NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
1. FINANCIAL STATEMENT PRESENTATION
Basis of Presentation and Principles of Consolidation
Halcón Resources Corporation (Halcón or the Company) is an independent energy company focused on the acquisition,
production, exploration and development of onshore liquids-rich oil and natural gas assets in the United States. The unaudited condensed consolidated financial statements include the accounts of all
majority-owned, controlled subsidiaries. The Company operates in one segment which focuses on oil and natural gas acquisition, production, exploration and development. The Company's oil and natural
gas properties are managed as a whole rather than through discrete operating areas. Operational information is tracked by operating area; however, financial performance is assessed as a whole.
Allocation of capital is made across the Company's entire portfolio without regard to operating area. All intercompany accounts and transactions have been eliminated. These unaudited condensed
consolidated financial statements reflect, in the opinion of the Company's management, all adjustments, consisting of normal and recurring adjustments, necessary to present fairly the financial
position as of, and the results of operations for, the periods presented. During interim periods, Halcón follows the accounting policies disclosed in its Annual Report on
Form 10-K, as filed with the United States Securities and Exchange Commission (SEC) on March 1, 2017. Please refer to the notes in the 2016 Annual Report on Form 10-K when
reviewing interim financial results, though, as described below, such prior financial statements may not be comparable to the interim financial statements due to the adoption of fresh-start accounting
on September 9, 2016.
Emergence from Voluntary Reorganization under Chapter 11
On July 27, 2016 (the Petition Date), the Company and certain of its subsidiaries (the Halcón Entities) filed voluntary
petitions for relief under chapter 11 of the United States Bankruptcy Code in the U.S. Bankruptcy Court in the District of Delaware (the Bankruptcy Court) to pursue a joint prepackaged plan of
reorganization (the Plan). On September 8, 2016, the Bankruptcy Court entered an order confirming the Plan and on September 9, 2016, the Plan became effective (the Effective Date) and
the Halcón Entities emerged from chapter 11 bankruptcy. The Company's subsidiary, HK TMS, LLC which was divested on September 30, 2016, was not part of the
chapter 11 bankruptcy filings. See Note 2,
"Reorganization,"
for further details on the Company's chapter 11 bankruptcy and the
Plan and Note 4,
"Acquisitions and Divestitures,"
for further details on the divestiture of HK TMS, LLC.
Upon
emergence from chapter 11 bankruptcy, the Company adopted fresh-start accounting in accordance with provisions of the Financial Accounting Standards Board's (FASB) Accounting
Standards Codification (ASC) 852,
"Reorganizations"
(ASC 852) which resulted in the Company becoming a new entity for financial reporting purposes on
the Effective Date. Upon the adoption of fresh-start accounting, the Company's assets and liabilities were recorded at their fair values as of the fresh-start reporting date. As a result of the
adoption of fresh-start accounting, the Company's unaudited condensed consolidated financial statements subsequent to September 9, 2016 are not comparable to its unaudited condensed
consolidated financial statements prior to, and including,
September 9, 2016. See Note 3,
"Fresh-start Accounting,"
for further details on the impact of fresh-start accounting on the Company's
unaudited condensed consolidated financial statements.
References
to "Successor" or "Successor Company" relate to the financial position and results of operations of the reorganized Company subsequent to September 9, 2016. References
to "Predecessor"
9
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
1. FINANCIAL STATEMENT PRESENTATION (Continued)
or
"Predecessor Company" relate to the financial position and results of operations of the Company prior to, and including, September 9, 2016.
Use of Estimates
The preparation of the Company's unaudited condensed consolidated financial statements in conformity with accounting principles generally
accepted in the United States requires the Company's management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and
liabilities, if any, at the date of the unaudited condensed consolidated financial statements and the reported amounts of revenues and expenses during the respective reporting periods. Estimates and
assumptions that, in the opinion of management of the Company, are significant include oil and natural gas revenue accruals, capital and operating expense accruals, oil and natural gas reserves,
depletion relating to oil and natural gas properties, asset retirement obligations, fair value estimates, including estimates of Reorganization Value, Enterprise Value and the fair value of assets and
liabilities recorded as a result of the adoption of fresh-start accounting, plus the estimated fair values of assets acquired and liabilities assumed in connection with the Pecos County Acquisition
and the fair value of assets sold in connection with the El Halcón Divestiture, including the gain on sale recorded, and income taxes. The Company bases its estimates and judgments on
historical experience and on various other assumptions and information believed to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be
predicted with certainty and, accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as the Company's operating
environment changes. Actual results may differ from the estimates and assumptions used in the preparation of the Company's unaudited condensed consolidated financial statements.
Interim
period results are not necessarily indicative of results of operations or cash flows for the full year and accordingly, certain information normally included in financial
statements prepared in accordance with accounting principles generally accepted in the United States, has been condensed or
omitted. The Company has evaluated events or transactions through the date of issuance of these unaudited condensed consolidated financial statements.
Accounts Receivable and Allowance for Doubtful Accounts
The Company's accounts receivable are primarily receivables from joint interest owners and oil and natural gas purchasers. Accounts receivable
are recorded at the amount due, less an allowance for doubtful accounts, when applicable. The Company establishes provisions for losses on accounts receivable if it determines that collection of all
or part of the outstanding balance is doubtful. The Company regularly reviews collectability and establishes or adjusts the allowance for doubtful accounts as necessary using the specific
identification method. There were no significant allowances for doubtful accounts as of March 31, 2017 (Successor) or December 31, 2016 (Successor).
Other Operating Property and Equipment
Gas gathering systems and equipment are recorded at fair value as a result of fresh-start accounting on September 9, 2016. Depreciation
is calculated using the straight-line method over a 30-year, 20-year, or 10-year estimated useful life applicable to gas gathering systems, a water recycling facility and a compressed natural gas
facility, respectively. Upon disposition, the cost and accumulated
10
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
1. FINANCIAL STATEMENT PRESENTATION (Continued)
depreciation
are removed and any gains or losses are reflected in current operations. Maintenance and repair costs are charged to operating expense as incurred. Material expenditures which increase
the life or productive capacity of an asset are capitalized and depreciated over the estimated remaining useful life of the asset.
Other
operating assets are recorded at fair value as a result of fresh-start accounting on September 9, 2016. Depreciation is calculated using the straight-line method over the
following estimated useful lives: automobiles and computers, three years; computer software, fixtures, furniture and equipment, five years or the lesser of the lease term; trailers, seven years; heavy
equipment, eight to ten years;
buildings, twenty years and leasehold improvements, lease term. Upon disposition, the cost and accumulated depreciation are removed and any gains or losses are reflected in current operations.
Maintenance and repair costs are charged to operating expense as incurred. Material expenditures which increase the life of an asset are capitalized and depreciated over the estimated remaining useful
life of the asset.
Refer
to Note 4,
"Acquisitions and Divestitures,"
for a discussion of gas gathering systems and equipment and other operating
assets acquired and divested during the period.
The
Company reviews its gas gathering systems and equipment and other operating assets for impairment in accordance with ASC 360,
Property, Plant, and
Equipment
(ASC 360). ASC 360 requires the Company to evaluate gas gathering systems and equipment and other operating assets for impairment as events occur or circumstances
change that would more likely than not reduce the fair value below the carrying amount. If the carrying amount is not recoverable from its undiscounted cash flows, then the Company would recognize an
impairment loss for the difference between the carrying amount and the current fair value. Further, the Company evaluates the remaining useful lives of its gas gathering systems and other operating
assets at each reporting period to determine whether events and circumstances warrant a revision to the remaining depreciation periods. For the three months ended March 31, 2016 (Predecessor),
the Company recorded a non-cash impairment charge of $28.1 million in
"Other operating property and equipment impairment"
in the Company's
unaudited condensed consolidated statements of operations and in
"Gas gathering and other operating assets"
in the Company's unaudited condensed
consolidated balance sheets related to $32.8 million gross investments in gas gathering infrastructure that were deemed non-economical due to a shift in exploration, drilling and developmental
plans in a low commodity price environment.
In
accordance with ASC 820,
Fair Value Measurements and Disclosures
(ASC 820), a financial instrument's level within the fair value
hierarchy is based on the lowest level of input that is significant to the fair value measurement. The estimate of the fair value of the Company's gas gathering systems was based on an income approach
that estimated future cash flows associated with those assets over the remaining asset lives. This estimation includes the use of unobservable inputs, such as estimated future production, gathering
and compression revenues and operating expenses. The use of these unobservable inputs results in the fair value estimate of the Company's gas gathering systems being classified as Level 3.
Recently Issued Accounting Pronouncements
In January 2017, the FASB issued Accounting Standards Update (ASU) No. 2017-01,
Business Combinations (Topic
805): Clarifying the Definition of a Business
(ASU 2017-01). For public business entities, ASU 2017-01 is effective for fiscal years and interim periods within those fiscal
years,
11
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
1. FINANCIAL STATEMENT PRESENTATION (Continued)
beginning
after December 15, 2017. The amendments in this ASU should be applied prospectively on or after the effective date. The ASU was issued to clarify the definition of a business with the
objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions of assets or businesses. The Company is in the process of assessing the
effects of the application of the new guidance.
In
August 2016, the FASB issued ASU No. 2016-15,
Statement of Cash Flows (Topic 230)
(ASU 2016-15). For public business
entities, ASU 2016-15 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2017 and early adoption is permitted. The areas for
simplification in this ASU involve addressing eight specific classification issues in the statement of cash flows. An entity should apply the amendments in this ASU using a retrospective transition
method. The Company is in the process of assessing the effects of the application of the new guidance.
In
February 2016, the FASB issued ASU No. 2016-02,
Leases (Topic 842)
(ASU 2016-02). For public business entities, ASU 2016-02 is
effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018 and early adoption is permitted. The FASB issued ASU 2016-02 to increase
transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. An entity should
apply the amendments in this ASU on a modified retrospective basis. The transition will require application of the new guidance at the beginning of the earliest comparative period presented in the
financial statements. The Company is in the early stages of assessing the effects of the application of the new guidance and the financial statement and disclosure impacts. The Company will adopt ASU
2016-02 no later than January 1, 2019.
In
May 2014, the FASB issued ASU No. 2014-09,
Revenue from Contracts with Customers
(ASU 2014-09). ASU 2014-09 states
that an entity should recognize revenue to depict the transfer of promised goods or services to customers in amounts that reflect the consideration to which the entity expects to be entitled in
exchange for those goods or services. The standard provides five steps an entity should apply in determining its revenue recognition. In March 2016, ASU 2014-09 was updated with ASU
No. 2016-08,
Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net)
(ASU
2016-08), which provides further clarification on the principal versus agent evaluation. ASU 2014-09 is required to be adopted using either the full retrospective approach, with all prior periods
presented adjusted, or the modified retrospective approach, with a cumulative adjustment to retained earnings on the opening balance sheet and is effective for annual reporting periods, and interim
periods within that reporting period, beginning after December 15, 2016, or after December 2017, if companies choose to elect the deferred adoption date approved by the FASB. Early adoption is
not permitted. The Company is in the early stages of assessing the effects of the application of the new guidance and the financial statement and disclosure impacts. The Company will adopt ASU 2014-09
effective January 1, 2018.
2. REORGANIZATION
On June 9, 2016, the Halcón Entities entered into a restructuring support agreement (the Restructuring Support Agreement) with certain holders of the Company's 13%
senior secured third lien notes due 2022 (the Third Lien Noteholders), the Company's 8.875% senior unsecured notes due 2021, 9.25% senior unsecured notes due 2022 and 9.75% senior unsecured notes due
2020 (collectively, the
12
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
2. REORGANIZATION (Continued)
Unsecured
Noteholders), the holder of the Company's 8% senior unsecured convertible note due 2020 (the Convertible Noteholder), and certain holders of the Company's 5.75% Series A Convertible
Perpetual Preferred Stock. On July 27, 2016, the Halcón Entities filed voluntary petitions for relief under chapter 11 of the United States Bankruptcy Code in the U.S.
Bankruptcy Court in the District of Delaware to effect an accelerated prepackaged bankruptcy restructuring as contemplated in the Restructuring Support Agreement. On September 8, 2016, the
Bankruptcy Court entered an order confirming the Plan and on September 9, 2016, the Halcón Entities emerged from chapter 11 bankruptcy.
