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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
FORM 10-Q
 
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2014
or
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from                  to                 
Commission file number: 1-34776

Oasis Petroleum Inc.
(Exact name of registrant as specified in its charter)
 
 
 
 
Delaware
 
80-0554627
(State or other jurisdiction of
incorporation or organization)
 
(I.R.S. Employer
Identification No.)
 
 
1001 Fannin Street, Suite 1500
Houston, Texas
 
77002
(Address of principal executive offices)
 
(Zip Code)

(281) 404-9500
(Registrant’s telephone number, including area code)
 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes   ý    No   ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  ý    No   ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. 
Large accelerated filer
ý
Accelerated filer
¨
 
 
 
 
Non-accelerated filer
o  (Do not check if a smaller reporting company)
Smaller reporting company
¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨     No   ý
Number of shares of the registrant’s common stock outstanding at August 1, 2014: 101,153,956 shares.
 
 
 
 
 




OASIS PETROLEUM INC.
FORM 10-Q
FOR THE QUARTER ENDED JUNE 30, 2014
TABLE OF CONTENTS
 
 
Page



PART I — FINANCIAL INFORMATION
Item 1. — Financial Statements (Unaudited)
Oasis Petroleum Inc.
Condensed Consolidated Balance Sheet
(Unaudited)
 
June 30, 2014
 
December 31, 2013
 
(In thousands, except share data)
ASSETS
 
 
 
Current assets
 
 
 
Cash and cash equivalents
$
26,957

 
$
91,901

Accounts receivable — oil and gas revenues
216,764

 
175,653

Accounts receivable — joint interest partners
147,056

 
139,459

Inventory
17,636

 
20,652

Prepaid expenses
8,907

 
10,191

Deferred income taxes
25,390

 
6,335

Derivative instruments

 
2,264

Advances to joint interest partners
97

 
760

Other current assets
421

 
391

Total current assets
443,228

 
447,606

Property, plant and equipment
 
 
 
Oil and gas properties (successful efforts method)
5,141,582

 
4,528,958

Other property and equipment
231,129

 
188,468

Less: accumulated depreciation, depletion, amortization and impairment
(823,500
)
 
(637,676
)
Total property, plant and equipment, net
4,549,211

 
4,079,750

Assets held for sale

 
137,066

Derivative instruments

 
1,333

Deferred costs and other assets
44,540

 
46,169

Total assets
$
5,036,979

 
$
4,711,924

LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
Current liabilities
 
 
 
Accounts payable
$
32,402

 
$
8,920

Revenues and production taxes payable
217,414

 
146,741

Accrued liabilities
288,813

 
241,830

Accrued interest payable
49,444

 
47,910

Derivative instruments
62,415

 
8,188

Advances from joint interest partners
6,910

 
12,829

Other current liabilities
3,311

 

Total current liabilities
660,709

 
466,418

Long-term debt
2,300,000

 
2,535,570

Deferred income taxes
460,897

 
323,147

Asset retirement obligations
37,542

 
35,918

Derivative instruments
11,844

 
139

Other liabilities
1,963

 
2,183

Total liabilities
3,472,955

 
3,363,375

Commitments and contingencies (Note 14)

 

Stockholders’ equity
 
 
 
Common stock, $0.01 par value: 300,000,000 shares authorized; 101,396,597 and 100,866,589 shares issued at June 30, 2014 and December 31, 2013, respectively
999

 
996

Treasury stock, at cost: 244,729 and 167,155 shares at June 30, 2014 and December 31, 2013, respectively
(8,677
)
 
(5,362
)
Additional paid-in capital
995,024

 
985,023

Retained earnings
576,678

 
367,892

Total stockholders’ equity
1,564,024

 
1,348,549

Total liabilities and stockholders’ equity
$
5,036,979

 
$
4,711,924

The accompanying notes are an integral part of these condensed consolidated financial statements.

1


Oasis Petroleum Inc.
Condensed Consolidated Statement of Operations
(Unaudited)
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
2014
 
2013
 
2014
 
2013
 
(In thousands, except per share data)
Revenues
 
 
 
 
 
 
 
Oil and gas revenues
$
354,182

 
$
241,842

 
$
686,029

 
$
483,493

Well services and midstream revenues
18,196

 
12,740

 
35,868

 
19,393

Total revenues
372,378

 
254,582

 
721,897

 
502,886

Expenses
 
 
 
 
 
 
 
Lease operating expenses
40,553

 
18,266

 
80,542

 
37,755

Well services and midstream operating expenses
8,769

 
6,644

 
19,689

 
9,558

Marketing, transportation and gathering expenses
7,114

 
10,779

 
12,300

 
14,168

Production taxes
34,493

 
21,397

 
66,296

 
43,486

Depreciation, depletion and amortization
97,276

 
66,790

 
188,548

 
133,051

Exploration expenses
475

 
392

 
855

 
2,249

Impairment of oil and gas properties
42

 
208

 
804

 
706

General and administrative expenses
20,751

 
16,656

 
44,271

 
30,510

Total expenses
209,473

 
141,132

 
413,305

 
271,483

Gain on sale of properties
3,640

 

 
187,033

 

Operating income
166,545

 
113,450

 
495,625

 
231,403

Other income (expense)
 
 
 
 
 
 
 
Net gain (loss) on derivative instruments
(65,570
)
 
12,591

 
(83,173
)
 
(2,021
)
Interest expense, net of capitalized interest
(38,990
)
 
(21,392
)
 
(79,148
)
 
(42,575
)
Other income (expense)
135

 
294

 
288

 
1,074

Total other income (expense)
(104,425
)
 
(8,507
)
 
(162,033
)
 
(43,522
)
Income before income taxes
62,120

 
104,943

 
333,592

 
187,881

Income tax expense
23,287

 
37,824

 
124,806

 
68,911

Net income
$
38,833

 
$
67,119

 
$
208,786

 
$
118,970

Earnings per share:
 
 
 
 
 
 
 
Basic (Note 12)
$
0.39

 
$
0.73

 
$
2.10

 
$
1.29

Diluted (Note 12)
0.39

 
0.72

 
2.08

 
1.28

Weighted average shares outstanding:
 
 
 
 
 
 
 
Basic (Note 12)
99,663

 
92,399

 
99,612

 
92,387

Diluted (Note 12)
100,260

 
92,702

 
100,328

 
92,812

The accompanying notes are an integral part of these condensed consolidated financial statements.


2


Oasis Petroleum Inc.
Condensed Consolidated Statement of Changes in Stockholders’ Equity
(Unaudited)
(In thousands)
 
 
Common Stock
 
Treasury Stock
 
Additional
Paid-in Capital
 
Retained Earnings
 
Total
Stockholders’
Equity
Shares
 
Amount
 
Shares
 
Amount
 
Balance as of December 31, 2013
100,699

 
$
996

 
167

 
$
(5,362
)
 
$
985,023

 
$
367,892

 
$
1,348,549

Fees (2013 issuance of common stock)

 

 

 

 
(176
)
 

 
(176
)
Stock-based compensation
531

 

 

 

 
10,180

 

 
10,180

Vesting of restricted shares

 
3

 

 

 
(3
)
 

 

Treasury stock – tax withholdings
(78
)
 

 
78

 
(3,315
)
 

 

 
(3,315
)
Net income

 

 

 

 

 
208,786

 
208,786

Balance as of June 30, 2014
101,152

 
$
999

 
245

 
$
(8,677
)
 
$
995,024

 
$
576,678

 
$
1,564,024

The accompanying notes are an integral part of these condensed consolidated financial statements.


