taxes

77,746



97,499


Advances from joint interest partners

5,788



6,616


Total current liabilities

642,239



795,128


Long-term debt

2,365,000



2,700,000


Deferred income taxes

539,146



526,770


Asset retirement obligations

42,980



42,097


Other liabilities

3,327



2,116


Total liabilities

3,592,692



4,066,111


Commitments and contingencies




Stockholders' equity




Common stock, $0.01 par value: 300,000,000 shares authorized; 139,619,087 and 101,627,296 shares issued at March 31, 2015 and December 31, 2014, respectively

1,372



1,001


Treasury stock, at cost: 397,732 and 285,677 shares at March 31, 2015 and December 31, 2014, respectively

(12,191)



(10,671)


Additional paid-in capital

1,478,336



1,007,202


Retained earnings

856,728



874,769


Total stockholders' equity

2,324,245



1,872,301


Total liabilities and stockholders' equity

$

5,916,937



$

5,938,412


 

Oasis Petroleum Inc.

Condensed Consolidated Statement of Operations

(Unaudited)






Three Months Ended March 31,



2015


2014



(In thousands, except per share data)

Revenues





Oil and gas revenues


$

173,859



$

331,847


Well services and midstream revenues


6,528



17,672


Total revenues


180,387



349,519


Expenses





Lease operating expenses


39,125



39,989


Well services and midstream operating expenses


1,952



10,920


Marketing, transportation and gathering expenses


7,278



5,186


Production taxes


16,621



31,803


Depreciation, depletion and amortization


118,478



91,272


Exploration expenses


843



380


Rig termination


1,080




Impairment of oil and gas properties


5,321



762


General and administrative expenses


23,324



23,520


Total expenses


214,022



203,832


Gain on sale of properties




183,393


Operating income (loss)


(33,635)



329,080


Other income (expense)





Net gain (loss) on derivative instruments


47,072



(17,603)


Interest expense, net of capitalized interest


(38,784)



(40,158)


Other income (expense)


(70)



153


Total other income (expense)


8,218



(57,608)


Income (loss) before income taxes


(25,417)



271,472


Income tax benefit (expense)


7,376



(101,519)


Net income (loss)


$

(18,041)



$

169,953


Earnings (loss) per share:





Basic


$

(0.17)



$

1.71


Diluted


(0.17)



1.70


Weighted average shares outstanding:





Basic


109,303



99,560


Diluted


109,303



100,049


 

Oasis Petroleum Inc.

Selected Financial and Operational Statistics

(Unaudited)




Three Months Ended March 31,


2015


2014

Operating results ($ in thousands):




Revenues




Oil

$

163,813



$

309,231


Natural gas

10,046



22,616


Well services and midstream

6,528



17,672


Total revenues

$

180,387



$

349,519


Production data:




Oil (MBbls)

4,022



3,449


Natural gas (MMcf)

3,107



2,448


Oil equivalents (MBoe)

4,540



3,857


Average daily production (Boe/d)

50,446



42,856


Average sales prices:




Oil, without derivative settlements (per Bbl)

$

40.73



$

89.66


Oil, with derivative settlements (per Bbl) (1)

67.89



89.01


Natural gas (per Mcf) (2)

3.23



9.24


Costs and expenses (per Boe of production):




Lease operating expenses

$

8.62



$

10.37


Marketing, transportation and gathering expenses (3)

1.60



1.53


Production taxes

3.66



8.25


Depreciation, depletion and amortization

26.10



23.66


General and administrative expenses

5.14



6.10




(1)

Realized prices include gains or losses on cash settlements for commodity derivatives, which do not qualify for and were not designated as hedging instruments for accounting purposes.

(2)

Natural gas prices include the value for natural gas and natural gas liquids.

(3)

Excludes non-cash valuation charges on pipeline imbalances.

 

Oasis Petroleum Inc.