Upon
emergence, pursuant to the terms of the Plan, the following significant transactions occurred:
-
-
the Predecessor Company's financing facility under the Predecessor Credit Agreement was refinanced and replaced with a debtor-in-possession
senior secured, super-priority revolving credit facility, which was subsequently converted into the Senior Credit Agreement (refer to Note 6,
"Debt,"
for credit agreement definitions and further
details regarding the credit agreements);
-
-
the Predecessor Company's Second Lien Notes (consisting of $700.0 million in aggregate principal amount outstanding of 8.625% senior
secured notes due 2020 and $112.8 million in aggregate principal amount outstanding of 12% senior secured notes due 2022) were unimpaired and reinstated;
-
-
the Predecessor Company's Third Lien Notes were cancelled and the Third Lien Noteholders received their pro rata share of 76.5% of the common
stock of reorganized Halcón, together with a cash payment of $33.8 million, and accrued and unpaid interest on their notes through May 15, 2016, which interest was paid
prior to the chapter 11 bankruptcy filing, in full and final satisfaction of their claims;
-
-
the Predecessor Company's Unsecured Notes were cancelled and the Unsecured Noteholders received their pro rata share of 15.5% of the common
stock of reorganized Halcón, together with a cash payment of $37.6 million and warrants to purchase 4% of the common stock of reorganized Halcón (with a four year
term and an exercise price of $14.04 per share), and accrued and unpaid interest on their notes through May 15, 2016, which interest was paid prior to the chapter 11 bankruptcy filing,
in full and final satisfaction of their claims;
-
-
the Predecessor Company's Convertible Note was cancelled and the Convertible Noteholder received 4% of the common stock of reorganized
Halcón, together with a cash payment of $15.0 million and warrants to purchase 1% of the common stock of reorganized Halcón (with a four year term and an exercise
price of $14.04 per share), in full and final satisfaction of their claims;
-
-
the general unsecured claims were unimpaired and paid in full in the ordinary course;
-
-
all outstanding shares of the Predecessor Company's Series A Preferred Stock were cancelled and the Preferred Holders received their pro
rata share of $11.1 million in cash, in full and final satisfaction of their interests; and
-
-
all of the Predecessor Company's outstanding shares of common stock were cancelled and the common stockholders received their pro rata share of
4% of the common stock of reorganized Halcón, in full and final satisfaction of their interests.
13
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
2. REORGANIZATION (Continued)
Each of the foregoing percentages of equity in the reorganized Company were as of September 9, 2016 and are subject to dilution from the exercise of the new warrants described
above, a management incentive plan discussed further in Note 11
, "Stockholders' Equity,"
and other future issuances of equity securities.
See
Note 6, "
Debt
," and Note 11, "
Stockholders' Equity
," for further
information regarding the Company's Successor and Predecessor debt and equity instruments.
3. FRESH-START ACCOUNTING
Upon the Company's emergence from chapter 11 bankruptcy, the Company qualified for and adopted fresh-start accounting in accordance with the provisions set forth in ASC 852 as
(i) the Reorganization Value of the Company's assets immediately prior to the date of confirmation was less than the post-petition liabilities and allowed claims, and (ii) the holders of
the existing voting shares of the Predecessor entity received less than 50% of the voting shares of the emerging entity. Refer to Note 2
,
"Reorganization,"
for the terms of the Plan. Fresh-start accounting requires the Company to present its assets, liabilities, and equity as if it were a new entity upon
emergence from bankruptcy. The new entity is referred to as "Successor" or "Successor Company." However, the Company will continue to present financial information for any periods before adoption of
fresh-start accounting for the Predecessor Company. The Predecessor and Successor companies may lack comparability, as required in ASC Topic 205,
Presentation of Financial
Statements
(ASC 205). ASC 205 states financial statements are required to be presented comparably from year to year, with any exceptions to comparability clearly disclosed.
Therefore, "black-line" financial statements are presented to distinguish between the Predecessor and Successor companies.
Adopting
fresh-start accounting results in a new financial reporting entity with no beginning retained earnings or deficit as of the fresh-start reporting date. Upon the application of
fresh-start accounting, the Company allocated the Reorganization Value (the fair value of the Successor Company's total assets) to its individual assets based on their estimated fair values. The
Reorganization Value is intended to represent the approximate amount a willing buyer would value the Company's assets immediately after the reorganization.
Reorganization
Value is derived from an estimate of Enterprise Value, or the fair value of the Company's long-term debt, stockholders' equity and working capital. The estimated
Enterprise Value at the Effective Date was below the midpoint of the Court approved range of $1.6 billion to $1.8 billion, primarily reflecting the decline in forward commodity prices
during the period between the Company's
analysis performed in advance of the July 2016 chapter 11 bankruptcy filing and the Effective Date. The Enterprise Value was derived from an independent valuation using an asset based
methodology of proved reserves, undeveloped acreage, and other financial information, considerations and projections, applying a combination of the income, cost and market approaches as of the
fresh-start reporting date of September 9, 2016.
The
Company's principal assets are its oil and natural gas properties. For purposes of estimating the fair value of the Company's proved, probable and possible reserves, an income
approach was used which estimated fair value based on the anticipated cash flows associated with the Company's reserves, risked by reserve category and discounted using a weighted average cost of
capital rate of 10.5% for proved reserves and 12.5% for probable and possible reserves. The proved reserve locations were limited to wells expected to be drilled in the Company's five year development
plan. Weighted average
14
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
3. FRESH-START ACCOUNTING (Continued)
commodity
prices utilized in the determination of the fair value of oil and natural gas properties were $72.30 per barrel of oil, $3.50 per million British thermal units (MMBtu) of natural gas and
$12.00 per barrel of oil equivalent of natural gas liquids, after adjustment for transportation fees and regional price differentials. Base pricing was derived from an average of forward strip prices
and analysts' estimated prices.
In
estimating the fair value of the Company's unproved acreage that was not included in the valuation of probable and possible reserves, a market approach was used in which a review of
recent transactions involving properties in the same geographical location indicated the fair value of the Company's unproved acreage from a market participant perspective.
See
further discussion below in the
"Fresh-start accounting adjustments"
for the specific assumptions used in the valuation of the
Company's various other assets.
Although
the Company believes the assumptions and estimates used to develop Enterprise Value and Reorganization Value were reasonable and appropriate, different assumptions and estimates
could materially impact the analysis and resulting conclusions. The assumptions used in estimating these values are inherently uncertain and require judgment.
The
following table reconciles the Company's Enterprise Value to the estimated fair value of the Successor's common stock as of September 9, 2016 (in thousands):
|
|
|
|
|
|
|
September 9, 2016
|
|
Enterprise Value
|
|
$
|
1,618,888
|
|
Plus: Cash
|
|
|
13,943
|
|
Less: Fair value of debt
|
|
|
(1,016,160
|
)
|
Less: Fair value of redeemable noncontrolling interest
|
|
|
(41,070
|
)
|
Less: Fair value of other long-term liabilities
|
|
|
(4,478
|
)
|
Less: Fair value of warrants
|
|
|
(16,691
|
)
|
|
|
|
|
|
Fair Value of Successor common stock
|
|
$
|
554,432
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The
following table reconciles the Company's Enterprise Value to its Reorganization Value as of September 9, 2016 (in thousands):
|
|
|
|
|
|
|
September 9, 2016
|
|
Enterprise Value
|
|
$
|
1,618,888
|
|
Plus: Cash
|
|
|
13,943
|
|
Plus: Current liabilities
|
|
|
178,639
|
|
Plus: Noncurrent asset retirement obligation
|
|
|
32,156
|
|
|
|
|
|
|
Reorganization Value of Successor assets
|
|
$
|
1,843,626
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Condensed Consolidated Balance Sheet
The following illustrates the effects on the Company's unaudited condensed consolidated balance sheet due to the reorganization and fresh-start
accounting adjustments. The explanatory notes following the table below provide further details on the adjustments, including the Company's assumptions and
15
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
3. FRESH-START ACCOUNTING (Continued)
methods
used to determine fair value for its assets and liabilities. Amounts included in the table below are rounded to thousands.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of September 9, 2016
|
|
|
|
Predecessor
Company
|
|
Reorganization
Adjustments
|
|
Fresh-Start
Adjustments
|
|
Successor
Company
|
|
Current assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash
|
|
|
$
|
111,464
|
|
|
|
$
|
(97,521
|
)
(1)
|
|
|
$
|
|
|
|
$
|
13,943
|
|
Accounts receivable
|
|
|
116,859
|
|
|
|
|
|
|
|
|
|
|
116,859
|
|
Receivables from derivative contracts
|
|
|
97,648
|
|
|
|
|
|
|
|
|
|
|
97,648
|
|
Restricted cash
|
|
|
17,164
|
|
|
|
|
|
|
|
|
|
|
17,164
|
|
Prepaids and other
|
|
|
8,961
|
|
|
|
|
|
|
|
(1,332
|
)
(7)
|
|
7,629
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
352,096
|
|
|
|
(97,521
|
)
|
|
|
(1,332
|
)
|
|
253,243
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and natural gas properties (full cost method):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Evaluated
|
|
|
7,712,003
|
|
|
|
|
|
|
|
(6,497,874
|
)
(8)
|
|
1,214,129
|
|
Unevaluated
|
|
|
1,193,259
|
|
|
|
|
|
|
|
(861,144
|
)
(8)
|
|
332,115
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross oil and natural gas properties
|
|
|
8,905,262
|
|
|
|
|
|
|
|
(7,359,018
|
)
|
|
1,546,244
|
|
Lessaccumulated depletion
|
|
|
(6,803,231
|
)
|
|
|
|
|
|
|
6,803,231
|
(8)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net oil and natural gas properties
|
|
|
2,102,031
|
|
|
|
|
|
|
|
(555,787
|
)
|
|
1,546,244
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other operating property and equipment:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas gathering and other operating assets
|
|
|
100,079
|
|
|
|
|
|
|
|
(62,008
|
)
(9)
|
|
38,071
|
|
Lessaccumulated depreciation
|
|
|
(24,154
|
)
|
|
|
|
|
|
|
24,154
|
(9)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net other operating property and equipment
|
|
|
75,925
|
|
|
|
|
|
|
|
(37,854
|
)
|
|
38,071
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other noncurrent assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Receivables from derivative contracts
|
|
|
4,431
|
|
|
|
|
|
|
|
|
|
|
4,431
|
|
Funds in escrow and other
|
|
|
1,610
|
|
|
|
|
|
|
|
27
|
(10)
|
|
1,637
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
|
$
|
2,536,093
|
|
|
|
$
|
(97,521
|
)
|
|
|
$
|
(594,946
|
)
|
|
$
|
1,843,626
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable and accrued liabilities
|
|
|
$
|
160,000
|
|
|
|
$
|
13,688
|
(2)
|
|
|
$
|
|
|
|
$
|
173,688
|
|
Liabilities from derivative contracts
|
|
|
102
|
|
|
|
|
|
|
|
|
|
|
102
|
|
Other
|
|
|
414
|
|
|
|
|
|
|
|
4,435
|
(11)(12)
|
|
4,849
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
160,516
|
|
|
|
13,688
|
|
|
|
4,435
|
|
|
178,639
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-term debt, net
|
|
|
1,031,114
|
|
|
|
|
|
|
|
(14,954
|
)
(13)
|
|
1,016,160
|
|
Liabilities subject to compromise
|
|
|
2,007,703
|
|
|
|
(2,007,703
|
)
(3)
|
|
|
|
|
|
|
|
Other noncurrent liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities from derivative contracts
|
|
|
525
|
|
|
|
|
|
|
|
|
|
|
525
|
|
Asset retirement obligations
|
|
|
48,955
|
|
|
|
|
|
|
|
(16,799
|
)
(12)
|
|
32,156
|
|
Other
|
|
|
528
|
|
|
|
|
|
|
|
3,425
|
(11)(14)
|
|
3,953
|
|
Commitments and contingencies
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Mezzanine equity:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Redeemable noncontrolling interest
|
|
|
219,891
|
|
|
|
|
|
|
|
(178,821
|
)
(14)
|
|
41,070
|
|
Stockholders' equity:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred stock (Predecessor)
|
|
|
|
|
|
|
|
(4)
|
|
|
|
|
|
|
|
Common Stock (Predecessor)
|
|
|
12
|
|
|
|
(12
|
)
(4)
|
|
|
|
|
|
|
|
Common Stock (Successor)
|
|
|
|
|
|
|
9
|
(5)
|
|
|
|
|
|
9
|
|
Additional paid-in capital (Predecessor)
|
|
|
3,287,906
|
|
|
|
(3,287,906
|
)
(4)
|
|
|
|
|
|
|
|
Additional paid-in capital (Successor)
|
|
|
|
|
|
|
571,114
|
(5)
|
|
|
|
|
|
571,114
|
|
Retained earnings (accumulated deficit)
|
|
|
(4,221,057
|
)
|
|
|
4,613,289
|
(6)
|
|
|
(392,232
|
)
(15)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders' equity
|
|
|
(933,139
|
)
|
|
|
1,896,494
|
|
|
|
(392,232
|
)
|
|
571,123
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders' equity
|
|
|
$
|
2,536,093
|
|
|
|
$
|
(97,521
|
)
|
|
|
$
|
(594,946
|
)
|
|
$
|
1,843,626
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
16
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
3. FRESH-START ACCOUNTING (Continued)
Reorganization adjustments
-
(1)
-
The
table below details cash payments as of September 9, 2016, pursuant to the terms of the Plan described in Note 2
"
Reorganization
" (in thousands):
|
|
|
|
|
Payment to Third Lien Noteholders
|
|
$
|
33,826
|
|
Payment to Unsecured Noteholders
|
|
|
37,595
|
|
Payment to Convertible Noteholder
|
|
|
15,000
|
|
Payment to Preferred Holders
|
|
|
11,100
|
|
|
|
|
|
|
Total Uses
|
|
$
|
97,521
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
-
(2)
-
In
connection with the chapter 11 bankruptcy, the Company modified and rejected certain office lease arrangements and paid approximately $3.4 million
for these modifications and rejections subsequent to the emergence from chapter 11 bankruptcy. This amount also reflects $10.3 million paid to the Company's restructuring advisors
subsequent to the emergence from chapter 11 bankruptcy.
