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EXCEL - IDEA: XBRL DOCUMENT - MAGNUM HUNTER RESOURCES CORP | Financial_Report.xls |
EX-3.2 - EX-3.2 - MAGNUM HUNTER RESOURCES CORP | h83458exv3w2.htm |
EX-12.1 - EX-12.1 - MAGNUM HUNTER RESOURCES CORP | h83458exv12w1.htm |
EX-32.1 - EX-32.1 - MAGNUM HUNTER RESOURCES CORP | h83458exv32w1.htm |
EX-31.2 - EX-31.2 - MAGNUM HUNTER RESOURCES CORP | h83458exv31w2.htm |
EX-31.1 - EX-31.1 - MAGNUM HUNTER RESOURCES CORP | h83458exv31w1.htm |
Table of Contents
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
þ | QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended June 30, 2011
-OR- |
o | TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from to
Commission file number 001-32997
MAGNUM HUNTER RESOURCES CORPORATION
(Name of registrant as specified in its charter)
Delaware | 86-0879278 | |
(State or other jurisdiction of | (IRS Employer | |
incorporation or organization) | Identification No.) |
777 Post Oak Boulevard, Suite 650, Houston, Texas 77056
(Address of principal executive offices)
(Address of principal executive offices)
(832) 369-6986
(Issuers telephone number)
(Issuers telephone number)
Indicate by check mark whether the registrant (1) filed all reports required to be filed by
Section 13 or 15(d) of the Exchange Act during the preceding twelve months, and (2) has been
subject to such filing requirements for the past 90 days.
Yes þ No o
Indicate by check mark whether the registrant has submitted electronically and posted on its
corporate Web site, if any, every Interactive Data File required to be submitted and posted
pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months
(or for such shorter period that the registrant was required to submit and post such files).
Yes þ No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated
filer, a non-accelerated filer or a smaller reporting company (as defined in Rule 12b-2 of the
Act):
Large accelerated filer o | Accelerated filer þ | Non-accelerated filer o | Smaller reporting company o | |||
(Do not check if a smaller reporting company) |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of
the Exchange Act). Yes o No þ
As of August 5, 2011 there were 126,357,586 shares of the registrants common stock ($0.01 par
value) outstanding.
MAGNUM HUNTER RESOURCES CORPORATION
QUARTERLY REPORT ON FORM 10-Q
FOR THE PERIOD ENDED JUNE 30, 2011
FOR THE PERIOD ENDED JUNE 30, 2011
TABLE OF CONTENTS
Table of Contents
MAGNUM HUNTER RESOURCES CORPORATION
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except shares and per-share data)
June 30, | December 31, | |||||||
2011 | 2010 | |||||||
ASSETS |
||||||||
CURRENT ASSETS: |
||||||||
Cash and cash equivalents |
$ | 4,750 | $ | 554 | ||||
Restricted cash |
4,825 | | ||||||
Accounts receivable |
33,173 | 11,705 | ||||||
Prepaids and other current assets |
5,986 | 867 | ||||||
Total current assets |
48,734 | 13,126 | ||||||
PROPERTY AND EQUIPMENT (Net of Accumulated Depletion and Depreciation): |
||||||||
Oil and natural gas properties, successful efforts accounting |
849,367 | 189,912 | ||||||
Gas gathering and other equipment |
91,799 | 42,689 | ||||||
Total property and equipment, net |
941,166 | 232,601 | ||||||
OTHER ASSETS: |
||||||||
Deferred financing costs, net of amortization of $133 and $1,237 respectively |
2,712 | 2,678 | ||||||
Derivatives and other long-term assets |
1,534 | 562 | ||||||
Total assets |
$ | 994,146 | $ | 248,967 | ||||
LIABILITIES AND SHAREHOLDERS EQUITY |
||||||||
CURRENT LIABILITIES: |
||||||||
Current portion of notes payable |
$ | 2,086 | $ | 7,132 | ||||
Accounts payable |
68,071 | 33,319 | ||||||
Accrued liabilities |
11,274 | 435 | ||||||
Revenue payable |
9,306 | 2,630 | ||||||
Derivatives and other current liabilities |
1,405 | 719 | ||||||
Total current liabilities |
92,142 | 44,235 | ||||||
OTHER LIABILITIES: |
||||||||
Notes payable, less current portion |
145,791 | 26,019 | ||||||
Asset retirement obligation |
14,599 | 4,455 | ||||||
Deferred tax liability |