Condensed Consolidated Statement of Cash Flows

(Unaudited)




Three Months Ended March 31,



2015


2014



(In thousands)

Cash flows from operating activities:




Net income (loss)

$

(18,041)



$

169,953


Adjustments to reconcile net income (loss) to net cash provided by operating activities:




Depreciation, depletion and amortization

118,478



91,272


Gain on sale of properties



(183,393)


Impairment of oil and gas properties

5,321



762


Deferred income taxes

(7,376)



98,753


Derivative instruments

(47,072)



17,603


Stock-based compensation expenses

7,606



4,505


Deferred financing costs amortization and other

1,655



1,487


Working capital and other changes:




Change in accounts receivable

63,313



(9,275)


Change in inventory

(602)



790


Change in prepaid expenses

1,892



(14,259)


Change in other current assets

5,539



(29)


Change in other assets



(1,593)


Change in accounts payable and accrued liabilities

(42,341)



29,007


Change in other current liabilities



2,766


Change in other liabilities

(11)



(82)


Net cash provided by operating activities

88,361



208,267


Cash flows from investing activities:




Capital expenditures

(359,113)



(280,895)


Proceeds from sale of properties



321,943


Costs related to sale of properties



(2,010)


Derivative settlements

109,259



(2,239)


Advances from joint interest partners

(828)



(1,898)


Net cash provided by (used in) investing activities

(250,682)



34,901


Cash flows from financing activities:




Proceeds from sale of common stock

463,218




Proceeds from revolving credit facility

145,000




Principal payments on revolving credit facility

(480,000)



(275,570)


Purchases of treasury stock

(1,520)



(3,025)


Other



(176)


Net cash provided by (used in) financing activities

126,698



(278,771)


Decrease in cash and cash equivalents

(35,623)



(35,603)


Cash and cash equivalents:




Beginning of period

45,811



91,901


End of period

$

10,188



$

56,298


Supplemental non-cash transactions:




Change in accrued capital expenditures

$

(90,189)



$

39,516


Change in asset retirement obligations

1,413



(128)


 

Non-GAAP Financial Measures

Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of the Company's consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. The Company defines Adjusted EBITDA as earnings before interest expense, income taxes, depreciation, depletion, amortization, exploration expenses and other similar non-cash or non-recurring charges. Adjusted EBITDA is not a measure of net income or cash flows as determined by United States generally accepted accounting principles, or GAAP.

The following table presents reconciliations of the GAAP financial measures of net income and net cash provided by operating activities to the non-GAAP financial measure of Adjusted EBITDA for the periods presented:


Three Months Ended March 31,


2015


2014


(In thousands)

Net income (loss)

$

(18,041)



$

169,953


Gain on sale of properties



(183,393)


Net (gain) loss on derivative instruments

(47,072)



17,603


Derivative settlements (1)

109,259



(2,239)


Interest expense, net of capitalized interest

38,784



40,158


Depreciation, depletion and amortization

118,478



91,272


Impairment of oil and gas properties

5,321



762


Rig termination

1,080




Exploration expenses

843



380


Stock-based compensation expenses

7,606



4,505


Income tax expense

(7,376)



101,519


Other non-cash adjustments

(4)



(746)


Adjusted EBITDA

$

208,878



$

239,774






Net cash provided by operating activities

$

88,361



$

208,267


Derivative settlements (1)

109,259



(2,239)


Interest expense, net of capitalized interest

38,784



40,158


Rig termination

1,080




Exploration expenses

843



380


Deferred financing costs amortization and other

(1,655)



(1,487)


Current tax expense



2,766


Changes in working capital

(27,790)



(7,325)


Other non-cash adjustments

(4)



(746)


Adjusted EBITDA

$

208,878



$

239,774




(1)

Cash settlements represent the cumulative gains and losses on the Company's derivative instruments for the periods presented and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled.