-
(3)
-
Liabilities
subject to compromise were as follows (in thousands):
|
|
|
|
|
13.0% senior secured third lien notes due 2022
|
|
$
|
1,017,970
|
|
9.25% senior notes due 2022
|
|
|
37,194
|
|
8.875% senior notes due 2021
|
|
|
297,193
|
|
9.75% senior notes due 2020
|
|
|
315,535
|
|
8.0% convertible note due 2020
|
|
|
289,669
|
|
Accrued interest
|
|
|
46,715
|
|
Office lease modification and rejection fees
|
|
|
3,427
|
|
|
|
|
|
|
Liabilities subject to compromise
|
|
|
2,007,703
|
|
Fair value of equity and warrants issued to Third Lien Noteholders, Unsecured Noteholders and Convertible Noteholder
|
|
|
(548,947
|
)
|
Cash payments to Third Lien Noteholders, Unsecured Noteholders and Convertible Noteholder
|
|
|
(86,421
|
)
|
Office lease modification and rejection fees
|
|
|
(3,427
|
)
|
|
|
|
|
|
Gain on settlement of Liabilities subject to compromise
|
|
$
|
1,368,908
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
-
(4)
-
Reflects
the cancellation of Predecessor equity, as follows (in thousands):
|
|
|
|
|
Predecessor Company stock
|
|
$
|
3,287,918
|
|
Fair value of equity issued to Predecessor common stockholers
|
|
|
(22,176
|
)
|
Cash payment to Preferred Holders
|
|
|
(11,100
|
)
|
|
|
|
|
|
Cancellation of Predecessor Company equity
|
|
$
|
3,254,642
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
-
(5)
-
Reflects
the issuance of Successor equity. In accordance with the Plan, the Successor Company issued 3.6 million shares of common stock to the Predecessor
Company's existing common stockholders, 68.8 million shares of common stock to the Third Lien Noteholders, 14.0 million shares of common stock to the Unsecured Noteholders, and
3.6 million shares of common stock to the Convertible Noteholder. This amount is subject to dilution by warrants issued to the
17
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
3. FRESH-START ACCOUNTING (Continued)
Unsecured
Noteholders and the Convertible Noteholder totaling 4.7 million shares with an exercise price of $14.04 per share and a term of four years. The fair value of the warrants was
estimated at $3.52 per share using a Black-Scholes-Merton valuation model.
-
(6)
-
The
table below reflects the cumulative effect of the reorganization adjustments discussed above (in thousands):
|
|
|
|
|
Gain on settlement of Liabilities subject to compromise
|
|
$
|
1,368,908
|
|
Accrued reorganization items
|
|
|
(10,261
|
)
|
Cancellation of Predecessor Company equity
|
|
|
3,254,642
|
|
|
|
|
|
|
Net impact to retained earnings (accumulated deficit)
|
|
$
|
4,613,289
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
-
(7)
-
Reflects
the reclassification of tubulars and well equipment to "
Oil and natural gas properties
."
-
(8)
-
In
estimating the fair value of its oil and natural gas properties, the Company used a combination of the income and market approaches. For purposes of estimating
the fair value of the Company's proved, probable and possible reserves, an income approach was used which estimated fair value based on the anticipated cash flows associated with the Company's
reserves, risked by reserve category and discounted using a weighted average cost of capital rate of 10.5% for proved reserves and 12.5% for probable and possible reserves. The proved reserve
locations were limited to wells expected to be drilled in the Company's five year development plan. Weighted average commodity prices utilized in the determination of the fair value of oil and natural
gas properties were $72.30 per barrel of oil, $3.50 per MMBtu of natural gas and $12.00 per barrel of natural gas liquids, after adjustment for transportation
fees and regional price differentials. Base pricing was derived from an average of forward strip prices and analysts' estimated prices.
In
estimating the fair value of the Company's unproved acreage that was not included in the valuation of probable and possible reserves, a market approach was used in which a review of recent
transactions involving properties in the same geographical location indicated the fair value of the Company's unproved acreage from a market participant perspective.
-
(9)
-
In
estimating the fair value of its gas gathering and other operating assets, the Company used a combination of the income, cost, and market approaches.
For
purposes of estimating the fair value of its gas gathering assets, an income approach was used that estimated future cash flows associated with the assets over the remaining useful lives. The
valuation included such inputs as estimated future production, gathering and compression revenues, and operating expenses that were discounted at a weighted average cost of capital rate of 9.5%.
For
purposes of estimating the fair value of its other operating assets, the Company used a combination of the market and cost approaches. A market approach was relied upon to value land and computer
equipment, and in this valuation approach, recent transactions of similar assets were utilized to determine the value from a market participant perspective. For the remaining other operating assets, a
cost approach was used. The estimation of fair value under the cost approach
18
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
3. FRESH-START ACCOUNTING (Continued)
was
based on current replacement costs of the assets, less depreciation based on the estimated economic useful lives of the assets and age of the assets.
-
(10)
-
Reflects
the adjustment of the Company's equity method investment in SBE Partners, L.P. to fair value based on an income approach, which calculated the
discounted cash flows of the Company's share of the partnership's interest in oil and gas proved reserves. The anticipated cash flows of the reserves were risked by reserve category and discounted at
10.5%. Weighted average commodity prices utilized in the determination of the fair value of oil and natural gas properties were $72.30 per barrel of oil, $3.50 per MMBtu of natural gas and $12.00 per
barrel of oil equivalent of natural gas liquids, after adjustment for transportation fees and regional price differentials. Base pricing was derived from an average of forward strip prices and
analysts' estimated prices.
-
(11)
-
Records
an intangible liability of approximately $8.3 million, $4.5 million of which was recorded as current, to adjust the Company's active rig
contract to fair value at September 9, 2016. The intangible liability will be amortized over the remaining life of the contract through July 2018.
-
(12)
-
Reflects
the adjustment of asset retirement obligations to fair value using estimated plugging and abandonment costs as of September 9, 2016, adjusted for
inflation and then discounted at the appropriate credit-adjusted risk free rate ranging from 5.5% to 6.6% depending on the life of the well. The fair value of asset retirement obligations was
estimated at $32.5 million, approximately $0.3 million of which was recorded as current. Refer to Note 9,
"Asset Retirement
Obligations"
for further details of the Company's asset retirement obligations.
-
(13)
-
Reflects
the adjustment of the 2020 Second Lien Notes and the 2022 Second Lien Notes to fair value. The fair value estimate was based on quoted market prices from
trades of such debt on September 9, 2016. Refer to Note 6,
"Debt"
for definitions of and further information regarding the 2020 Second
Lien Notes and 2022 Second Lien Notes.
-
(14)
-
Reflects
the adjustment of the Company's redeemable noncontrolling interest and related embedded derivative of HK TMS, LLC to fair value. The fair
value of the redeemable noncontrolling interest was estimated at $41.1 million and the embedded derivative was estimated at zero. For purposes of estimating the fair values, an income approach
was used that estimated fair value based on the anticipated cash flows associated with HK TMS, LLC's proved reserves, risked by reserve category and discounted using a weighted average
cost of capital rate of 12.5%. The value of the redeemable noncontrolling interest was further reduced by a probability factor of the potential assignment of the common shares of
HK TMS, LLC to Apollo Global Management, which occurred subsequent to the fresh-start date. Refer to Note 4,
"Acquisitions and
Divestitures,"
for further information regarding the divestiture of HK TMS, LLC on September 30, 2016.
-
(15)
-
Reflects
the cumulative effect of the fresh-start accounting adjustments discussed above.
19
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
4. ACQUISITIONS AND DIVESTITURES
Acquisitions
Southern Delaware Basin Assets (Pecos and Reeves Counties, Texas)
On January 18, 2017 (Successor), Halcón Energy Properties, Inc., a wholly owned subsidiary of the Company, entered
into a Purchase and Sale Agreement with Samson Exploration, LLC (Samson), pursuant to which it agreed to acquire a total of 20,901 net acres and related assets in the Southern Delaware Basin
located in Pecos and Reeves Counties, Texas (collectively, the Pecos County Assets), for a total purchase price of $703.9 million, subject to customary post-closing adjustments (the Pecos
County Acquisition). The Pecos County Acquisition closed on February 28, 2017. The Company funded the Pecos County Acquisition with the net proceeds from the private placement of its preferred
stock and borrowings under its Senior Credit Agreement. Refer to Note 11,
"Stockholders' Equity,"
for further discussion of the Company's
issuance of 8% Automatically Convertible Preferred Stock.
The
transaction had an effective date of November 1, 2016, and was subject to customary closing conditions, as well as the execution and delivery of certain other agreements.
The
Pecos County Acquisition was accounted for as a business combination in accordance with ASC 805,
Business Combinations
(ASC 805)
which, among other things, requires assets acquired and liabilities assumed to be measured at their acquisition date fair values. The estimated fair value of the properties acquired approximates the
fair value of consideration and as a result no goodwill was recognized.
The
following table summarizes the consideration paid to acquire the Pecos County Assets, as well as the preliminary amounts of assets acquired and liabilities assumed as of the
acquisition date (in thousands):
|
|
|
|
|
Cash consideration paid to Samson at closing
(1)
|
|
$
|
703,865
|
|
Less: Estimated post-effective closing date adjustments
(2)
|
|
|
(5,698
|
)
|
|
|
|
|
|
Estimated consideration transferred
|
|
$
|
698,167
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Plus: Estimated Fair Value of Liabilities Assumed:
|
|
|
|
|
Current liabilities
|
|
$
|
721
|
|
Asset retirement obligations
|
|
|
2,116
|
|
|
|
|
|
|
Amount attributable to liabilites assumed
|
|
|
2,837
|
|
|
|
|
|
|
Total purchase price plus liabilities assumed
|
|
$
|
701,004
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Estimated Fair Value of Assets Acquired:
|
|
|
|
|
Evaluated oil and natural gas properties
(3)(4)
|
|
$
|
160,275
|
|
Unevaluated oil and natural gas properties
(3)(4)
|
|
|
514,350
|
|
Gas gathering and other operating assets
(5)
|
|
|
26,379
|
|
|
|
|
|
|
Amount attributable to assets acquired
|
|
$
|
701,004
|
|
|
|
|
|
|
Goodwill
|
|
$
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
-
(1)
-
Represents amount of cash consideration, adjusted for customary closing items, for the purchase of the Pecos County Assets funded by the issuance of approximately
$400.1 million
20
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
4. ACQUISITIONS AND DIVESTITURES (Continued)
of new 8% automatically convertible preferred stock and borrowings under the Senior Credit Agreement.
-
(2)
-
In accordance with the purchase agreement, the effective date of the acquisition was November 1, 2016 and therefore revenues, expenses and related capital
expenditures from November 1, 2016 through the closing of the Pecos County Acquisition have been reflected as adjustments to the purchase price consideration. At closing, a net
$1.1 million was identified as reductions to the purchase price consideration for post effective date activities from November 1, 2016 through December 31, 2016. Estimates have
been made to reflect expected purchase price consideration adjustments for the post effective date period from January 1, 2017 through February 28, 2017 (the closing
date).