3


Oasis Petroleum Inc.
Condensed Consolidated Statement of Cash Flows
(Unaudited)
 
Six Months Ended June 30,
 
2014
 
2013
 
(In thousands)
Cash flows from operating activities:
 
 
 
Net income
$
208,786

 
$
118,970

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
Depreciation, depletion and amortization
188,548

 
133,051

Gain on sale of properties
(187,033
)
 

Impairment of oil and gas properties
804

 
706

Deferred income taxes
118,695

 
67,974

Derivative instruments
83,173

 
2,021

Stock-based compensation expenses
9,678

 
5,371

Debt discount amortization and other
3,220

 
1,753

Working capital and other changes:
 
 
 
Change in accounts receivable
(37,132
)
 
(13,768
)
Change in inventory
3,016

 
(4,200
)
Change in prepaid expenses
1,284

 
(4,402
)
Change in other current assets
(30
)
 
330

Change in other assets
(1,477
)
 

Change in accounts payable and accrued liabilities
91,543

 
48,701

Change in other current liabilities
3,311

 
688

Change in other liabilities
(132
)
 
612

Net cash provided by operating activities
486,254

 
357,807

Cash flows from investing activities:
 
 
 
Capital expenditures
(606,924
)
 
(428,630
)
Acquisition of oil and gas properties
(8,116
)
 

Proceeds from sale of properties
324,888

 

Costs related to sale of properties
(2,337
)
 

Redemptions of short-term investments

 
25,000

Derivative settlements
(13,644
)
 
2,932

Advances from joint interest partners
(5,919
)
 
(5,593
)
Net cash used in investing activities
(312,052
)
 
(406,291
)
Cash flows from financing activities:
 
 
 
Proceeds from revolving credit facility
100,000

 

Principal payments on revolving credit facility
(335,570
)
 

Purchases of treasury stock
(3,315
)
 
(364
)
Debt issuance costs
(85
)
 
(2,998
)
Other
(176
)
 

Net cash used in financing activities
(239,146
)
 
(3,362
)
Decrease in cash and cash equivalents
(64,944
)
 
(51,846
)
Cash and cash equivalents:
 
 
 
Beginning of period
91,901

 
213,447

End of period
$
26,957

 
$
161,601

Supplemental non-cash transactions:
 
 
 
Change in accrued capital expenditures
$
51,129

 
$
(6,085
)
Change in asset retirement obligations
1,624

 
3,441

The accompanying notes are an integral part of these condensed consolidated financial statements.

4


OASIS PETROLEUM INC.
Notes to Condensed Consolidated Financial Statements (Unaudited)
1. Organization and Operations of the Company
Organization
Oasis Petroleum Inc. (together with its subsidiaries, “Oasis” or the “Company”) was formed on February 25, 2010, pursuant to the laws of the State of Delaware, to become a holding company for Oasis Petroleum LLC (“OP LLC”), the Company’s predecessor, which was formed as a Delaware limited liability company on February 26, 2007. In connection with its initial public offering in June 2010 and related corporate reorganization, the Company acquired all of the outstanding membership interests in OP LLC in exchange for shares of the Company’s common stock. In 2007, Oasis Petroleum North America LLC (“OPNA”), a Delaware limited liability company, was formed to conduct domestic oil and natural gas exploration and production activities. In 2011, the Company formed Oasis Well Services LLC (“OWS”), a Delaware limited liability company, to provide well services to OPNA, and Oasis Petroleum Marketing LLC (“OPM”), a Delaware limited liability company, to provide marketing services to OPNA. In 2013, the Company formed Oasis Midstream Services LLC (“OMS”), a Delaware limited liability company, to provide midstream services to OPNA. As part of the formation of OMS, the Company transferred substantially all of its salt water disposal and other midstream assets from OPNA to OMS.
Nature of Business
The Company is an independent exploration and production company focused on the acquisition and development of unconventional oil and natural gas resources in the Williston Basin. The Company’s proved and unproved oil and natural gas properties are located in the North Dakota and Montana areas of the Williston Basin and are owned by OPNA. The Company also operates a marketing business (OPM), a well services business (OWS) and a midstream services business (OMS), all of which are complementary to its primary development and production activities. Both OWS and OMS are separate reportable business segments.
2. Summary of Significant Accounting Policies
Basis of Presentation
The accompanying condensed consolidated financial statements of the Company include the accounts of Oasis and its wholly-owned subsidiaries. All significant intercompany transactions have been eliminated in consolidation. The accompanying condensed consolidated financial statements of the Company have not been audited by the Company’s independent registered public accounting firm, except that the Condensed Consolidated Balance Sheet at December 31, 2013 is derived from audited financial statements. Certain reclassifications of prior year balances have been made to conform such amounts to current year classifications. These reclassifications have no impact on net income. In the opinion of management, all adjustments, consisting of normal recurring adjustments necessary for the fair presentation, have been included. Management has made certain estimates and assumptions that affect reported amounts in the condensed consolidated financial statements and disclosures of contingencies. Actual results may differ from those estimates. The results for interim periods are not necessarily indicative of annual results.
These interim financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Certain disclosures have been condensed or omitted from these financial statements. Accordingly, they do not include all of the information and notes required by accounting principles generally accepted in the United States of America (“GAAP”) for complete consolidated financial statements and should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 (“2013 Annual Report”).
Significant Accounting Policies
There have been no material changes to the Company’s critical accounting policies and estimates from those disclosed in the 2013 Annual Report other than those noted below.
Recent Accounting Pronouncements
Revenue recognition. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”). The objective of ASU 2014-09 is greater consistency and comparability across industries by using a five-step model to recognize revenue from customer contracts. ASU 2014-09 also contains some new disclosure requirements under GAAP and is effective for interim and annual reporting periods beginning after December 15, 2016. The Company is currently evaluating the effect that adopting this new guidance will have on its financial position, cash flows and results of operations.

5


3. Inventory
Equipment and materials consist primarily of tubular goods, well equipment to be used in future drilling or repair operations, well fracturing equipment, chemicals and proppant, all of which are stated at the lower of cost or market value with cost determined on an average cost method. Crude oil inventory includes oil in tank and linefill and is stated at the lower of average cost or market value. Inventory consists of the following:
 
June 30, 2014
 
December 31, 2013
 
(In thousands)
Equipment and materials
$
7,222

 
$
11,669

Crude oil inventory
10,414

 
8,983

Total inventory
$
17,636

 
$
20,652

4. Property, Plant and Equipment
The following table sets forth the Company’s property, plant and equipment:
 
June 30, 2014
 
December 31, 2013
 
(In thousands)
Proved oil and gas properties(1)
$
4,305,827

 
$
3,713,525

Less: Accumulated depreciation, depletion, amortization and impairment
(787,418
)
 
(612,380
)
Proved oil and gas properties, net
3,518,409

 
3,101,145

Unproved oil and gas properties
835,755

 
815,433

Total oil and gas properties, net
4,354,164

 
3,916,578

Other property and equipment
231,129

 
188,468

Less: Accumulated depreciation
(36,082
)
 
(25,296
)
Other property and equipment, net
195,047

 
163,172

Total property, plant and equipment, net
$
4,549,211

 
$
4,079,750

 __________________
(1)
Included in the Company’s proved oil and gas properties are estimates of future asset retirement costs of $33.4 million and $32.6 million at June 30, 2014 and December 31, 2013, respectively.
As a result of expiring leases and periodic assessments of unproved properties, the Company recorded non-cash impairment charges on its unproved oil and natural gas properties of $42,000 and $0.8 million for the three and six months ended June 30, 2014, respectively, and $0.2 million and $0.7 million for the three and six months ended June 30, 2013, respectively. No impairment charges on proved oil and natural gas properties were recorded for the three and six months ended June 30, 2014 or 2013.
5. Divestiture
On March 5, 2014, the Company completed the sale of certain non-operated properties in its Sanish project area and other non-operated leases adjacent to its Sanish position (the “Sanish Divestiture”) for cash proceeds of approximately $324.9 million, which includes, and is subject to further, customary post close adjustments. The Company recognized a $187.0 million gain on sale of properties in its Condensed Consolidated Statement of Operations for the six months ended June 30, 2014. The transaction was structured as an Internal Revenue Code Section 1031 like-kind exchange for tax purposes and as such did not give rise to any currently taxable gain.
6. Fair Value Measurements
In accordance with the FASB’s authoritative guidance on fair value measurements, the Company’s financial assets and liabilities are measured at fair value on a recurring basis. The Company recognizes its non-financial assets and liabilities, such as asset retirement obligations (“ARO”) and proved oil and natural gas properties upon impairment, at fair value on a non-recurring basis.
As defined in the authoritative guidance, fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). To estimate fair value, the Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable.