 

The following tables present reconciliations of the GAAP financial measure of income before income taxes to the non-GAAP financial measure of Adjusted EBITDA for the Company's three reportable business segments on a gross basis for the periods presented:



Exploration and Production



Three Months Ended

March 31,



2015


2014



(In thousands)

Income (loss) before income taxes


$

(34,008)



$

265,285


Gain on sale of properties




(183,393)


Net (gain) loss on derivative instruments


(47,072)



17,603


Derivative settlements(1)


109,259



(2,239)


Interest expense, net of capitalized interest


38,784



40,158


Depreciation, depletion and amortization


117,540



90,228


Impairment of oil and gas properties


5,321



762


Rig termination


1,080




Exploration expenses


843



380


Stock-based compensation expenses


7,542



4,428


Other non-cash adjustments


(4)



(746)


Adjusted EBITDA


$

199,285



$

232,466




(1)

Cash settlements represent the cumulative gains and losses on the Company's derivative instruments for the periods presented and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled.

 



Well Services



Three Months Ended March 31,



2015


2014



(In thousands)

Income before income taxes


$

9,608



$

13,504


Depreciation, depletion and amortization


4,518



2,635


Stock-based compensation expenses


543



253


Adjusted EBITDA


$

14,669



$

16,392










Midstream Services



Three Months Ended March 31,



2015


2014



(In thousands)

Income before income taxes


$

9,289



$

4,632


Depreciation, depletion and amortization


1,186



851


Stock-based compensation expenses


204




Adjusted EBITDA


$

10,679



$

5,483


 

Adjusted Net Income and Adjusted Diluted Earnings Per Share are supplemental non-GAAP financial measures that are used by management and external users of the Company's consolidated financial statements, such as industry analysts, investors, lenders and rating agencies. The Company defines Adjusted Net Income as net income after adjusting first for (1) the impact of certain non-cash and non-recurring items, including non-cash changes in the fair value of derivative instruments, impairment of oil and gas properties, and other similar non-cash and non-recurring charges, and then (2) the non-cash and non-recurring items' impact on taxes based on the Company's effective tax rate in the same period. Adjusted Net Income is not a measure of net income as determined by GAAP. The Company defines Adjusted Diluted Earnings Per Share as Adjusted Net Income divided by diluted weighted average shares outstanding.

The following table presents reconciliations of the GAAP financial measure of net income to the non-GAAP financial measure of Adjusted Net Income and the GAAP financial measure of diluted earnings per share to the non-GAAP financial measure of Adjusted Diluted Earnings Per Share for the periods presented:


Three Months Ended March 31,


2015


2014


(In thousands, except per share data)

Net income (loss)

$

(18,041)



$

169,953


Gain on sale of properties



(183,393)


Net gain (loss) on derivative instruments

(47,072)



17,603


Derivative settlements (1)

109,259



(2,239)


Impairment of oil and gas properties

5,321



762


Rig termination

1,080




Other non-cash adjustments

(4)



(746)


Tax impact (2)

(19,903)



62,830


Adjusted Net Income

$

30,640



$

64,770






Diluted earnings per share

$

(0.17)



$

1.70


Gain on sale of properties



(1.83)


Net gain (loss) on derivative instruments

(0.43)



0.18


Derivative settlements (1)

1.00



(0.02)


Impairment of oil and gas properties

0.05



0.01


Rig termination

0.01




Other non-cash adjustments



(0.01)


Tax impact (2)

(0.18)



0.62


Adjusted Diluted Earnings Per Share

$

0.28



$

0.65






Diluted weighted average shares outstanding

109,303



100,049






Effective tax rate

29.0

%


37.4

%



(1)

Cash settlements represent the cumulative gains and losses on the Company's derivative instruments for the periods presented and do not include a recovery of costs that were paid to acquire or modify the derivative instruments that were settled.

(2)

The tax impact is computed utilizing the Company's effective tax rate on the adjustments for certain non-cash and non-recurring items.

 

 

SOURCE Oasis Petroleum Inc.

For further information: Oasis Petroleum Inc., Richard Robuck, (281) 404-9600, Vice President - Finance and Treasurer