-
(3)
-
In estimating the fair value of the Pecos County Assets' oil and natural gas properties, the Company used an income approach. For
purposes of estimating the fair
value of the proved, probable and possible reserves, an income approach was used which estimated fair value based on the anticipated cash flows associated with the Pecos County Assets' estimated
reserves risked by reserve category and discounted using a weighted average cost of capital rate of 10.0% for proved reserves and 12.0% for probable and possible reserves. The proved reserve locations
were limited to wells expected to be drilled in the Company's five-year development plan. This estimation includes the use of unobservable inputs, such as estimated future production, oil and natural
gas revenues and expenses. The use of these unobservable inputs results in the fair value estimate of the Pecos County Assets being classified as
Level 3.
-
(4)
-
Weighted average commodity prices utilized in the determination of the fair value of oil and natural gas properties were
$76.10 per barrel of oil, $4.14 per Mcf of
natural gas and $29.48 per barrel of oil equivalent of natural gas liquids, after adjustment for transportation fees and regional price differentials. Base pricing was derived from an average of
forward strip prices and research analysts' estimated prices.
-
(5)
-
In estimating the fair value of the Pecos County Assets' gas gathering and
other operating assets, the Company used a combination of the cost and market approaches.
A market approach was relied upon to value the land, heavy equipment and vehicles, and in this valuation approach, recent transactions of similar assets were utilized to determine the value from a
market participant perspective. For the remaining other operating assets, a cost approach was used. The estimation of fair value under the cost approach was based on current replacement costs of the
assets, less depreciation based on the estimated economic useful lives of the assets and age of the assets.
The
following unaudited pro forma combined results of operations are provided for the three months ended March 31, 2017 and 2016 as though the Pecos County Acquisition had been
completed as of the beginning of the comparable prior annual reporting period, or January 1, 2016. The pro forma combined results of operations for the three months ended March 31, 2017
and 2016 have been prepared by adjusting the historical results of the Company to include the historical results of the Pecos County Assets. These supplemental pro forma results of operations are
provided for illustrative purposes only and do not purport to be indicative of the actual results that would have been achieved
by the combined company for the periods presented or that may be achieved by the combined company in the future. The pro forma results of operations do not include any cost savings or other synergies
that resulted, or may result, from the Pecos County Acquisition or any estimated costs that will be
21
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
4. ACQUISITIONS AND DIVESTITURES (Continued)
incurred
to integrate the Pecos County Assets. Future results may vary significantly from the results reflected in this unaudited pro forma financial information because of future events and
transactions, as well as other factors. Amounts included in the table below are rounded to thousands.
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
Predecessor
|
|
|
|
Three Months
Ended
March 31, 2017
(Unaudited)
|
|
|
|
Three Months
Ended
March 31, 2016
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenue
|
|
$
|
142,975
|
|
|
|
$
|
85,485
|
|
Net income (loss)
|
|
|
195,365
|
|
|
|
|
(541,729
|
)
|
Net income (loss) available to common stockholders
|
|
|
194,564
|
|
|
|
|
(568,592
|
)
|
Pro forma net income (loss) per share of common stock:
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
2.13
|
|
|
|
$
|
(4.74
|
)
|
Diluted
|
|
$
|
1.74
|
|
|
|
$
|
(4.74
|
)
|
The
Company's historical financial information was adjusted to give effect to the pro forma events that are directly attributable to Pecos County Assets and are factually supportable.
The unaudited pro forma consolidated results include the historical revenues and expenses of assets acquired and liabilities assumed, with the following
adjustments:
-
-
Adjustment to recognize incremental depletion expense under the full cost method of accounting based on the fair value of the oil and natural
gas properties and incremental accretion expense based on the asset retirement costs of the oil and natural gas properties at acquisition;
-
-
Adjustment to recognize incremental depreciation expense of the gas gathering and other operating assets and incremental accretion expense
based on the asset retirement costs of the gas gathering and other operating assets at acquisition; and
-
-
Eliminate transaction costs and non-recurring charges directly related to the transactions that were included in the historical results of
operations for the Company in the amount of $0.4 million. Transaction costs directly related to the transaction that do not have a continuing impact on the combined Company's operating results
have been excluded from the pro forma earnings.
For
the three months ended March 31, 2017, the Company recognized $3.3 million of oil, natural gas and natural gas liquids and other revenue related to the Pecos County
Assets and $1.6 million of net field operating income (oil, natural gas and natural gas liquids and other revenues less lease operating expense, workover expense, production taxes, gathering
and other expense, and depletion and depreciation expense) related to the Pecos County Assets. Additionally, non-recurring transaction costs of $0.4 million related to the Pecos County
Acquisition for the three months ended March 31, 2017 are included in the unaudited condensed consolidated statements of operations in "
General and
administrative"
expenses; these non-recurring transaction costs have been excluded from the pro forma results for all periods presented in the above table.
22
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
4. ACQUISITIONS AND DIVESTITURES (Continued)
Divestitures
East Texas Eagle Ford Assets
On January 24, 2017 (Successor), certain of the Company's subsidiaries entered into an Agreement of Sale and Purchase with a subsidiary
of Hawkwood Energy, LLC (Hawkwood) for the sale of all of its oil and natural gas properties and related assets located in the Eagle Ford formation of East Texas (the El Halcón
Assets) for a total adjusted sales price of $483.5 million, subject to post-closing adjustments (the El Halcón Divestiture). The effective date of the sale was January 1,
2017 and the transaction closed on March 9, 2017. The sale properties included approximately 80,500 net acres prospective for the Eagle Ford formation in East Texas and related gas gathering
and other operating assets. The Company used the net proceeds from the sale to repay borrowings outstanding under its Senior Credit Agreement and for general corporate purposes.
The
net proceeds from the sale were allocated between the Company's oil and natural gas properties, gas gathering and other operating assets and liabilities transferred on a fair value
basis. Approximately $10.2 million was allocated to gas gathering and other operating assets and approximately $477.3 million was allocated to the Company's oil and natural gas
properties.
As
discussed further in Note 5,
"Oil and Natural Gas Properties,"
the Company uses the full cost method of accounting for its
investment in oil and natural gas properties. Under this method of accounting, sales of oil and gas properties are accounted for as adjustments of capitalized costs with no gain or loss recognized,
unless the adjustment significantly alters the relationship between capitalized costs and proved reserves. If the El Halcón Divestiture was accounted for as an adjustment of capitalized
costs with no gain or loss recognized, the adjustment would have significantly altered the relationship between capitalized costs and proved reserves. Accordingly, the Company recognized a gain on the
sale of $231.2 million during the three months ended March 31, 2017 (Successor). The carrying value of the properties sold was determined by allocating total capitalized costs within the
full cost pool between properties sold and properties retained based on their relative fair values. The gain was recorded in
"Gain (loss) on sale of oil and natural gas
properties,"
on the Company's unaudited condensed consolidated statements of operations.
HK TMS, LLC
On September 30, 2016, certain wholly-owned subsidiaries of the Successor Company executed an Assignment and Assumption Agreement with an
affiliate of Apollo Global Management (Apollo) pursuant to which Apollo acquired one hundred percent (100%) of the common shares (the Membership Interests) of HK TMS, LLC (HK TMS), which
transaction is referred to as the HK TMS Divestiture. HK TMS was previously a wholly-owned subsidiary and held all of the Successor Company's oil and natural gas properties in the Tuscaloosa Marine
Shale (TMS). In exchange for the assignment of the Membership Interests, Apollo assumed all obligations relating to the Membership Interests, which were previously classified as
"Mezzanine Equity"
on
the unaudited condensed consolidated balance sheets of HK TMS, from and after such date. Prior to the HK TMS Divestiture, the
preferred shares were considered probable of becoming redeemable and therefore were accreted up to the estimated required redemption value. The accretion was presented as a deemed dividend and
recorded in "
Preferred dividends and accretion on redeemable noncontrolling interest
" on the unaudited condensed consolidated statements of operations.
For the three months ended March 31, 2016 (Predecessor), HK TMS issued 3,295 additional preferred shares to Apollo for dividends paid-in-kind. These dividends were presented within
"
Preferred
23
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
4. ACQUISITIONS AND DIVESTITURES (Continued)
dividends and accretion on redeemable noncontrolling interest
" on the unaudited condensed consolidated statements of operations.
HK
TMS was not included in the chapter 11 bankruptcy filings or the Restructuring Support Agreement discussed in Note 2,
"
Reorganization.
"
5. OIL AND NATURAL GAS PROPERTIES
The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs of acquisition, exploration and
development of oil and natural gas reserves (including such costs as leasehold acquisition costs, geological expenditures, dry hole costs, tangible and intangible development costs and direct internal
costs) are capitalized as the cost of oil and natural gas properties when incurred. To the extent capitalized costs of evaluated oil and natural gas properties, net of accumulated depletion, exceed
the discounted future net revenues of proved oil and natural gas reserves, net of deferred taxes, such excess capitalized costs are charged to expense.
Additionally,
the Company assesses all properties classified as unevaluated property on a quarterly basis for possible impairment or reduction in value. The Company assesses properties
on an individual basis or as a group, if properties are individually insignificant. The assessment includes consideration of the following factors, among others: intent to drill; remaining lease term;
geological and geophysical evaluations; drilling results and activity; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period
in which these factors indicate impairment, the cumulative drilling costs incurred to date for such property and all or a portion of the associated leasehold costs are transferred to the full cost
pool and are then subject to depletion and the full cost ceiling test limitation.
Investments
in unevaluated oil and natural gas properties and exploration and development projects for which depletion expense is not currently recognized, and for which exploration or
development activities are in progress, qualify for interest capitalization. The Predecessor Company determined capitalized interest by multiplying the Predecessor Company's weighted-average borrowing
cost on debt by the average amount of qualifying costs incurred that were excluded from the full cost pool. The capitalized interest amounts were recorded as additions to unevaluated oil and natural
gas properties on the unaudited condensed consolidated balance sheets. For the three months ended March 31, 2016 (Predecessor), the Company capitalized interest costs of $32.1 million.
The Successor Company's policy on the capitalization of interest establishes thresholds for the determination of a development project for the purpose of interest capitalization.
At
March 31, 2017 (Successor), the ceiling test value of the Company's reserves was calculated based on the first-day-of-the-month average for the 12-months ended March 31,
2017 of the West Texas Intermediate (WTI) crude oil spot price of $47.61 per barrel, adjusted by lease or field for quality, transportation fees, and regional price differentials, and the
first-day-of-the-month average for the 12-months ended March 31, 2017 of the Henry Hub natural gas price of $2.73 per million British thermal units (MMBtu), adjusted by lease or field for
energy content, transportation fees, and regional price differentials. Using these prices, the Company's net book value of oil and natural gas properties at March 31, 2017 (Successor) did not
exceed the ceiling amount.
At
March 31, 2016 (Predecessor), the ceiling test value of the Company's reserves was calculated based on the first-day-of-the-month average for the 12-months ended
March 31, 2016 of the WTI crude oil spot price of $46.26 per barrel, adjusted by lease or field for quality, transportation fees, and
24
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
5. OIL AND NATURAL GAS PROPERTIES (Continued)
regional
price differentials, and the first-day-of-the-month average for the 12-months ended March 31, 2016 of the Henry Hub natural gas price of $2.40 per MMBtu, adjusted by lease or field for
energy content, transportation fees, and regional price differentials. Using these prices, the Company's net book value of oil and natural gas properties at March 31, 2016 (Predecessor)
exceeded the ceiling amount by $496.9 million ($315.1 million after taxes, before valuation allowance) which resulted in a ceiling test impairment of that amount for the quarter. The
impairment reflects additional transfers of the remaining unevaluated Utica / Point Pleasant (Utica) and TMS properties of approximately $330.4 million and $74.8 million, respectively,
to the full cost pool and, to a lesser extent, an 8% decrease in the first-day-of-the-month average price for crude oil used in the ceiling test calculation, which was $50.28 per barrel at
December 31, 2015 (Predecessor). As discussed above, the Company considers the facts and circumstances around its unevaluated properties that may indicate impairment on a quarterly basis.
Management concluded that it was no longer probable that capital would be available or approved to continue exploratory drilling activities in the Company's Utica or TMS acreage positions in advance
of the related lease expirations due to the Company's evaluation of strategic alternatives to reduce its long-term debt while preserving liquidity in light of low commodity prices, together with a
reduction of the Company's exploration department and the Company's intent to expend capital only on its most economical and proven areas.