6


The authoritative guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (“Level 1” measurements) and the lowest priority to unobservable inputs (“Level 3” measurements). The three levels of the fair value hierarchy are as follows:
Level 1 — Unadjusted quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
Level 2 — Pricing inputs, other than unadjusted quoted prices in active markets included in Level 1, are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace.

Level 3 — Pricing inputs are generally less observable from objective sources, requiring internally developed valuation methodologies that result in management’s best estimate of fair value.
Financial Assets and Liabilities
As required, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The following tables set forth by level within the fair value hierarchy the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis: 
 
At fair value as of June 30, 2014
 
Level 1
 
Level 2
 
Level 3
 
Total
 
(In thousands)
Assets:
 
 
 
 
 
 
 
Money market funds
$
742

 
$

 
$

 
$
742

Total assets
$
742

 
$

 
$

 
$
742

Liabilities:
 
 
 
 
 
 
 
Commodity derivative instruments (see Note 7)
$

 
$
74,259

 
$

 
$
74,259

Total liabilities
$

 
$
74,259

 
$

 
$
74,259

 
 
 
 
 
 
 
 
 
At fair value as of December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Total
 
(In thousands)
Assets:
 
 
 
 
 
 
 
Money market funds
$
742

 
$

 
$

 
$
742

Commodity derivative instruments (see Note 7)

 
3,597

 

 
3,597

Total assets
$
742

 
$
3,597

 
$

 
$
4,339

Liabilities:
 
 
 
 
 
 
 
Commodity derivative instruments (see Note 7)
$

 
$
8,327

 
$

 
$
8,327

Total liabilities
$

 
$
8,327

 
$

 
$
8,327

The Level 1 instruments presented in the tables above consist of money market funds included in cash and cash equivalents on the Company’s Condensed Consolidated Balance Sheet at June 30, 2014 and December 31, 2013. The Company’s money market funds represent cash equivalents backed by the assets of high-quality major banks and financial institutions. The Company identified the money market funds as Level 1 instruments because the money market funds have daily liquidity, quoted prices for the underlying investments can be obtained and there are active markets for the underlying investments.
The Level 2 instruments presented in the tables above consist of commodity derivative instruments, which include oil collars, swaps and deferred premium puts. The fair values of the Company’s commodity derivative instruments are based upon

7


a third-party preparer’s calculation using mark-to-market valuation reports provided by the Company’s counterparties for monthly settlement purposes to determine the valuation of its derivative instruments. The Company has the third-party preparer evaluate other readily available market prices for its derivative contracts as there is an active market for these contracts. The third-party preparer performs its independent valuation using a moment matching method similar to Turnbull-Wakeman for Asian options. The significant inputs used are crude oil prices, volatility, skew, discount rate and the contract terms of the derivative instruments. However, the Company does not have access to the specific proprietary valuation models or inputs used by its counterparties or third-party preparer. The Company compares the third-party preparer’s valuation to counterparty valuation statements, investigating any significant differences, and analyzes monthly valuation changes in relation to movements in crude oil forward price curves. The determination of the fair value for derivative instruments also incorporates a credit adjustment for non-performance risk, as required by GAAP. The Company calculates the credit adjustment for derivatives in a net asset position using current credit default swap values for each counterparty. The credit adjustment for derivatives in a net liability position is based on the Company’s market credit spread. Based on these calculations, the Company recorded an adjustment to reduce the fair value of its net derivative liability by $2.5 million and $0.2 million at June 30, 2014 and December 31, 2013, respectively.

Fair Value of Other Financial Instruments
The Company’s financial instruments, including certain cash and cash equivalents, accounts receivable and accounts payable, are carried at cost, which approximates fair value due to the short-term maturity of these instruments. At June 30, 2014, the Company’s cash equivalents were all Level 1 assets. The carrying amount of the Company’s long-term debt reported in the Condensed Consolidated Balance Sheet at June 30, 2014 is $2,300.0 million, which includes $2,200.0 million of senior unsecured notes and $100.0 million of borrowings under the revolving credit facility (see Note 8 – Long-Term Debt). The fair value of the Company’s senior unsecured notes, which are Level 1 liabilities, is $2,380.0 million at June 30, 2014.
Nonfinancial Assets and Liabilities
Asset retirement obligations. The carrying amount of the Company’s ARO in the Condensed Consolidated Balance Sheet at June 30, 2014 is $38.1 million (see Note 9 – Asset Retirement Obligations). The Company determines the ARO by calculating the present value of estimated cash flows related to the liability. Estimating the future ARO requires management to make estimates and judgments regarding timing and existence of a liability, as well as what constitutes adequate restoration. Inherent in the fair value calculation are numerous assumptions and judgments, including the ultimate costs, inflation factors, credit adjusted discount rates, timing of settlement and changes in the legal, regulatory, environmental and political environments. These assumptions represent Level 3 inputs. To the extent future revisions to these assumptions impact the fair value of the existing ARO liability, a corresponding adjustment is made to the related asset.
Impairment. The Company reviews its proved oil and natural gas properties for impairment whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. The Company estimates the expected undiscounted future cash flows of its oil and natural gas properties and compares such undiscounted future cash flows to the carrying amount of the oil and natural gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will adjust the carrying amount of the oil and natural gas properties to fair value. The factors used to determine fair value are subject to management’s judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net of estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. These assumptions represent Level 3 inputs. No impairment charges on proved oil and natural gas properties were recorded for the three and six months ended June 30, 2014 or 2013.
7. Derivative Instruments
The Company utilizes derivative financial instruments to manage risks related to changes in oil prices. As of June 30, 2014, the Company utilized two-way and three-way costless collar options, swaps, swaps with sub-floors and deferred premium puts to reduce the volatility of oil prices on a significant portion of its future expected oil production. A two-way collar is a combination of options: a sold call and a purchased put. The purchased put establishes a minimum price (floor) and the sold call establishes a maximum price (ceiling) the Company will receive for the volumes under contract. A three-way collar is a combination of options: a sold call, a purchased put and a sold put. The purchased put establishes a minimum price (floor), unless the market price falls below the sold put (sub-floor), at which point the minimum price would be NYMEX West Texas Intermediate (“WTI”) crude oil index price plus the difference between the purchased put and the sold put strike price. The sold call establishes a maximum price (ceiling) the Company will receive for the volumes under contract. A swap is a sold call and a purchased put established at the same price (both ceiling and floor). A swap with a sub-floor is a swap coupled with a

8


sold put (sub-floor) at which point the minimum price would be WTI crude oil index price plus the difference between the swap and the sold put strike price. For the deferred premium puts, the Company agrees to pay a premium to the counterparty at the time of settlement. At settlement, if the WTI price is below the floor price of the put, the Company receives the difference between the floor price and the WTI price multiplied by the contract volumes, less the premium. If the WTI price settles at or above the floor price of the put, the Company pays only the premium.
All derivative instruments are recorded on the Company’s Condensed Consolidated Balance Sheet as either assets or liabilities measured at fair value (see Note 6 – Fair Value Measurements). The Company has not designated any derivative instruments as hedges for accounting purposes and does not enter into such instruments for speculative trading purposes. If a derivative does not qualify as a hedge or is not designated as a hedge, the changes in fair value are recognized in the other income (expense) section of the Company’s Condensed Consolidated Statement of Operations as a net gain or loss on derivative instruments. The Company’s cash flow is only impacted when the actual settlements under the derivative contracts result in making a payment to or receiving a payment from the counterparty. These cash settlements are reflected as investing activities in the Company’s Condensed Consolidated Statement of Cash Flows.
As of June 30, 2014, the Company had the following outstanding commodity derivative instruments, all of which settle monthly based on the average WTI crude oil index price:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Weighted Average Deferred Premium
 