97,199 | | ||||||
Derviatives and other long term liabilities |
3,515 | 700 | ||||||
Total liabilities |
353,246 | 75,409 | ||||||
COMMITMENTS AND CONTINGENCIES (Note 13) |
||||||||
REDEEMABLE PREFERRED STOCK: |
||||||||
Series C Cumulative Perpetual Preferred Stock, cumulative dividend rate 10.25% per annum,
4,000,000 authorized, 4,000,000 and 2,809,456 issued & outstanding as of June 30, 2011 and
December 31, 2010, respectively, with liquidation preference of $25.00 per share |
100,000 | 70,236 | ||||||
SHAREHOLDERS EQUITY: |
||||||||
Preferred Stock, 10,000,000 shares authorized |
| | ||||||
Series D Cumulative Perpetual Preferred Stock, cumulative dividend rate 8.0% per annum,
5,750,000 authorized, 1,298,095 and none issued & outstanding as of June 30, 2011 and
December 31, 2010, respectively, with liquidation preference of $50.00 per share |
64,905 | | ||||||
Common stock, $0.01 par value, 250,000,000 shares authorized, 126,813,150 and 74,863,135 shares
issued and 126,346,229 and 74,863,135 outstanding as of June 30, 2011 and December 31, 2010, respectively |
1,263 | 749 | ||||||
Exchangeable common stock, par value $0.01 per share, 3,895,346 and none issued & outstanding as of June 30, 2011 and December 31, 2010, respectively |
39 | | ||||||
Additional paid in capital |
554,954 | 152,439 | ||||||
Accumulated deficit |
(77,197 | ) | (49,402 | ) | ||||
Accumulated other comprehensive income |
(3,214 | ) | | |||||
Treasury stock at cost, 761,652 shares |
(1,310 | ) | (1,310 | ) | ||||
Unearned common stock in KSOP at cost, 153,300 shares |
(604 | ) | (604 | ) | ||||
Total Magnum Hunter Resources Corporation shareholders equity |
538,836 | 101,872 | ||||||
Non-controlling interest |
2,064 | 1,450 | ||||||
Total shareholders equity |
540,900 | 103,322 | ||||||
Total liabilities and shareholders equity |
$ | 994,146 | $ | 248,967 | ||||
The accompanying notes are an integral part of these unaudited consolidated financial statements
1
Table of Contents
MAGNUM HUNTER RESOURCES CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except shares and per-share data)
Three Months Ended | Six Months Ended | |||||||||||||||
June 30, | June 30, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
REVENUE: |
||||||||||||||||
Oil and gas sales |
$ | 26,020 | $ | 6,941 | 39,981 | $ | 13,068 | |||||||||
Field operations and other |
7,417 | 1,460 | 8,777 | 1,988 | ||||||||||||
Total revenue |
33,437 | 8,401 | 48,758 | 15,056 | ||||||||||||
EXPENSES: |
||||||||||||||||
Lease operating expenses |
7,393 | 2,941 | 10,390 | 5,228 | ||||||||||||
Severance taxes and marketing |
1,782 | 721 | 2,777 | 1,230 | ||||||||||||
Exploration |
423 | 360 | 738 | 457 | ||||||||||||
Field operations |
3,298 | 1,446 | 4,454 | 1,717 | ||||||||||||
Depreciation, depletion and accretion |
10,814 | 2,883 | 16,344 | 4,098 | ||||||||||||
General and administrative |
23,715 | 6,501 | 30,571 | 13,269 | ||||||||||||
Total expenses |
47,425 | 14,852 | 65,274 | 25,999 | ||||||||||||
OPERATING LOSS |
(13,988 | ) | (6,451 | ) | (16,516 | ) | (10,943 | ) | ||||||||
OTHER INCOME AND (EXPENSE): |
||||||||||||||||
Interest income |
1 | 2 | 4 | 4 | ||||||||||||
Interest expense |
(3,926 | ) | (1,044 | ) | (4,716 | ) | (1,694 | ) | ||||||||
Gain (loss) on derivative contracts |
2,668 | 1,277 | (674 | ) | 2,409 | |||||||||||
Other income and (expense) |
92 | | 92 | | ||||||||||||
Loss from continuing operations before income
taxes and
non-controlling interest |
(15,153 | ) | (6,216 | ) | (21,810 | ) | (10,224 | ) | ||||||||
Income tax benefit |
197 | | 197 | | ||||||||||||
Net (income) loss attributable to non-controlling interest |
(84 | ) | 3 | (117 | ) | (65 | ) | |||||||||
Net loss attributable to Magnum Hunter Resources
Corporation from continuing operations |
(15,040 | ) | (6,213 | ) | (21,730 | ) | (10,289 | ) | ||||||||
Income from discontinued operations |
| 665 | | 955 | ||||||||||||
Net loss |
(15,040 | ) | (5,548 | ) | (21,730 | ) | (9,334 | ) | ||||||||
Dividend on Preferred Stock |