The
Company recorded the full cost ceiling test impairment in "
Full cost ceiling impairment
" in the Company's unaudited condensed
consolidated statements of operations and in "
Accumulated depletion
" in the Company's unaudited condensed consolidated balance sheets. Changes in
commodity prices, production rates, levels of reserves, future development costs, transfers of unevaluated properties, capital spending, and other factors will determine the Company's ceiling test
calculations and impairment analyses in future periods.
6. DEBT
Long-term debt as of March 31, 2017 (Successor) and December 31, 2016 (Successor), consisted of the following (in thousands):
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
March 31,
2017
|
|
December 31,
2016
|
|
Senior revolving credit facility
|
|
$
|
|
|
$
|
186,000
|
|
8.625% senior secured second lien notes due 2020
(1)
|
|
|
|
|
|
672,613
|
|
12.0% senior secured second lien notes due 2022
(2)
|
|
|
106,277
|
|
|
106,040
|
|
6.75% senior notes due 2025
(3)
|
|
|
834,295
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
940,572
|
|
$
|
964,653
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
-
(1)
-
On February 16, 2017, the Company repurchased approximately 41% of the outstanding aggregate principal amount of its 2020 Second Lien Notes with proceeds from
the issuance of new 6.75% senior unsecured notes due 2025. The remaining aggregate principal amount was redeemed on March 20, 2017. Amount was net of a $27.4 million unamortized discount
at December 31, 2016 (Successor). Refer to "8.625% Senior Secured Second Lien Notes" below for further details.
-
(2)
-
Amounts are net of a
$6.5 million and $6.8 million unamortized discount at March 31, 2017 (Successor) and December 31, 2016 (Successor),
respectively.
25
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
6. DEBT (Continued)
-
(3)
-
On February 16, 2017, the Company issued $850.0 million aggregate principal amount of new 6.75% senior unsecured notes due 2025. Amount is net of
$15.7 million unamortized debt issuance costs at March 31, 2017 (Successor). Refer to "6.75% Senior Notes" below for further
details.
Senior Revolving Credit Facility
On the Effective Date, the Company entered into a senior secured revolving credit agreement (the Senior Credit Agreement) with JPMorgan Chase
Bank, N.A., as administrative agent, and certain other financial institutions party thereto, as lenders. The Senior Credit Agreement provides for a $1.5 billion senior secured reserve-based
revolving credit facility with a current borrowing base of $650.0 million, that was affirmed in the redetermination that occurred on May 2, 2017. The maturity date of the Senior Credit
Agreement is July 28, 2021. The borrowing base will be redetermined semi-annually, with the lenders and the Company each having the right to one interim unscheduled redetermination between any
two consecutive semi-annual redeterminations. The borrowing base takes into account the estimated value of the Company's oil and natural gas properties, proved reserves, total indebtedness, and other
relevant factors consistent with customary oil and natural gas lending criteria. Amounts outstanding under the Senior Credit Agreement bear interest at specified margins over the base rate of 1.75% to
2.75% for ABR-based loans or at specified margins over LIBOR of 2.75% to 3.75% for Eurodollar-based loans. These margins fluctuate based on the Company's utilization of the facility. The Company may
elect, at its option, to prepay any borrowings outstanding under the Senior Credit Agreement without premium or penalty (except with respect to any break funding payments which may be payable pursuant
to the terms of the Senior Credit Agreement). Additionally, if the Company has outstanding borrowings or letters of credit or reimbursement obligations in respect of letters of credit and the
Consolidated Cash Balance (as defined in the Senior Credit Agreement) exceeds $100.0 million as of the close of business on the most recently ended business day, the Company may also be
required to make mandatory prepayments.
Amounts
outstanding under the Senior Credit Agreement are guaranteed by certain of the Company's direct and indirect subsidiaries and secured by a security interest in substantially all
of the assets of the Company and its subsidiaries.
The
Senior Credit Agreement also contains certain financial covenants, including the maintenance of (i) a Total Net Indebtedness Leverage Ratio (as defined in the Senior Credit
Agreement) not to exceed 4.75:1.00 initially, determined as of each four fiscal quarter periods and commencing with the fiscal quarter ending September 30, 2016, stepping down to 4.50:1.00 and
4.00:1.00 on September 30, 2017 and March 31, 2019, respectively, and (ii) a Current Ratio (as defined in the Senior Credit Agreement) not to be less than 1.00:1.00. At
March 31, 2017 (Successor), the Company was in compliance with the financial covenants under the Senior Credit Agreement.
The
Senior Credit Agreement also contains certain events of default, including non-payment; breaches of representations and warranties; non-compliance with covenants or other agreements;
cross-default to material indebtedness; judgments; change of control; and voluntary and involuntary bankruptcy.
At
March 31, 2017 (Successor), under the then effective borrowing base of $600.0 million, the Company had no borrowings outstanding, approximately $6.4 million
letters of credit outstanding and approximately $593.6 million of borrowing capacity available under the Senior Credit Agreement.
26
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
6. DEBT (Continued)
8.625% Senior Secured Second Lien Notes
On May 1, 2015 (Predecessor), the Company issued $700.0 million aggregate principal amount of its 8.625% senior secured second
lien notes due 2020 (the 2020 Second Lien Notes) in a private offering. The 2020 Second Lien Notes were issued at par. The net proceeds from the sale of the 2020 Second Lien Notes were approximately
$686.2 million (after deducting offering fees and expenses). The 2020 Second Lien Notes bore interest at a rate of 8.625% per annum, payable semi-annually on February 1 and
August 1 of each year. In accordance with the Plan, the 2020 Second Lien Notes were unimpaired and reinstated upon the Company's emergence from chapter 11 bankruptcy.
On
February 16, 2017 (Successor), the Company paid approximately $303.5 million for approximately $289.2 million principal amount of 2020 Second Lien Notes, a
make-whole premium of $13.2 million plus accrued and unpaid interest of approximately $1.1 million to repurchase such notes pursuant to a tender offer and issued a redemption notice to
redeem the remaining 2020 Second Lien Notes. On February 21, 2017 (Successor), the Company paid approximately $1.2 million for approximately $1.2 million of principal amount of
2020 Second Lien Notes, a make-whole premium of approximately $54,000 plus accrued and unpaid interest to repurchase such notes pursuant to guaranteed delivery procedures of the tender offer. On
March 20, 2017 (Successor), the Company paid approximately $432.0 million for $409.6 million aggregate principal amount of 2020 Second Lien Notes, a make-whole premium of
$17.7 million and unpaid interest of approximately $4.8 million to redeem the remaining notes at a price of 104.313% of the principal amount thereof, plus accrued and unpaid interest to,
but not including, the redemption date. The repurchase and redemption of the 2020 Second Lien Notes was funded with proceeds from the issuance of $850.0 million in new 6.75% senior unsecured
notes due 2025.
The
Company recognized a loss on the extinguishment of debt, representing a $30.9 million loss on the repurchase for the tender premium paid and a $26.0 million loss on the
write-off of the discount on the notes. The loss was recorded in
"Gain (loss) on extinguishment of debt"
on the unaudited condensed consolidated
statements of operations.
12.0% Senior Secured Second Lien Notes
On December 21, 2015 (Predecessor), the Company completed the issuance in a private placement of approximately $112.8 million
aggregate principal amount of new 12.0% senior secured second lien notes due 2022 (the 2022 Second Lien Notes) in exchange for approximately $289.6 million principal amount of its then
outstanding senior unsecured notes, consisting of $116.6 million principal amount of 9.75% senior notes due 2020, $137.7 million principal amount of 8.875% senior notes due 2021 and
$35.3 million principal amount of 9.25% senior notes due 2022. At closing, the Predecessor Company paid all accrued and unpaid interest since the respective interest payment dates of the
unsecured notes surrendered in the exchange. The Predecessor Company recorded the issuance of the 2022 Second Lien Notes at par.
Interest
on the 2022 Second Lien Notes accrues at a rate of 12.0% per annum, payable semi-annually on February 15 and August 15 of each year. The 2022 Second Lien Notes
will mature on February 15, 2022. The 2022 Second Lien Notes are secured by second-priority liens on substantially all of the Company's, and certain subsidiaries of the Company (the
Guarantors') assets to the extent such assets secure the Company's Senior Credit Agreement (the Collateral). Pursuant to the terms of the Intercreditor Agreement, dated December 21, 2015, the
security interest in the Collateral securing the 2022 Second Lien Notes and the guarantees are contractually subordinated to liens that secure the
27
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
6. DEBT (Continued)
Company's
Senior Credit Agreement and certain other permitted indebtedness. Consequently, the 2022 Second Lien Notes and the guarantees are effectively subordinated to the Senior Credit Agreement and
such other indebtedness to the extent of the value of the Collateral. In accordance with the terms of the Plan, the 2022 Second Lien Notes were unimpaired and reinstated upon the Company's emergence
from chapter 11 bankruptcy.
As
discussed in Note 3,
"Fresh-start Accounting,"
on September 9, 2016, the Company adjusted the 2022 Second Lien Notes to
fair value of $107.2 million by recording a discount of $5.7 million to be amortized over the remaining life of the 2020 Second Lien Notes, using the effective interest method.
In
addition, on September 28, 2016, the Company, each of its guarantors and U.S. Bank National Association, as trustee, entered into a supplemental indenture (the 2022 Second Lien
Note Supplemental Indenture) to the Indenture dated as of December 21, 2015 with respect to the
Company's 2022 Second Lien Notes (the 2022 Second Lien Note Indenture). The 2022 Second Lien Note Supplemental Indenture amended the 2022 Second Lien Note Indenture to modify the incurrence of
indebtedness, lien and restricted payments covenants. The 2022 Second Lien Note Supplemental Indenture became operative upon the consummation of the consent solicitation on September 30, 2016.
The Company paid an aggregate consent fee of approximately $1.4 million to holders of the 2022 Second Lien Notes and recorded an additional discount of approximately $1.4 million.
The
remaining unamortized discount was $6.5 million at March 31, 2017 (Successor).
6.75% Senior Notes
On February 16, 2017 (Successor), the Company issued $850.0 million aggregate principal amount of new 6.75% senior unsecured notes
due 2025 (the 2025 Notes) in a private placement exempt from registration under Section 4(a)(2) of the Securities Act of 1933, as amended (Securities Act), Rule 144A and
Regulation S, and applicable state securities laws. The 2025 Notes were issued at par and bear interest at a rate of 6.75% per annum, payable semi-annually on February 15 and
August 15 of each year, beginning on August 15, 2017. The 2025 Notes will mature on February 15, 2025. Proceeds from the private placement were approximately $834.1 million
after deducting initial purchasers' discounts and commissions and offering expenses. The Company used a portion of the net proceeds from the private placement to fund the repurchase and redemption of
the outstanding 2020 Second Lien Notes, as discussed above, and for general corporate purposes.
The
2025 Notes are governed by an Indenture, dated as of February 16, 2017 (the February 2017 Indenture) by and among the Company, the Guarantors and U.S. Bank National
Association, as Trustee, which contains affirmative and negative covenants that, among other things, limit the ability of the Company and the Guarantors to incur indebtedness; purchase or redeem stock
or subordinated indebtedness; make investments; create liens; enter into transactions with affiliates; sell assets; refinance certain indebtedness; merge with or into other companies or transfer
substantially all of their assets; and, in certain circumstances, to pay dividends or make other distributions on stock. The February 2017 Indenture also contains customary events of default. Upon the
occurrence of certain events of default, the Trustee or the holders of the 2025 Notes may declare all outstanding 2025 Notes to be due and payable immediately. The 2025 Notes are jointly and
severally, fully and unconditionally guaranteed on a senior unsecured basis by the Company's existing wholly-owned subsidiaries. Halcón, the issuer of the 2025 Notes, has no material
independent assets or operations apart from the assets and operations of its subsidiaries.
28
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
6. DEBT (Continued)
In connection with the sale of the 2025 Notes, on February 16, 2017, the Company, the Guarantors and J.P. Morgan Securities LLC, on behalf of itself and as representative
of the initial purchasers, entered into a Registration Rights Agreement (the 2017 Registration Rights Agreement) pursuant to which the Company agreed to, among other things, use reasonable best
efforts to file a registration statement under the Securities Act and complete an exchange offer for the 2025 Notes within 365 days after closing.