 
Settlement
Period
 
Derivative
Instrument
 
Total Notional
Amount of Oil
 
Weighted Average Prices
 
 
Fair Value
Asset
(Liability)
 
 
 
Swap
 
Sub-Floor
 
Floor
 
Ceiling
 
 
 
 
 
 
(Barrels)
 
($/Barrel)
 
 
 
(In thousands)
2014
 
Two-way collars
 
1,855,500

 
 
 
 
 
$
94.92

 
$
106.16

 
 
 
$
(3,019
)
2014
 
Three-way collars
 
1,615,500

 
 
 
$
70.57

 
$
90.57

 
$
105.20

 
 
 
(3,774
)
2014
 
Swaps
 
1,858,500

 
$
96.13

 
 
 
 
 
 
 
 
 
(14,339
)
2014
 
Swaps with sub-floors
 
1,098,000

 
$
92.60

 
$
70.00

 
 
 
 
 
 
 
(12,194
)
2015
 
Two-way collars
 
2,388,500

 
 
 
 
 
$
87.98

 
$
103.21

 
 
 
(2,738
)
2015
 
Three-way collars
 
263,500

 
 
 
$
70.59

 
$
90.59

 
$
105.25

 
 
 
(489
)
2015
 
Swaps
 
5,263,500

 
$
90.81

 
 
 
 
 
 
 
 
 
(34,657
)
2015
 
Swaps with sub-floors
 
186,000

 
$
92.60

 
$
70.00

 
 
 
 
 
 
 
(1,544
)
2015
 
Deferred premium puts
 
1,086,000

 
 
 
 
 
$
90.00

 
 
 
$
2.55

 
(549
)
2016
 
Two-way collars
 
155,000

 
 
 
 
 
$
86.00

 
$
103.42

 
 
 
92

2016
 
Swaps
 
310,000

 
$
90.15

 
 
 
 
 
 
 
 
 
(1,048
)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
$
(74,259
)
The following table summarizes the location and fair value of all outstanding commodity derivative instruments recorded in the Company’s Condensed Consolidated Balance Sheet for the periods presented:
 
Fair Value of Derivative Instrument Assets (Liabilities)
 
 
 
 
Fair Value
Commodity
 
Balance Sheet Location
 
June 30, 2014
 
December 31, 2013
 
 
 
 
(In thousands)
Crude oil
 
Derivative instruments — current assets
 
$

 
$
2,264

Crude oil
 
Derivative instruments — non-current assets
 

 
1,333

Crude oil
 
Derivative instruments — current liabilities
 
(62,415
)
 
(8,188
)
Crude oil
 
Derivative instruments — non-current liabilities
 
(11,844
)
 
(139
)
Total derivative instruments
 
 
 
$
(74,259
)
 
$
(4,730
)
The following table summarizes the location and amounts of gains and losses from the Company’s commodity derivative instruments for the periods presented:

9


 
 
 
Three Months Ended 
 June 30,
 
Six Months Ended 
 June 30,
 
Statement of Operations Location
 
2014
 
2013
 
2014
 
2013
 
 
 
(In thousands)
Non-cash change in fair value of derivative instruments
Net gain (loss) on derivative instruments
 
$
(54,165
)
 
$
11,345

 
$
(69,529
)
 
$
(4,953
)
Derivative settlements
Net gain (loss) on derivative instruments
 
(11,405
)
 
1,246

 
(13,644
)
 
2,932

Total net gain (loss) on derivative instruments
 
$
(65,570
)
 
$
12,591

 
$
(83,173
)
 
$
(2,021
)
In accordance with the FASB’s authoritative guidance on disclosures about offsetting assets and liabilities, the Company is required to disclose both gross and net information about instruments and transactions eligible for offset in the statement of financial position as well as instruments and transactions subject to an agreement similar to a master netting agreement. The Company’s derivative instruments are presented as assets and liabilities on a net basis by counterparty, as all counterparty contracts provide for net settlement. No margin or collateral balances are deposited with counterparties, and as such, gross amounts are offset to determine the net amounts presented in the Company’s Condensed Consolidated Balance Sheet.
The following tables summarize gross and net information about the Company’s commodity derivative instruments for the periods presented:
Offsetting of Derivative Assets
 
Gross Amounts of Recognized Assets
 
Gross Amounts Offset
in the Balance Sheet
 
Net Amounts of Assets Presented
in the Balance Sheet
 
 
(In thousands)
As of June 30, 2014
 
$
22,988

 
$
(22,988
)
 
$

As of December 31, 2013
 
22,743

 
(19,146
)
 
3,597

 
 
 
 
 
 
 
Offsetting of Derivative Liabilities
 
Gross Amounts of Recognized Liabilities
 
Gross Amounts Offset
in the Balance Sheet
 
Net Amounts of Liabilities Presented
in the Balance Sheet
 
 
(In thousands)
As of June 30, 2014
 
$
97,247

 
$
(22,988
)
 
$
74,259

As of December 31, 2013
 
27,473

 
(19,146
)
 
8,327


8. Long-Term Debt
Senior unsecured notes. On September 24, 2013, the Company issued $1,000.0 million of 6.875% senior unsecured notes due March 15, 2022 (the “2022 Notes”). The issuance of the 2022 Notes resulted in aggregate net proceeds to the Company of $983.6 million. The Company used the proceeds from the 2022 Notes to fund the acquisition of oil and gas properties in its West Williston project area. On June 30, 2014, the Company filed a registration statement on Form S-4 with the SEC to allow the holders of the 2022 Notes to exchange the 2022 Notes for the same principal amount of a new issue of notes with substantially identical terms, except the new notes will be freely transferable under the Securities Act. The Company will use commercially reasonable efforts to cause the exchange to be completed within 360 days after the 2022 Notes issuance date. Under certain circumstances, in lieu of a registered exchange offer, the Company must use commercially reasonable efforts to file a shelf registration statement for the resale of the 2022 Notes. If the Company fails to satisfy these obligations on a timely basis, the annual interest borne by the 2022 Notes will be increased by 1.0% per annum until the exchange offer is completed or the shelf registration statement is declared effective. The Company estimates the value of this contingent interest is immaterial at June 30, 2014 and December 31, 2013.
During 2011 and 2012, the Company issued $400.0 million of 7.25% senior unsecured notes due February 1, 2019 (the “2019 Notes”), $400.0 million of 6.5% senior unsecured notes due November 1, 2021 (the “2021 Notes”) and $400.0 million of 6.875% senior unsecured notes due January 15, 2023 (the “2023 Notes,” and together with the 2022 Notes, 2019 Notes and 2021 Notes, the “Notes”). The issuance of the 2019 Notes, 2021 Notes and the 2023 Notes resulted in aggregate net proceeds to the Company of $1,175.8 million. The Company used the proceeds from the 2019 Notes, 2021 Notes and the 2023 Notes to fund its exploration, development and acquisition program and for general corporate purposes. Interest on the Notes is payable semi-annually in arrears.
The Notes were issued under indentures containing provisions that are substantially the same, as amended and supplemented by supplemental indentures (collectively the “Indentures”), among the Company, along with its material subsidiaries (the “Guarantors”), and U.S. Bank National Association, as trustee (the “Trustee”). The Notes are guaranteed on a senior unsecured basis by the Company’s Guarantors. These guarantees are full and unconditional and joint and several among the Guarantors, subject to certain customary release provisions, as follows:

10


in connection with any sale or other disposition of all or substantially all of the assets of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary (as defined in the Indentures) of the Company;
in connection with any sale or other disposition of the capital stock of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary of the Company, such that, immediately after giving effect to such transaction, such Guarantor would no longer constitute a subsidiary of the Company;
if the Company designates any Restricted Subsidiary that is a Guarantor to be an unrestricted subsidiary in accordance with the Indenture;
upon legal defeasance or satisfaction and discharge of the Indenture; or
upon the liquidation or dissolution of a Guarantor, provided no event of default occurs under the Indentures as a result thereof.
The Company has certain options to redeem up to 35% of the Notes at a certain redemption price based on a percentage of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings so long as the redemption occurs within 180 days of completing such equity offering and at least 65% of the aggregate principal amount of the Notes remains outstanding after such redemption. Prior to certain dates, the Company has the option to redeem some or all of the Notes for cash at certain redemption prices equal to a certain percentage of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. The Company estimates that the fair value of these redemption options is immaterial at June 30, 2014 and December 31, 2013.
The Indentures restrict the Company’s ability and the ability of certain of its subsidiaries to: (i) incur additional debt or enter into sale and leaseback transactions; (ii) pay distributions on, redeem or repurchase equity interests; (iii) make certain investments; (iv) incur liens; (v) enter into transactions with affiliates; (vi) merge or consolidate with another company; and (vii) transfer and sell assets. These covenants are subject to certain exceptions and qualifications. If at any time when the Notes are rated investment grade by both Moody’s Investors Service, Inc. and Standard & Poor’s Ratings Services and no Default (as defined in the Indentures) has occurred and is continuing, many of such covenants will terminate and the Company and its subsidiaries will cease to be subject to such covenants.
The Indentures contain customary events of default, including:
default in any payment of interest on any Note when due, continued for 30 days;
default in the payment of principal or premium, if any, on any Note when due;
failure by the Company to comply with its other obligations under the Indentures, in certain cases subject to notice and grace periods;
payment defaults and accelerations with respect to other indebtedness of the Company and its Restricted Subsidiaries in the aggregate principal amount of $10.0 million or more;
certain events of bankruptcy, insolvency or reorganization of the Company or a Significant Subsidiary (as defined in the Indentures) or group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary;
failure by the Company or any Significant Subsidiary or group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary to pay certain final judgments aggregating in excess of $10.0 million within 60 days; and
any guarantee of the Notes by a Guarantor ceases to be in full force and effect, is declared null and void in a judicial proceeding or is denied or disaffirmed by its maker.

Senior secured revolving line of credit. On April 5, 2013, the Company, as parent, and OPNA, as borrower, entered into a second amended and restated credit agreement (the “Second Amended Credit Facility”), which has a maturity date of April 5, 2018. The Second Amended Credit Facility is restricted to the borrowing base, which is reserve-based and subject to semi-annual redeterminations on April 1 and October 1 of each year. On March 27, 2014, the lenders under the Second Amended Credit Facility (the “Lenders”) completed their regular semi-annual redetermination of the borrowing base, resulting in an increase to the borrowing base from $1,500.0 million to $1,750.0 million. However, the Company elected to limit the Lenders’ aggregate commitment to $1,500.0 million. The overall senior secured line of credit under the Second Amended Credit Facility is $2,500.0 million as of June 30, 2014.


11


Borrowings under the Second Amended Credit Facility are collateralized by perfected first priority liens and security interests on substantially all of the Company’s assets, including mortgage liens on oil and natural gas properties having at least 80% of the reserve value as determined by reserve reports.

Borrowings under the Second Amended Credit Facility are subject to varying rates of interest based on (1) the total outstanding borrowings (including the value of all outstanding letters of credit) in relation to the borrowing base and (2) whether the loan is a London interbank offered rate (“LIBOR”) loan or a domestic bank prime interest rate loan (defined in the Second Amended Credit Facility as an Alternate Based Rate or “ABR” loan). As of June 30, 2014, any outstanding LIBOR and ABR loans bore their respective interest rates plus the applicable margin indicated in the following table:
 
Ratio of Total Outstanding Borrowings to Borrowing Base
 
Applicable Margin
for LIBOR Loans
 
Applicable Margin
for ABR Loans
Less than .25 to 1
 
1.50
%
 
0.00
%
Greater than or equal to .25 to 1 but less than .50 to 1
 
1.75
%
 
0.25
%
Greater than or equal to .50 to 1 but less than .75 to 1
 
2.00
%
 
0.50
%
Greater than or equal to .75 to 1 but less than .90 to 1
 
2.25
%
 
0.75
%
Greater than .90 to 1 but less than or equal 1
 
2.50
%
 
1.00
%
An ABR loan may be repaid at any time before the scheduled maturity of the Second Amended Credit Facility upon the Company providing advance notification to the Lenders. Interest is paid quarterly on ABR loans based on the number of days an ABR loan is outstanding as of the last business day in March, June, September and December. The Company has the option to convert an ABR loan to a LIBOR-based loan upon providing advance notification to the Lenders. The minimum available loan term is one month and the maximum loan term is six months for LIBOR-based loans. Interest for LIBOR loans is paid upon maturity of the loan term. Interim interest is paid every three months for LIBOR loans that have loan terms greater than three months in duration. At the end of a LIBOR loan term, the Second Amended Credit Facility allows the Company to elect to repay the borrowing, continue a LIBOR loan with the same or a differing loan term or convert the borrowing to an ABR loan.
On a quarterly basis, the Company pays a 0.375% (as of June 30, 2014) annualized commitment fee on the average amount of borrowing base capacity not utilized during the quarter and fees calculated on the average amount of letter of credit balances outstanding during the quarter.
As of June 30, 2014, the Second Amended Credit Facility contained covenants that included, among others:
a prohibition against incurring debt, subject to permitted exceptions;
a prohibition against making dividends, distributions and redemptions, subject to permitted exceptions;
a prohibition against making investments, loans and advances, subject to permitted exceptions;
restrictions on creating liens and leases on the assets of the Company and its subsidiaries, subject to permitted exceptions;
restrictions on merging and selling assets outside the ordinary course of business;
restrictions on use of proceeds, investments, transactions with affiliates or change of principal business;
a provision limiting oil and natural gas derivative financial instruments;
a requirement that the Company maintain a ratio of consolidated EBITDAX (as defined in the Second Amended Credit Facility) to consolidated Interest Expense (as defined in the Second Amended Credit Facility) of no less than 2.5 to 1.0 for the four quarters ended on the last day of each quarter; and
a requirement that the Company maintain a Current Ratio (as defined in the Second Amended Credit Facility) of consolidated current assets (including unused borrowing base capacity and with exclusions as described in the Second Amended Credit Facility) to consolidated current liabilities (with exclusions as described in the Second Amended Credit Facility) of no less than 1.0 to 1.0 as of the last day of any fiscal quarter.
The Second Amended Credit Facility contains customary events of default. If an event of default occurs and is continuing, the Lenders may declare all amounts outstanding under the Second Amended Credit Facility to be immediately due and payable.