At
any time prior to February 15, 2020, the Company may redeem the 2025 Notes, in whole or in part, at a redemption price equal to 100% of their principal amount plus a make-whole
premium, together with accrued and unpaid interest, if any, to the redemption date. The 2025 Notes will be redeemable, in whole or in part, on or after February 15, 2020 at redemption prices
equal to the principal amount multiplied by the percentage set forth below, plus accrued and unpaid interest (if any) on the 2025 Notes redeemed during the twelve month period indicated beginning on
February 15 of the years indicated below:
|
|
|
|
|
Year
|
|
Percentage
|
|
2020
|
|
|
105.063
|
|
2021
|
|
|
103.375
|
|
2022
|
|
|
101.688
|
|
2023 and thereafter
|
|
|
100.000
|
|
Additionally,
the Company may redeem up to 35% of the 2025 Notes prior to February 15, 2020 for a redemption price of 106.75% of the principal amount thereof, plus accrued and
unpaid interest, utilizing net cash proceeds from certain equity offerings. In addition, upon a change of control of the Company, holders of the 2025 Notes will have the right to require the Company
to repurchase all or any part of their 2025 Notes for cash at a price equal to 101% of the aggregate principal amount of the 2025 Notes repurchased, plus any accrued and unpaid interest.
Debt Issuance Costs
The Company capitalizes certain direct costs associated with the issuance of debt and amortizes such costs over the lives of the respective
debt. During the three months ended March 31, 2017 (Successor), the Company capitalized approximately $15.9 million of debt issuance costs related to the 2025 Notes. As part of the
Company's reorganization, all debt issuance costs related to the Company's Predecessor debt were extinguished. The debt issuance costs for the Successor
Company's senior unsecured debt are presented in
"Long-term debt, net"
within total liabilities on the unaudited condensed consolidated balance sheet at
March 31, 2017 (Successor).
7. FAIR VALUE MEASUREMENTS
Pursuant to ASC 820,
Fair Value Measurements
(ASC 820), the Company's determination of fair value incorporates not only the credit
standing of the counterparties involved in transactions with the Company resulting in receivables on the Company's unaudited condensed consolidated balance sheets, but also the impact of the Company's
nonperformance risk on its own liabilities. ASC 820 defines fair value as 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). ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The
29
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
7. FAIR VALUE MEASUREMENTS (Continued)
hierarchy
assigns the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs
(Level 3). Level 2 measurements are inputs that are observable for assets or liabilities, either directly or indirectly, other than quoted prices included within Level 1. 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. The Company classifies fair value balances based on the observability of those inputs.
As
required by ASC 820, a financial instrument's level within the fair value hierarchy is 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 to the fair value measurement requires judgment, and may affect the
valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. There were no transfers between fair value hierarchy levels for any period presented. 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 as of March 31, 2017 (Successor) and
December 31, 2016 (Successor) (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
March 31, 2017
|
|
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Receivables from derivative contracts
|
|
$
|
|
|
$
|
14,962
|
|
$
|
|
|
$
|
14,962
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities from derivative contracts
|
|
$
|
|
|
$
|
1,745
|
|
$
|
|
|
$
|
1,745
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2016
|
|
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Total
|
|
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Receivables from derivative contracts
|
|
$
|
|
|
$
|
5,923
|
|
$
|
|
|
$
|
5,923
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities from derivative contracts
|
|
$
|
|
|
$
|
16,920
|
|
$
|
|
|
$
|
16,920
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivative
contracts listed above as Level 2 include collars and swaps that are carried at fair value. The Company records the net change in the fair value of these positions in
"Net gain (loss) on derivative
contracts"
on the unaudited condensed consolidated statements of operations. The Company is able to value the assets and
liabilities based on observable market data for similar instruments, which resulted in the Company reporting its derivatives as Level 2. This observable data includes the forward curves for
commodity prices based on quoted market prices and implied volatility factors related to changes in the forward curves. See Note 8,
"Derivative and Hedging
Activities,"
for additional discussion of derivatives.
The
Company's derivative contracts are with major financial institutions with investment grade credit ratings which are believed to have minimal credit risk. As such, the Company is
exposed to credit
30
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
7. FAIR VALUE MEASUREMENTS (Continued)
risk
to the extent of nonperformance by the counterparties in the derivative contracts; however, the Company does not anticipate such nonperformance.
The
following disclosure of the estimated fair value of financial instruments is made in accordance with the requirements of ASC 825,
Financial
Instruments
. The estimated fair value amounts have been determined at discrete points in time based on relevant market information. These estimates involve uncertainties and
cannot be determined with precision. The estimated fair value of cash, accounts receivables and accounts payables approximate their carrying value due to their short-term nature. The estimated fair
value of the Company's Senior Credit Agreement approximates carrying value because the interest rates approximate current market rates. The following table presents the estimated fair values of the
Company's fixed interest rate debt instruments as of March 31, 2017 (Successor) and December 31, 2016 (Successor) (excluding discounts and debt issuance costs) (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
March 31, 2017
|
|
December 31, 2016
|
|
Debt
|
|
Principal
Amount
|
|
Estimated
Fair Value
|
|
Principal
Amount
|
|
Estimated
Fair Value
|
|
8.625% senior secured second lien notes
|
|
$
|
|
|
$
|
|
|
$
|
700,000
|
|
$
|
733,250
|
|
12.0% senior secured second lien notes
|
|
|
112,826
|
|
|
132,147
|
|
|
112,826
|
|
|
123,827
|
|
6.75% senior notes
|
|
|
850,000
|
|
|
838,525
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
962,826
|
|
$
|
970,672
|
|
$
|
812,826
|
|
$
|
857,077
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The
fair value of the Company's fixed interest rate debt instruments was calculated using Level 2 criteria. The fair value of the Company's senior notes is based on quoted market
prices from trades of such debt.
On
February 28, 2017 (Successor), the Company closed the Pecos County Acquisition and recorded the assets acquired and liabilities assumed at their acquisition date fair values.
See Note 4,
"Acquisitions and Divestitures
," for a discussion of the fair value approaches used by the Company and the classification of the
estimates within the fair value hierarchy.
On
September 9, 2016, the Company emerged from chapter 11 bankruptcy and adopted fresh-start accounting, which resulted in the Company becoming a new entity for financial
reporting purposes. Upon the adoption of fresh-start accounting, the Company's assets and liabilities were recorded at their fair values as of the fresh-start reporting date, September 9, 2016.
See Note 3,
"Fresh-start Accounting,"
for a detailed discussion of the fair value approaches used by the Company.
During
the three months ended March 31, 2016 (Predecessor), the Company recorded a non-cash impairment charge of $28.1 million related to its gas gathering systems. See
Note 1,
"Financial Statement Presentation,"
for a discussion of the valuation approach used and the classification of the estimate within the
fair value hierarchy.
The
Company follows the provisions of ASC 820 for nonfinancial assets and liabilities measured at fair value on a non-recurring basis. These provisions apply to the Company's initial
recognition of asset retirement obligations for which fair value is used. The asset retirement obligation estimates are derived from historical costs and management's expectation of future cost
environments; consequently, the Company has designated these liabilities as Level 3. See Note 9, "
Asset Retirement Obligations
," for
31
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
7. FAIR VALUE MEASUREMENTS (Continued)
a
reconciliation of the beginning and ending balances of the liability for the Company's asset retirement obligations.
8. DERIVATIVE AND HEDGING ACTIVITIES
The Company is exposed to certain risks relating to its ongoing business operations, including commodity price risk and interest rate risk. Derivative contracts are utilized to hedge the
Company's exposure to price fluctuations and reduce the variability in the Company's cash flows associated with anticipated sales of future oil and natural gas production. When derivative contracts
are available at terms (or prices) acceptable to the Company, it generally hedges a substantial, but varying, portion of anticipated oil and natural gas production for future periods. Derivatives are
carried at fair value on the unaudited condensed consolidated balance sheets as assets or liabilities, with the changes in the fair value included in the unaudited condensed consolidated statements of
operations for the period in which the change occurs. The Company's hedge policies and objectives may change significantly as its operational profile changes and/or commodities prices change. The
Company does not enter into derivative contracts for speculative trading purposes.
It
is the Company's policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions determined by management as competent and competitive
market makers. The Company did not post collateral under any of its derivative contracts as they are secured under the Company's Senior Credit Agreement or are uncollateralized trades.
At
March 31, 2017 (Successor), the Company's crude oil and natural gas derivative positions consisted of swaps, basis swaps and costless put/call "collars." At December 31,
2016 (Successor), the Company's derivative positions consisted of collars only. Swaps are designed so that the Company receives or makes payments based on a differential between fixed and variable
prices for crude oil and natural gas. Basis swaps effectively lock in a price differential between regional prices (i.e. Midland) and the relevant price index at which the oil production is
sold (i.e. Cushing). A costless collar consists of a sold call, which establishes a maximum price the Company will receive for the volumes under contract and a purchased put that establishes a
minimum price. The Company has elected not to designate any of its derivative contracts for hedge accounting. Accordingly, the Company records the net change in the mark-to-market valuation of these
derivative contracts, as well as payments and receipts on settled derivative contracts, in
"Net gain (loss) on derivative contracts"
on the unaudited
condensed consolidated statements of operations.
At
March 31, 2017 (Successor), the Company had 28 open commodity derivative contracts summarized in the following tables: four natural gas collar arrangements, two crude oil basis
swaps and 22 crude oil collar arrangements.
At
December 31, 2016 (Successor), the Company had 22 open commodity derivative contracts summarized in the following tables: two natural gas collar arrangements and 20 crude oil
collar arrangements.
All
derivative contracts are recorded at fair market value in accordance with ASC 815 and ASC 820 and included in the unaudited condensed consolidated balance sheets as
assets or liabilities.
32
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
8. DERIVATIVE AND HEDGING ACTIVITIES (Continued)
The
following table summarizes the location and fair value amounts of all derivative contracts in the unaudited condensed consolidated balance sheets (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Asset derivative contracts
|
|
|
|
Liability derivative
contracts
|
|
|
|
|
|
Successor
|
|
|
|
Successor
|
|
Derivatives not designated as
hedging contracts under
ASC 815
|
|
Balance sheet location
|
|
March 31,
2017
|
|
December 31,
2016
|
|
Balance sheet location
|
|
March 31,
2017
|
|
December 31,
2016
|
|
Commodity contracts
|
|
Current assetsreceivables from derivative contracts
|
|
$
|
11,757
|
|
$
|
5,923
|
|
Current liabilitiesliabilities from derivative contracts
|
|
$
|
(1,578
|
)
|
$
|
(16,434
|
)
|
Commodity contracts
|
|
Other noncurrent assetsreceivables from derivative contracts
|
|
|
3,205
|
|
|
|
|
Other noncurrent liabilitiesliabilities from derivative contracts
|
|
|
(167
|
)
|
|
(486
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total derivatives not designated as hedging contracts under ASC 815
|
|
|
|
$
|
14,962
|
|
$
|
5,923
|
|
|
|
$
|
(1,745
|
)
|
$
|
(16,920
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The
following table summarizes the location and amounts of the Company's realized and unrealized gains and losses on derivative contracts in the Company's unaudited condensed
consolidated statements of operations (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amount of gain or (loss)
recognized in income on
derivative contracts for the
|
|
|
|
|
|
Successor
|
|
|
|
Predecessor
|
|
|
|
Location of gain or (loss) recognized in
income on derivative contracts
|
|
Three Months
Ended
March 31, 2017
|
|
|
|
Three Months
Ended
March 31, 2016
|
|
Derivatives not designated as hedging
contracts under ASC 815
|
|
|
|
|
|
|
Commodity contracts:
|
|
|
|
|
|
|
|
|
|
|
|
Unrealized gain (loss) on commodity contracts
|
|
Other income (expenses)net gain (loss) on derivative contracts
|
|
$
|
24,214
|
|
|
|
$
|
(88,978
|
)
|
Realized gain (loss) on commodity contracts
|
|
Other income (expenses)net gain (loss) on derivative contracts
|
|
|
2,184
|
|
|
|
|
107,720
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total net gain (loss) on derivative contracts
|
|
|
|
$
|
26,398
|
|
|
|
$
|
18,742
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
At
March 31, 2017 (Successor) and December 31, 2016 (Successor), the Company had the following open crude oil and natural gas derivative contracts:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
|
|
|
|
March 31, 2017
|
|
|
|
|
|
|
|
|
|
Floors
|
|
Ceilings
|
|
|
|
Period
|
|
Instrument
|
|
Commodity
|
|
Volume in
Mmbtu's/
Bbl's
|
|
Price /
Price Range
|
|
Weighted
Average
Price
|
|
Price /
Price Range
|
|
Weighted
Average
Price
|
|
Basis
Differential
|
|
April 2017 - December 2017
(1)
|
|
Collars
|
|
Natural Gas
|
|
|
4,125,000
|
|
$3.10 - 3.26
|
|
$
|
3.17
|
|
$3.44 - 3.76
|
|
$
|
3.58
|
|
$
|
0.00
|
|
April 2017 - December 2017
(2)
|
|
Collars
|
|
Crude Oil
|
|
|
5,156,250
|
|
47.00 - 60.00
|
|
|
51.39
|
|
52.00 - 76.84
|
|
|
58.75
|
|
|
|
|
January 2018 - December 2018
(2)
|
|
Collars
|
|
Crude Oil
|
|
|
1,460,000
|
|
50.00 - 53.00
|
|
|
51.50
|
|
58.00 - 60.00
|
|
|
59.00
|
|
|
|
|
January 2018 - December 2018
(3)
|
|
Basis Swaps
|
|
Crude Oil
|
|
|
912,500
|
|
|
|
|
|
|
|
|
|
|
|
|
(1.05
|
)
|
33
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
8. DERIVATIVE AND HEDGING ACTIVITIES (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
|
|
|
|
December 31, 2016
|
|
|
|
|
|
|
|
|
|
Floors
|
|
Ceilings
|
|
Period
|
|
Instrument
|
|
Commodity
|
|
Volume in
Mmbtu's/
Bbl's
|
|
Price /
Price Range
|
|
Weighted
Average
Price
|
|
Price /
Price Range
|
|
Weighted
Average
Price
|
|
January 2017 - December 2017
|
|
Collars
|
|
Natural Gas
|
|
|
3,650,000
|
|
$3.15 - $3.26
|
|
$
|
3.20
|
|
$3.50 - $3.76
|
|
$
|
3.63
|
|
January 2017 - December 2017
|
|
Collars
|
|
Crude Oil
|
|
|
6,843,750
|
|
47.00 - 60.00
|
|
|
51.39
|
|
52.00 - 76.84
|
|
|
58.75
|
|
January 2018 - December 2018
|
|
Collars
|
|
Crude Oil
|
|
|
730,000
|
|
53.00
|
|
|
53.00
|
|
58.00
|
|
|
58.00
|
|
-
(1)
-
Subsequent to March 31, 2017, the Company entered into a natural gas collar at a floor of $3.00 per MMBtu and a ceiling of $3.38 per MMBtu for a total of
1,525,000 MMBtu for the period from May 2017 through December 2018 and a natural gas collar at a floor of $3.00 per MMBtu and a ceiling of $3.39 per MMBtu for a total of 1,372,500 MMBtu for the period
from July 2017 through December 2018.
-
(2)
-
Subsequent to March 31, 2017, the Company entered into a crude oil collar at a floor of $50.00 per Bbl and a ceiling of $55.25 per Bbl for a total of 610,000
Bbls for the period from May 2017 through December 2018 and crude oil collars at floors ranging from $51.05 to $51.07 per Bbl and ceilings ranging from $56.05 to $56.07 per Bbl for a total of 276,000
Bbls for the period from July 2017 to December 2017.
-
(3)
-
Subsequent to March 31, 2017, the Company entered into a crude oil basis swap at a basis differential of ($1.50) for a total of 912,500 Bbls for 2018.
The
Company presents the fair value of its derivative contracts at the gross amounts in the unaudited condensed consolidated balance sheets. The following table shows the potential
effects of master netting arrangements on the fair value of the Company's derivative contracts (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivative Assets
|
|
Derivative Liabilities
|
|
|
|
Successor
|
|
Successor
|
|
Offsetting of Derivative Assets and Liabilities
|
|
March 31,
2017
|
|
December 31,
2016
|
|
March 31,
2017
|
|
December 31,
2016
|
|
Gross Amounts Presented in the Consolidated Balance Sheet
|
|
$
|
14,962
|
|
$
|
5,923
|
|
$
|
(1,745
|
)
|
$
|
(16,920
|
)
|
Amounts Not Offset in the Consolidated Balance Sheet
|
|
|
(1,644
|
)
|
|
(5,283
|
)
|
|
1,578
|
|
|
5,075
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Amount
|
|
$
|
13,318
|
|
$
|
640
|
|
$
|
(167
|
)
|
$
|
(11,845
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The
Company enters into an International Swap Dealers Association Master Agreement (ISDA) with each counterparty prior to a derivative contract with such counterparty. The ISDA is a
standard contract that governs all derivative contracts entered into between the Company and the respective counterparty. The ISDA allows for offsetting of amounts payable or receivable between the
Company and the counterparty, at the election of both parties, for transactions that occur on the same date and in the same currency.
9. ASSET RETIREMENT OBLIGATIONS
The Company records an asset retirement obligation (ARO) on oil and natural gas properties when it can reasonably estimate the fair value of an obligation to perform site reclamation,
dismantle facilities or plug and abandon costs. For gas gathering systems and equipment, the Company records an ARO when the system is placed in service and it can reasonably estimate the fair value
of an obligation to perform site reclamation and other necessary work when it is required. The Company records the ARO liability on the unaudited condensed consolidated balance sheets and capitalizes
a portion of the cost in "
Oil and natural gas properties
" or "
Other operating property and equipment
"
during the period in
34
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
9. ASSET RETIREMENT OBLIGATIONS (Continued)
which
the obligation is incurred. The Company records the accretion of its ARO liabilities in "
Depletion, depreciation and accretion
" expense in the
unaudited condensed consolidated statements of operations. The additional capitalized costs are depreciated on a unit-of-production basis or straight-line basis.
The
Company recorded the following activity related to its ARO liability (in thousands, inclusive of the current portion):
|
|
|
|
|
Liability for asset retirement obligations as of December 31, 2016 (Sucessor)
|
|
$
|
32,375
|
|
Liabilities settled and divested
(1)
|
|
|
(8,160
|
)
|
Additions
|
|
|
7
|
|
Acquisitions
(1)
|
|
|
2,116
|
|
Accretion expense
|
|
|
467
|
|
|
|
|
|
|
Liability for asset retirement obligations as of March 31, 2017 (Successor)
|
|
$
|
26,805
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
-
(1)
-
See Note 4, "Acquisitions and Divestitures," for further information.
10. COMMITMENTS AND CONTINGENCIES
Commitments
The Company leases corporate office space in Houston, Texas; and Denver, Colorado as well as a number of other field office locations. Rent
expense was approximately $1.0 million and $2.2 million for the three months ended March 31, 2017 (Successor) and 2016 (Predecessor), respectively. As of March 31, 2017,
the amount of commitments under office and equipment lease agreements is consistent with the levels as disclosed in the Company's Annual Report on Form 10-K for the fiscal year ended
December 31, 2016, approximating $14.5 million in the aggregate, and containing various expiration dates through 2024.
In
addition, the Company has commitments for certain equipment under long-term operating lease agreements, namely drilling rigs, with various expiration dates through 2018. In the first
quarter of 2016 (Predecessor), the Company entered into an amendment to one of its drilling rig contracts with an original term ending date of August 31, 2016, whereby, as of April 5,
2016 (Predecessor), the Company early terminated the rig contract, incurred a termination fee of approximately $1.2 million and reduced its 2016 drilling commitments by extending part of the
contract term on another of its drilling rig contracts out further in 2018. In January 2015, the Company made the decision to early terminate a drilling rig contract in response to the decline in
crude oil prices, and the Company incurred an early
termination fee of $6.0 million, paid over the first half of 2015 (Predecessor). If certain requirements are not met by January 12, 2020, the Company may incur up to an additional
$3.0 million in connection with this drilling rig contract. Rig termination fees are expensed as incurred within
"Gathering and other"
on the
unaudited condensed consolidated statements of operations.
In
addition, the Company has two drilling rig commitments, for which the Company is incurring a stacking fee of $10,000 and $10,500 per day. The contract terms for these drilling rig
commitments extend through the second quarter of 2017 and 2018, respectively. Rig stacking fees are expensed as incurred within "
Gathering and other
" on
the unaudited condensed consolidated statements of
35
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
10. COMMITMENTS AND CONTINGENCIES (Continued)
operations.
Early termination of the Company's additional drilling rig commitments would result in termination penalties approximating $12.6 million, which would be in lieu of the remaining
$21.7 million of drilling rig commitments as of March 31, 2017 (Successor).
The
Company has entered into an agreement with a private operator for the right to purchase up to 15,040 net acres located in Ward and Winkler Counties, Texas (the Ward County Assets)
prospective for the Wolfcamp and Bone Spring formations. The Ward County Assets are divided into two tracts: the Southern Tract, comprising 6,720 net acres, and the Northern Tract, comprising 8,320
net acres, with separate options for each tract. Pursuant to the terms of the agreement, the Company paid $5.0 million and drilled a commitment well on the Southern Tract. The Company has until
June 15, 2017 to exercise the option on either the Southern Tract acreage or on all 15,040 net acres, in each case for $11,000 per acre. If the Company initially elects only to exercise its
option on the Southern Tract, the Company would need to pay $5.0 million on or before June 15, 2017 and drill a commitment well on the Northern Tract by September 1, 2017 to earn
an option to acquire the Northern Tract acreage for $11,000 per acre by December 31, 2017.
The
Company has entered into various long-term gathering, transportation and sales contracts with respect to production from the Bakken/Three Forks formations in North Dakota and the
Southern Delaware Basin in West Texas. As of March 31, 2017 (Successor), the Company had in place ten long-term crude oil contracts and eight long-term natural gas contracts in these areas.
Under the terms of these contracts, the Company has committed a substantial portion of its production from these areas for periods ranging from one to ten years from the date of first production. The
sales prices under these contracts are based on posted market rates. Historically, the Company has been able to meet its delivery commitments.
Contingencies
From time to time, the Company may be a plaintiff or defendant in a pending or threatened legal proceeding arising in the normal course of its
business. While the outcome and impact of currently pending legal proceedings cannot be determined, the Company's management and legal counsel believe that the resolution of these proceedings through
settlement or adverse judgment will not have a material effect on the Company's unaudited condensed consolidated operating results, financial position or cash flows.
11. STOCKHOLDERS' EQUITY
Preferred Stock and Non-Cash Preferred Stock Dividend
On January 24, 2017 (Successor) (the Commitment Date), the Company entered into a stock purchase agreement with certain accredited
investors to sell, in a private placement exempt from registration requirements of the Securities Act pursuant to Section 4(a)(2), approximately 5,518 shares of 8% Automatically Convertible
Preferred Stock, par value $0.0001 per share (the Preferred Stock), each share of which was convertible into 10,000 shares of common stock. Also on January 24, 2017, the Company received an
executed written consent in lieu of a stockholders' meeting authorizing and approving the conversion of the Preferred Stock into common stock. On February 27, 2017, the Company filed with the
Delaware Secretary of State a Certificate of Designation, Preferences, Rights and Limitations of the Preferred Stock (the Certificate of Designation), which created the series of preferred stock
issued by the Company on that same date. The Company issued the Preferred Stock at
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
11. STOCKHOLDERS' EQUITY (Continued)
$72,500
per share. Gross proceeds were approximately $400.1 million, or $7.25 per share of common stock. The Company incurred approximately $11.6 million in expenses associated with this
offering, including placement agent fees. On March 16, 2017, the Company mailed a definitive information statement to its common stockholders notifying them that a majority of its stockholders
had consented to the issuance of common stock, par value $0.0001 per share, upon the conversion of the Preferred Stock. The Preferred Stock automatically converted into 55.2 million shares of
common stock on April 6, 2017 in accordance with the terms of the Certificate of Designation. No cash dividends were paid on the Preferred Stock since, pursuant to the terms of the Certificate
of Designation of the Preferred Stock, conversion occurred prior to June 1, 2017.
The
Company agreed to file a registration statement to register the resale of shares of common stock issuable upon conversion of the preferred stock and to pay penalties in the
event such registration was not effective by June 27, 2017. The Company filed such registration statement on March 3, 2017 and it was declared effective by the SEC on April 7,
2017.