12


As of June 30, 2014, the Company had $100.0 million of LIBOR loans and $5.2 million of outstanding letters of credit issued under the Second Amended Credit Facility, resulting in an unused borrowing base capacity of $1,394.8 million. As of June 30, 2014, the weighted average interest rate was 1.7% on borrowings outstanding under the Second Amended Credit Facility. The Company was in compliance with the financial covenants of the Second Amended Credit Facility as of June 30, 2014.
Deferred financing costs. As of June 30, 2014, the Company had $38.7 million of deferred financing costs related to the Notes and the Second Amended Credit Facility. The deferred financing costs are included in deferred costs and other assets on the Company’s Condensed Consolidated Balance Sheet at June 30, 2014 and are being amortized over the respective terms of the Notes and the Second Amended Credit Facility. Amortization of deferred financing costs recorded for the three and six months ended June 30, 2014 was $1.6 million and $3.2 million, respectively, and $1.0 million and $1.9 million for the three and six months ended June 30, 2013, respectively. These costs are included in interest expense on the Company’s Condensed Consolidated Statement of Operations.
9. Asset Retirement Obligations
The following table reflects the changes in the Company’s ARO during the six months ended June 30, 2014:
 
(In thousands)
Balance at December 31, 2013
$
36,458

Liabilities incurred during period
2,689

Liabilities settled during period(1)
(1,974
)
Accretion expense during period(2)
909

Balance at June 30, 2014
$
38,082

 ___________________
(1)
Liabilities settled during period represents ARO related to the properties sold in the Sanish Divestiture.
(2)
Included in depreciation, depletion and amortization on the Company’s Condensed Consolidated Statement of Operations.
At June 30, 2014, the current portion of the total ARO balance was approximately $0.5 million and is included in accrued liabilities on the Company’s Condensed Consolidated Balance Sheet.
10. Stock-Based Compensation
Restricted stock awards. The Company has granted restricted stock awards to employees and directors under its Amended and Restated 2010 Long Term Incentive Plan, the majority of which vest over a three-year period. The fair value of restricted stock grants is based on the value of the Company’s common stock on the date of grant. Compensation expense is recognized ratably over the requisite service period. For the six months ended June 30, 2014, the Company assumed annual forfeiture rates by employee group ranging from 0% to 12.7% based on the Company’s forfeiture history for this type of award.
During the six months ended June 30, 2014, employees and non-employee directors of the Company were granted restricted stock awards equal to 621,770 shares of common stock with a $42.67 weighted average grant date per share value. Stock-based compensation expense recorded for restricted stock awards for the three and six months ended June 30, 2014 was $4.3 million and $8.2 million, respectively, and was $2.6 million and $4.6 million for three and six months ended June 30, 2013, respectively. Stock-based compensation expense is included in general and administrative expenses on the Company’s Condensed Consolidated Statement of Operations.
Performance share units. The Company has granted performance share units (“PSUs”) to officers of the Company under its Amended and Restated 2010 Long Term Incentive Plan. The PSUs are awards of restricted stock units, and each PSU that is earned represents the right to receive one share of the Company’s common stock. For the six months ended June 30, 2014, the Company assumed an annual forfeiture rate of 3.3% based on the Company’s forfeiture history for the officer employee group receiving PSUs.
During the six months ended June 30, 2014, officers of the Company were granted 158,970 PSUs with a $41.71 weighted average grant date per share value. Stock-based compensation expense recorded for PSUs for the three and six months ended June 30, 2014 was $0.9 million and $1.5 million, respectively, and is included in general and administrative expenses on the Condensed Consolidated Statement of Operations. Stock-based compensation expense recorded for PSUs for the three and six months ended June 30, 2013 was $0.5 million and $0.8 million, respectively.

13


Each grant of PSUs is subject to a designated three-year initial performance period. The number of PSUs to be earned is subject to a market condition, which is based on a comparison of the total shareholder return (“TSR”) achieved with respect to shares of the Company’s common stock against the TSR achieved by a defined peer group at the end of the performance period. Depending on the Company’s TSR performance relative to the defined peer group, an award recipient will earn between 0% and 200% of the initial PSUs granted. If less than 200% of the initial PSUs granted are earned at the end of the initial three-year performance period, then the performance period will be extended an additional year to give the recipient the opportunity to earn up to an aggregate of 200% of the initial PSUs granted.

The Company accounted for these PSUs as equity awards pursuant to the FASB’s authoritative guidance for share-based payments. The aggregate grant date fair value of the market-based awards was determined using a Monte Carlo simulation model, which results in an expected percentage of PSUs earned. The fair value of these PSUs is recognized on a straight-line basis over the performance period. As it is probable that a portion of the awards will be earned during the extended performance period, the grant date fair value will be amortized over four years. However, if 200% of the initial PSUs granted are earned at the end of the initial performance period, then the remaining compensation expense will be accelerated in order to be fully recognized over three years. All compensation expense related to the PSUs will be recognized if the requisite performance period is fulfilled, even if the market condition is not achieved.
The Monte Carlo simulation model uses assumptions regarding random projections and must be repeated numerous times to achieve a probabilistic assessment. The key valuation assumptions for the Monte Carlo model are the forecast period, initial value, risk-free interest rate, volatility and correlation coefficients. The risk-free interest rate is the U.S. treasury bond rate on the date of grant that corresponds to the extended performance period. The initial value is the average of the volume weighted average prices for the 30 trading days prior to the start of the performance cycle for the Company and each of its peers. Volatility is the standard deviation of the average percentage in stock price over a historical two-year period for the Company and each of its peers. The correlation coefficients are measures of the strength of the linear relationship between and amongst the Company and its peers estimated based on historical stock price data.
The following assumptions were used for the Monte Carlo model to determine the grant date fair value and associated stock-based compensation expense of the PSUs granted during the six months ended June 30, 2014:
Forecast period (years)
4.00

Risk-free interest rate
1.12
%
Oasis stock price volatility
44.49
%
Based on these assumptions, the Monte Carlo simulation model resulted in an expected percentage of PSUs earned of 98% for the PSUs granted during the six months ended June 30, 2014.
11. Income Taxes
The Company’s effective tax rate for the three and six months ended June 30, 2014 was 37.5% and 37.4%, respectively. The Company’s effective tax rate for the three and six months ended June 30, 2013 was 36.0% and 36.7%, respectively. These rates were 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. As of June 30, 2014, the Company did not have any uncertain tax positions requiring adjustments to its tax liability.
The Company had deferred tax assets for its federal and state tax loss carryforwards at June 30, 2014 recorded in deferred taxes. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. As of June 30, 2014, management determined that a valuation allowance was not required for the tax loss carryforwards as they are expected to be fully utilized before expiration.
12. Earnings Per Share
Basic earnings per share is computed by dividing income available to common stockholders by the weighted average number of shares outstanding for the periods presented. The calculation of diluted earnings per share includes the impact of potentially dilutive non-vested restricted shares outstanding during the periods presented, unless their effect is anti-dilutive. There are no adjustments made to income available to common stockholders in the calculation of diluted earnings per share.

14


The following is a calculation of the basic and diluted weighted-average shares outstanding for the three and six months ended June 30, 2014 and 2013: 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
2014
 
2013
 
2014
 
2013
 
(In thousands)
Basic weighted average common shares outstanding
99,663

 
92,399

 
99,612

 
92,387

Dilution effect of stock awards at end of period
597

 
303

 
716

 
425

Diluted weighted average common shares outstanding
100,260

 
92,702

 
100,328

 
92,812

Anti-dilutive stock-based compensation awards
1,115

 
914

 
909

 
711


Issuance of common stock. On December 9, 2013, the Company completed a public offering of 7,000,000 shares of its common stock, par value $0.01 per share, at an offering price of $44.94 per share. Net proceeds from the offering were $314.4 million, after deducting offering expenses, of which $70,000 is included in common stock and $314.3 million is included in additional paid-in capital on the Company’s Consolidated Balance Sheet. The Company used the net proceeds to repay outstanding indebtedness under its Second Amended Credit Facility, to fund its exploration, development and acquisition program and for general corporate purposes.

13. Business Segment Information

The Company’s exploration and production segment is engaged in the acquisition and development of oil and natural gas properties and includes the complementary marketing services provided by OPM. Revenues for the exploration and production segment are primarily derived from the sale of oil and natural gas production. In the first quarter of 2012, the Company began its well services business segment (OWS) to perform completion services for the Company’s oil and natural gas wells operated by OPNA. Revenues for the well services segment are derived from providing well completion services, related product sales and tool rentals. In the first quarter of 2013, the Company formed its midstream services business segment (OMS) to perform salt water disposal and other midstream services for the Company’s oil and natural gas wells operated by OPNA. Revenues for the midstream segment are primarily derived from providing salt water disposal services and fresh water sales. The revenues and expenses related to work performed by OWS and OMS for OPNA’s working interests are eliminated in consolidation, and only the revenues and expenses related to non-affiliated working interest owners are included in the Company’s Condensed Consolidated Statement of Operations. These segments represent the Company’s three current operating units, each offering different products and services. The Company’s corporate activities have been allocated to the supported business segments accordingly.
Management evaluates the performance of the Company’s business segments based on operating income, which is defined as segment operating revenues less expenses. The following table summarizes financial information for the Company’s segments for the periods presented:

15


 
 
Exploration and
Production
 
Well Services
 
Midstream Services
 
Consolidated
 
(In thousands)
Three months ended June 30, 2014:
 
Revenues
$
354,183

 
$
58,447

 
$
13,478

 
$
426,108

Inter-segment revenues

 
(43,570
)
 
(10,160
)
 
(53,730
)
Total revenues
354,183

 
14,877

 
3,318

 
372,378

Operating income
158,353

 
6,858

 
1,334

 
166,545

Other income (expense)
(104,448
)
 
23

 

 
(104,425
)
Income before income taxes
53,905

 
6,881

 
1,334

 
62,120

 
 
Three months ended June 30, 2013:
 
 
 
 
 
 
 
Revenues
$
241,842

 
$
31,382

 
$
7,035

 
$
280,259

Inter-segment revenues

 
(19,921
)
 
(5,756
)
 
(25,677
)
Total revenues
241,842

 
11,461

 
1,279

 
254,582

Operating income
105,459

 
3,310

 
4,681

 
113,450

Other income (expense)
(8,511
)
 
4

 

 
(8,507
)
Income before income taxes
96,948

 
3,314

 
4,681

 
104,943

 
 
Six months ended June 30, 2014:
 
Revenues
$
686,030

 
$
110,853

 
$
22,831

 
$
819,714

Inter-segment revenues

 
(80,149
)
 
(17,668
)
 
(97,817
)
Total revenues
686,030

 
30,704

 
5,163

 
721,897

Operating income
484,886

 
8,478

 
2,261

 
495,625

Other income (expense)
(162,108
)
 
75

 

 
(162,033
)
Income before income taxes
322,778

 
8,553

 
2,261

 
333,592

 
 
Six months ended June 30, 2013:
 
 
 
 
 
 
 
Revenues
$
483,493

 
$
67,150

 
$
11,855

 
$
562,498

Inter-segment revenues

 
(49,975
)
 
(9,637
)
 
(59,612
)
Total revenues
483,493

 
17,175

 
2,218

 
502,886

Operating income
218,357

 
5,873

 
7,173

 
231,403

Other income (expense)
(43,530
)
 
8

 

 
(43,522
)
Income before income taxes
174,827

 
5,881

 
7,173

 
187,881

 
 
Total assets:
 
As of June 30, 2014
$
4,844,196

 
$
77,050

 
$
115,733

 
$
5,036,979

As of December 31, 2013
4,532,264

 
70,708

 
108,952

 
4,711,924

14. Commitments and Contingencies
Lease obligations. The Company’s total rental commitments under leases for office space and other property and equipment at June 30, 2014 were $27.4 million.
Drilling contracts. As of June 30, 2014, the Company had certain drilling rig contracts with initial terms greater than one year. In the event of early termination under these contracts, the Company would be obligated to pay approximately $35.0 million as of June 30, 2014 for the days remaining through the end of the primary terms of the contracts.
Volume commitment agreements. As of June 30, 2014, the Company had certain agreements with an aggregate requirement to deliver a minimum quantity of approximately 35.7 MMBbl and 10.4 Bcf from its Williston Basin project areas within specified timeframes, all of which are less than ten years. Future obligations under these agreements were approximately $179.8 million as of June 30, 2014.

16


Water purchase agreements. As of June 30, 2014, the Company had certain agreements for the purchase of freshwater with an aggregate future obligation of approximately $4.2 million.
Cost sharing agreements. As of June 30, 2014, the Company had certain agreements to share the cost to construct and install electrical facilities. The Company’s estimated future obligation under these agreements was $11.1 million as of June 30, 2014.
Investment commitment. As of June 30, 2014, the Company had a remaining capital spending commitment of $7.0 million in connection with drilling and completion activities that the Company agreed to fund for certain wells that were part of the Company’s acquisitions of oil and natural gas properties in its East Nesson project area during the third quarter of 2013.
Litigation. The Company is party to various legal and/or regulatory proceedings from time to time arising in the ordinary course of business. While the ultimate outcome and impact to the Company cannot be predicted with certainty, the Company believes that all such matters are without merit and involve amounts which, if resolved unfavorably, either individually or in the aggregate, will not have a material adverse effect on its financial condition, results of operations or cash flows. When the Company determines that a loss is probable of occurring and is reasonably estimable, the Company accrues an undiscounted liability for such contingencies based on its best estimate using information available at the time. The Company discloses contingencies where an adverse outcome may be material, or in the judgment of management, the matter should otherwise be disclosed.
On July 6, 2013, a freight train operated by Montreal, Maine and Atlantic Railway (“MMA”) carrying crude oil (the “Train”) derailed in Lac-Mégantic, Quebec. In March 2014, Oasis Petroleum Inc. and OP LLC were added to a group of over fifty named defendants, including other crude oil producers as well as the Canadian Pacific Railway, MMA and certain of its affiliates, owners and transloaders of the crude oil carried by the Train, several lessors of tank cars, and the Attorney General of Canada, in a motion filed in Quebec Superior Court to authorize a class-action lawsuit seeking economic, compensatory and punitive damages, as well as costs for claims arising out of the derailment of the Train (Yannick Gagne, etc., et al. v. Rail World, Inc., etc., et al., Case No. 48006000001132). The motion generally alleges wrongful death and negligence in the failure to provide for the proper and safe transportation of crude oil.
The Company believes that all claims against Oasis Petroleum Inc. and OP LLC in connection with the derailment of the Train in Lac-Mégantic, Quebec are without merit and intends to vigorously defend against them.

17



15. Condensed Consolidating Financial Information
The Notes (see Note 8) are guaranteed on a senior unsecured basis by the Guarantors, which are 100% owned by the Company. These guarantees are full and unconditional and joint and several among the Guarantors. Certain of the Company’s immaterial wholly-owned subsidiaries do not guarantee the Notes (“Non-Guarantor Subsidiaries”).
The following financial information reflects consolidating financial information of the parent company, Oasis Petroleum Inc. (“Issuer”), and its Guarantors on a combined basis, prepared on the equity basis of accounting. The Non-Guarantor Subsidiaries are immaterial and, therefore, not presented separately. The information is presented in accordance with the requirements of Rule 3-10 under the SEC’s Regulation S-X. The financial information may not necessarily be indicative of results of operations, cash flows or financial position had the Guarantors operated as independent entities. The Company has not presented separate financial and narrative information for each of the Guarantors because it believes such financial and narrative information would not provide any additional information that would be material in evaluating the sufficiency of the Guarantors.
 