In
accordance with ASC Topic 470,
Debt
(ASC 470), the Company determined that the conversion feature in the Preferred Stock represented a
beneficial conversion feature. The fair value of the Company's common stock of $8.12 per share on the Commitment Date was greater than the conversion price of $7.25 per share of common stock,
representing a beneficial conversion feature of $0.87 per share of common stock, or approximately $48.0 million in aggregate. Under ASC 470, $48.0 million (the intrinsic value of the
beneficial conversion feature) of the proceeds received from the issuance of the Preferred Stock was allocated to
"Additional paid-in capital,"
creating
a discount on the Preferred Stock (the Discount). The Discount is required to be amortized on a non-cash basis over the approximate 65-month period between the issuance date and the required
redemption date of July 28, 2022, or fully amortized upon an accelerated date of redemption or conversion, and recorded as a preferred dividend. As a result, approximately $0.8 million
of the Discount was amortized and a non-cash preferred dividend was recorded in the three months ended March 31, 2017 (Successor) and due to the conversion date occurring on April 6,
2017, the remaining $47.2 million of the amortization of the Discount will be accelerated to the conversion date and will be fully amortized in the three months ended June 30, 2017. The
Discount amortization is reflected in
"Non-cash preferred dividend"
in the unaudited condensed consolidated statements of operations. The preferred
dividend was charged against additional paid-in capital since no retained earnings were available.
Common Stock
On September 9, 2016, upon emergence from chapter 11 bankruptcy, all existing shares of Predecessor common stock were cancelled
and the Successor Company issued approximately 90.0 million shares of common stock in total to the Predecessor Company's existing common stockholders, Third Lien Noteholders, Unsecured
Noteholders, and the Convertible Noteholder. Refer to Note 2, "
Reorganization
" for further details.
On
September 9, 2016, upon emergence from chapter 11 bankruptcy, the Successor Company filed an amended and restated certificate of incorporation with the Delaware
Secretary of State to provide for (i) the total number of shares of all classes of capital stock that the Successor Company has the authority to issue is 1,001,000,000 of which 1,000,000,000
shares are common stock, par value $0.0001 per share and 1,000,000 shares are preferred stock, par value $0.0001 per share, (ii) a classified board structure, (iii) the right of removal
of directors with or without cause by stockholders, and (iv) a
37
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
11. STOCKHOLDERS' EQUITY (Continued)
restriction
on the Successor Company from issuing any non-voting equity securities in violation of Section 1123(a)(6) of chapter 11 of title 11 of the United States Code. Additionally,
the Company's 5.75% Series A Convertible Perpetual Preferred Stock (the Series A Preferred), was cancelled pursuant to the Plan, and no shares of Series A Preferred are
outstanding.
Warrants
On September 9, 2016, upon the emergence from chapter 11 bankruptcy, all existing February 2012 warrants were cancelled and the
Successor Company issued 3.8 million new warrants to the Unsecured Noteholders and 0.9 million new warrants to the Convertible Noteholder. The warrants in aggregate can be exercised to
purchase 4.7 million shares of the Successor Company's common stock at an exercise price of $14.04 per share. The Company allocated approximately $16.7 million of the Enterprise Value to
the warrants which is reflected in "
Successor Additional paid-in capital
" on the unaudited consolidated balance sheets. The holders are entitled to
exercise the warrants in whole or in part at any time prior to expiration on September 9, 2020. See Note 2, "
Reorganization
" for further
details.
Incentive Plans
Immediately prior to emergence from chapter 11 bankruptcy, the Predecessor incentive plan was cancelled and all share-based compensation
awards granted thereunder were either vested or cancelled and the Predecessor Company's Board adopted the 2016 Long-Term Incentive Plan (the 2016 Incentive Plan). An aggregate of 10.0 million
shares of the Successor Company's common stock were available for grant pursuant to awards under the 2016 Incentive Plan in the form of nonqualified stock options, incentive stock options, restricted
stock awards, restricted stock units, stock appreciation rights, performance units, performance bonuses, stock awards and other incentive awards. As of March 31, 2017 (Successor) and
December 31, 2016 (Successor), a maximum of 1.8 million and 1.7 million shares of common stock, respectively, remained reserved for issuance under the 2016 Incentive Plan. On
April 6, 2017 (Successor), an amendment to the 2016 Incentive Plan to increase by 9.0 million shares the maximum number of shares of common stock that may be issued thereunder,
i.e., a maximum of 19.0 million shares, became effective, which was 20 calendar days following the date the Company mailed an information statement to all stockholders of record
notifying them of approval of the amendment by written consent.
The
Company accounts for share-based payment accruals under authoritative guidance on stock compensation. The guidance requires all share-based payments to employees and directors,
including grants of stock options and restricted stock, to be recognized in the financial statements based on their fair values. For awards granted under the 2016 Incentive Plan subsequent to emerging
from chapter 11 bankruptcy and in conjunction with the early adoption of ASU 2016-09, the Company has elected to not apply a forfeiture estimate and will recognize a credit in compensation
expense to the extent awards are forfeited.
For
the three months ended March 31, 2017 (Successor) and the three months ended March 31, 2016 (Predecessor) the Company recognized $8.3 million and
$2.1 million, respectively, of share-based compensation expense. Share-based compensation expense is recorded as a component of "
General and
administrative
" on the unaudited condensed consolidated statements of operations.
38
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
11. STOCKHOLDERS' EQUITY (Continued)
Stock Options
From time to time, the Company grants stock options under its incentive plan covering shares of common stock to employees of the Company. Stock
options, when exercised, are settled through the payment of the exercise price in exchange for new shares of stock underlying the option. These awards typically vest over a three year period at a rate
of one-third on the annual anniversary date of the grant and expire ten years from the grant date.
No
options were granted during the three months ended March 31, 2017 (Successor). At March 31, 2017 (Successor), the Company had $21.4 million of unrecognized
compensation expense related to non-vested stock options to be recognized over a weighted-average period of 1.5 years.
No
options were granted during the three months ended March 31, 2016 (Predecessor). At March 31, 2016 (Predecessor), the Company had $3.5 million of unrecognized
compensation expense related to non-vested stock options to be recognized over a weighted-average period of 1.5 years. Immediately prior to emergence from chapter 11 bankruptcy, all
outstanding stock options under the Predecessor Incentive Plan were cancelled. Refer to Note 2,
"Reorganization,"
for further details.
Restricted Stock
From time to time, the Company grants shares of restricted stock to employees and non-employee directors of the Company. Employee shares
typically vest over a three year period at a rate of one-third on the annual anniversary date of the grant, and the non-employee directors' shares vest six months from the date of grant. For certain
shares granted under the 2016 Incentive Plan, subsequent to emergence from chapter 11 bankruptcy, half vested immediately on the date of grant and the remaining half will vest on the first
anniversary of the date of grant.
No
restricted shares were granted during the three months ended March 31, 2017 (Successor). At March 31, 2017 (Successor), the Company had $7.4 million of
unrecognized compensation expense related to non-vested restricted stock awards to be recognized over a weighted-average period of 0.7 years.
No
restricted shares were granted during the three months ended March 31, 2016 (Predecessor). At March 31, 2016 (Predecessor), the Company had $6.6 million of
unrecognized compensation expense
related to non-vested restricted stock awards to be recognized over a weighted-average period of 1.5 years. Immediately prior to emergence from chapter 11 bankruptcy, all restricted
stock awards granted under the Predecessor Incentive Plan were vested. Refer to Note 2,
"Reorganization,"
for further details.
39
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HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
12. EARNINGS PER COMMON SHARE
On September 9, 2016, upon emergence from chapter 11 bankruptcy, the Company's Predecessor equity was cancelled and new equity was issued. Refer to Note 2,
"Reorganization,"
for further details.
The
following represents the calculation of earnings (loss) per share (in thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
Predecessor
|
|
|
|
Three Months
Ended
March 31, 2017
|
|
|
|
Three Months
Ended
March 31, 2016
|
|
|
|
|
|
|
|
|
|
Basic:
|
|
|
|
|
|
|
|
|
|
Net income (loss) available to common stockholders
|
|
$
|
188,551
|
|
|
|
$
|
(566,862
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average basic number of common shares outstanding
|
|
|
91,274
|
|
|
|
|
120,011
|
|
|
|
|
|
|
|
|
|
|
|
Basic net income (loss) per share of common stock
|
|
$
|
2.07
|
|
|
|
$
|
(4.72
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted:
|
|
|
|
|
|
|
|
|
|
Net income (loss) available to common stockholders
|
|
$
|
188,551
|
|
|
|
$
|
(566,862
|
)
|
|
|
|
|
|
|
|
|
|
|
Non-cash preferred dividend
|
|
|
801
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) available to common stockholders after assumed conversions
|
|
$
|
189,352
|
|
|
|
$
|
(566,862
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average basic number of common shares outstanding
|
|
|
91,274
|
|
|
|
|
120,011
|
|
Common stock equivalent shares representing shares issuable upon:
|
|
|
|
|
|
|
|
|
|
Exercise of stock options
|
|
|
Anti-dilutive
|
|
|
|
|
Anti-dilutive
|
|
Exercise of February 2012 Warrants
|
|
|
|
|
|
|
|
Anti-dilutive
|
|
Exercise of warrants
|
|
|
Anti-dilutive
|
|
|
|
|
|
|
Vesting of restricted shares
|
|
|
578
|
|
|
|
|
Anti-dilutive
|
|
Vesting of performance units
|
|
|
|
|
|
|
|
|
|
Conversion of preferred stock
|
|
|
20,232
|
|
|
|
|
|
|
Conversion of Convertible Note
|
|
|
|
|
|
|
|
Anti-dilutive
|
|
Conversion of Series A Preferred Stock
|
|
|
|
|
|
|
|
Anti-dilutive
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average diluted number of common shares outstanding
|
|
|
112,084
|
|
|
|
|
120,011
|
|
|
|
|
|
|
|
|
|
|
|
Diluted net income (loss) per share of common stock
|
|
$
|
1.69
|
|
|
|
$
|
(4.72
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common
stock equivalents, including stock options, restricted shares, warrants, and preferred stock totaling 10.0 million shares for the three months ended March 31, 2017
(Successor) were not included in the computation of diluted earnings per share of common stock because the effect would have been anti-dilutive.
Common
stock equivalents, including stock options, warrants, restricted shares, convertible debt and preferred stock totaling 45.9 million shares for the three months ended
March 31, 2016 (Predecessor), respectively, were not included in the computation of diluted earnings per share of common stock because the effect would have been anti-dilutive due to the net
loss.
40
Table of Contents
HALCÓN RESOURCES CORPORATION
NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)
13. ADDITIONAL FINANCIAL STATEMENT INFORMATION
Certain balance sheet amounts are comprised of the following (in thousands):
|
|
|
|
|
|
|
|
|
|
Successor
|
|
|
|
March 31, 2017
|
|
December 31, 2016
|
|
Accounts receivable:
|
|
|
|
|
|
|
|
Oil, natural gas and natural gas liquids revenues
|
|
$
|
84,535
|
|
$
|
86,433
|
|
Joint interest accounts
|
|
|
26,692
|
|
|
39,828
|
|
Accrued settlements on derivative contracts
|
|
|
1,265
|
|
|
18,599
|
|
Affiliated partnership
|
|
|
739
|
|
|
268
|
|
Other
|
|
|
9,679
|
|
|
2,634
|
|
|
|
|
|
|
|
|
|
|
|
$
|
122,910
|
|
$
|
147,762
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Prepaids and other:
|
|
|
|
|
|
|
|
Prepaids
|
|
$
|
6,058
|
|
$
|
6,704
|
|
Other
|
|
|
54
|
|
|
236
|
|
|
|
|
|
|
|
|
|
|
|
$
|
6,112
|
|
$
|
6,940
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable and accrued liabilities:
|
|
|
|
|
|
|
|
Trade payables
|
|
$
|
23,383
|
|
$
|
24,364
|
|
Accrued oil and natural gas capital costs
|
|
|
26,735
|
|
|
32,967
|
|
Revenues and royalties payable
|
|
|
70,631
|
|
|
79,147
|
|
Accrued interest expense
|
|
|
8,910
|
|
|
31,146
|
|
Accrued employee compensation
|
|
|
2,770
|
|
|
3,428
|
|
Accrued lease operating expenses
|
|
|
12,537
|
|
|
14,077
|
|
Drilling advances from partners
|
|
|
2,084
|
|
|
422
|
|
Income taxes payable
|
|
|
12,250
|
|
|
250
|
|
Affiliated partnership
|
|
|
1,239
|
|
|
323
|
|
Other
|
|
|
55
|
|
|
60
|
|
|
|
|
|
|
|
|
|
|
|
$
|
160,594
|
|
$
|
186,184
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
41
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