Condensed Consolidating Balance Sheet
(In thousands, except share data)

 
June 30, 2014
 
Parent/
Issuer
 
Combined
Guarantor
Subsidiaries
 
Intercompany
Eliminations
 
Consolidated
ASSETS
 
 
 
 
 
 
 
Current assets
 
 
 
 
 
 
 
Cash and cash equivalents
$
1,603

 
$
25,354

 
$

 
$
26,957

Accounts receivable – oil and gas revenues

 
216,764

 

 
216,764

Accounts receivable – joint interest partners

 
147,056

 

 
147,056

Accounts receivable – affiliates
781

 
13,416

 
(14,197
)
 

Inventory

 
17,636

 

 
17,636

Prepaid expenses

 
8,907

 

 
8,907

Deferred income taxes

 
25,390

 

 
25,390

Advances to joint interest partners

 
97

 

 
97

Other current assets

 
421

 

 
421

Total current assets
2,384

 
455,041

 
(14,197
)
 
443,228

Property, plant and equipment
 
 
 
 
 
 
 
Oil and gas properties (successful efforts method)

 
5,141,582

 

 
5,141,582

Other property and equipment

 
231,129

 

 
231,129

Less: accumulated depreciation, depletion, amortization and impairment

 
(823,500
)
 

 
(823,500
)
Total property, plant and equipment, net

 
4,549,211

 

 
4,549,211

Investments in and advances to subsidiaries
3,675,495

 

 
(3,675,495
)
 

Deferred income taxes
117,199

 

 
(117,199
)
 

Deferred costs and other assets
31,726

 
12,814

 

 
44,540

Total assets
$
3,826,804

 
$
5,017,066

 
$
(3,806,891
)
 
$
5,036,979

LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
 
 
 
 
Current liabilities
 
 
 
 
 
 
 
Accounts payable
$

 
$
32,402

 
$

 
$
32,402

Accounts payable – affiliates
13,416

 
781

 
(14,197
)
 

Revenues and production taxes payable

 
217,414

 

 
217,414

Accrued liabilities
24

 
288,789

 

 
288,813

Accrued interest payable
49,340

 
104

 

 
49,444

Derivative instruments

 
62,415

 

 
62,415

Advances from joint interest partners

 
6,910

 

 
6,910

Other current liabilities

 
3,311

 

 
3,311

Total current liabilities
62,780

 
612,126

 
(14,197
)
 
660,709

Long-term debt
2,200,000

 
100,000

 

 
2,300,000

Deferred income taxes

 
578,096

 
(117,199
)
 
460,897

Asset retirement obligations

 
37,542

 

 
37,542

Derivative instruments

 
11,844

 

 
11,844

Other liabilities

 
1,963

 

 
1,963

Total liabilities
2,262,780

 
1,341,571

 
(131,396
)
 
3,472,955

Stockholders’ equity
 
 
 
 
 
 
 
Capital contributions from affiliates

 
2,893,387

 
(2,893,387
)
 

Common stock, $0.01 par value: 300,000,000 shares authorized; 101,396,597 issued
999

 

 

 
999

Treasury stock, at cost: 244,729 shares
(8,677
)
 

 

 
(8,677
)
Additional paid-in capital
995,024

 
8,743

 
(8,743
)
 
995,024

Retained earnings
576,678

 
773,365

 
(773,365
)
 
576,678

Total stockholders’ equity
1,564,024

 
3,675,495

 
(3,675,495
)
 
1,564,024

Total liabilities and stockholders’ equity
$
3,826,804

 
$
5,017,066

 
$
(3,806,891
)
 
$
5,036,979



18


Condensed Consolidating Balance Sheet
(In thousands, except share data)
 
December 31, 2013
 
Parent/
Issuer
 
Combined
Guarantor
Subsidiaries
 
Intercompany
Eliminations
 
Consolidated
ASSETS
 
 
 
 
 
 
 
Current assets
 
 
 
 
 
 
 
Cash and cash equivalents
$
34,277

 
$
57,624

 
$

 
$
91,901

Accounts receivable – oil and gas revenues

 
175,653

 

 
175,653

Accounts receivable – joint interest partners

 
139,459

 

 
139,459

Accounts receivable – affiliates
770

 
9,100

 
(9,870
)
 

Inventory

 
20,652

 

 
20,652

Prepaid expenses
318

 
9,873

 

 
10,191

Deferred income taxes

 
6,335

 

 
6,335

Derivative instruments

 
2,264

 

 
2,264

Advances to joint interest partners

 
760

 

 
760

Other current assets

 
391

 

 
391

Total current assets
35,365

 
422,111

 
(9,870
)
 
447,606

Property, plant and equipment
 
 
 
 
 
 
 
Oil and gas properties (successful efforts method)

 
4,528,958

 

 
4,528,958

Other property and equipment

 
188,468

 

 
188,468

Less: accumulated depreciation, depletion, amortization and impairment

 
(637,676
)
 

 
(637,676
)
Total property, plant and equipment, net

 
4,079,750

 

 
4,079,750

Assets held for sale

 
137,066

 

 
137,066

Investments in and advances to subsidiaries
3,450,668

 

 
(3,450,668
)
 

Derivative instruments

 
1,333

 

 
1,333

Deferred income taxes
85,288

 

 
(85,288
)
 

Deferred costs and other assets
33,983

 
12,186

 

 
46,169

Total assets
$
3,605,304

 
$
4,652,446

 
$
(3,545,826
)
 
$
4,711,924

LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
 
 
 
 
Current liabilities
 
 
 
 
 
 
 
Accounts payable
$

 
$
8,920

 
$

 
$
8,920

Accounts payable – affiliates
9,100

 
770

 
(9,870
)
 

Revenues and production taxes payable

 
146,741

 

 
146,741

Accrued liabilities
33

 
241,797

 

 
241,830

Accrued interest payable
47,622

 
288

 

 
47,910

Derivative instruments

 
8,188

 

 
8,188

Advances from joint interest partners

 
12,829

 

 
12,829

Total current liabilities
56,755

 
419,533

 
(9,870
)
 
466,418

Long-term debt
2,200,000

 
335,570

 

 
2,535,570

Deferred income taxes

 
408,435

 
(85,288
)
 
323,147

Asset retirement obligations

 
35,918

 

 
35,918

Derivative instruments

 
139

 

 
139

Other liabilities

 
2,183

 

 
2,183

Total liabilities
2,256,755

 
1,201,778

 
(95,158
)
 
3,363,375

Stockholders’ equity
 
 
 
 
 
 
 
Capital contributions from affiliates

 
2,930,978

 
(2,930,978
)
 

Common stock, $0.01 par value: 300,000,000 shares authorized; 100,866,589 issued
996

 

 

 
996

Treasury stock, at cost: 167,155 shares
(5,362
)
 

 

 
(5,362
)
Additional paid-in capital
985,023

 
8,743

 
(8,743
)
 
985,023

Retained earnings
367,892

 
510,947

 
(510,947
)
 
367,892

Total stockholders’ equity
1,348,549

 
3,450,668

 
(3,450,668
)
 
1,348,549

Total liabilities and stockholders’ equity
$
3,605,304

 
$
4,652,446

 
$
(3,545,826
)
 
$
4,711,924



19


Condensed Consolidating Statement of Operations
(In thousands)

 
Three Months Ended June 30, 2014
 
Parent/
Issuer
 
Combined
Guarantor
Subsidiaries
 
Intercompany
Eliminations
 
Consolidated
Revenues
 
 
 
 
 
 
 
Oil and gas revenues
$

 
$
354,182

 
$

 
$
354,182

Well services and midstream revenues

 
18,196

 

 
18,196

Total revenues

 
372,378

 

 
372,378

Expenses
 
 
 
 
 
 
 
Lease operating expenses

 
40,553

 

 
40,553

Well services and midstream operating expenses

 
8,769

 

 
8,769

Marketing, transportation and gathering expenses

 
7,114

 

 
7,114

Production taxes

 
34,493

 

 
34,493

Depreciation, depletion and amortization

 
97,276

 

 
97,276

Exploration expenses

 
475

 

 
475

Impairment of oil and gas properties

 
42

 

 
42

General and administrative expenses
5,805

 
14,946

 

 
20,751

Total expenses
5,805

 
203,668