(3,457 | ) | (446 | ) | (6,065 | ) | (708 | ) | ||||||||
Net loss attributable to common shareholders |
$ | (18,497 | ) | $ | (5,994 | ) | $ | (27,795 | ) | $ | (10,042 | ) | ||||
Weighted average number of common shares
outstanding
Basic and diluted |
112,619,793 | 62,153,376 | 94,233,091 | 58,968,651 | ||||||||||||
Net loss from continuing operations |
$ | (0.16 | ) | $ | (0.11 | ) | $ | (0.29 | ) | $ | (0.19 | ) | ||||
Net income from discontinued operations |
$ | | $ | 0.01 | $ | | $ | 0.02 | ||||||||
Net loss per common share |
$ | (0.16 | ) | $ | (0.10 | ) | $ | (0.29 | ) | $ | (0.17 | ) | ||||
The accompanying notes are an integral part of these unaudited consolidated financial statements
2
Table of Contents
MAGNUM HUNTER RESOURCES CORPORATION
UNAUDITED CONSOLIDATED STATEMENT OF OTHER COMPREHENSIVE INCOME
(In thousands, except shares and per-share data)
For the Three Months Ended June 30, | For the Six Months Ended June 30, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Net loss |
$ | (15,040 | ) | $ | (5,548 | ) | $ | (21,730 | ) | $ | (9,334 | ) | ||||
Foreign currency translation |
(3,222 | ) | | (3,222 | ) | | ||||||||||
Unrealized gain (loss) on available for sale
investments |
8 | | 8 | | ||||||||||||
Total comprehensive loss |
$ | (18,254 | ) | $ | (5,548 | ) | $ | (24,944 | ) | $ | (9,334 | ) | ||||
The accompanying notes are an integral part of these unaudited consolidated financial statements
3
Table of Contents
MAGNUM HUNTER RESOURCES CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENT OF SHAREHOLDERS EQUITY
(In thousands)
(In thousands)
Number | Number of Shares | Number of | Additional | |||||||||||||||||||||||||||||||||||||||||||||||||
of Shares | of Exchangeable | Shares of Series D | Common | Exchangeable | Series D | Paid in | Accumulated | Accumulated Other | Treasury | Unearned Common | Noncontrolling | Total | ||||||||||||||||||||||||||||||||||||||||
of Common | Common Stock | Preferred Stock | Stock | Common Stock | Stock | Capital | Deficit | Comprehensive Income | Stock | Shares in KSOP | Interest | Equity | ||||||||||||||||||||||||||||||||||||||||
BALANCE, January 1, 2011 |
74,863 | | | $ | 749 | $ | | $ | | $ | 152,439 | $ | (49,402 | ) | $ | | $ | (1,310 | ) | $ | (604 | ) | $ | 1,450 | $ | 103,322 | ||||||||||||||||||||||||||
Restricted stock issued to employees and directors |
120 | | | 1 | | | 404 | | | | | | 405 | |||||||||||||||||||||||||||||||||||||||
Stock compensation |
| | | | | | 11,705 | | | | | | 11,705 | |||||||||||||||||||||||||||||||||||||||
Issued shares of Series C Preferred Stock for cash |
| | | | | | (689 | ) | | | | | | (689 | ) | |||||||||||||||||||||||||||||||||||||
Issued shares of Common Stock for cash |
1,714 | | | 17 | | | 13,875 | | | | | | 13,892 | |||||||||||||||||||||||||||||||||||||||
Issued shares of Series D Preferred Stock for cash |
| | 1,298 | | | 64,905 | (5,448 | ) | | | | | | 59,457 | ||||||||||||||||||||||||||||||||||||||
Issued shares of Common Stock upon warrant exercise |
802 | | | 8 | | | 2,390 | | | | | | 2,398 | |||||||||||||||||||||||||||||||||||||||
Issued shares of common stock upon stock option exercise |
2,403 | | | 24 | | | 3,412 | | | | | | 3,436 | |||||||||||||||||||||||||||||||||||||||
Dividends on Series C Cumulative Perpetual Preferred |
| | | | | | | (5,124 | ) | | | | | (5,124 | ) | |||||||||||||||||||||||||||||||||||||
Dividends on Series D Preferred Stock |
| | | | | | | (941 | ) | | | | | (941 | ) | |||||||||||||||||||||||||||||||||||||
Issued shares of common stock for acquisition of assets |
946 | | | 9 | | | 7,533 | | | | | | 7,542 | |||||||||||||||||||||||||||||||||||||||
Issued shares of common stock for acquisition of NGAS Resources |
6,635 | | | 66 | | | 52,951 | | | | | | 53,017 | |||||||||||||||||||||||||||||||||||||||
Issued shares of common stock to employees for change in control
payments for NGAS Resources |
351 | | | 4 | | | 2,798 | | | | | | 2,802 | |||||||||||||||||||||||||||||||||||||||
Issued 138,388 warrants in replacement of NGAS Resources warrants |
| | | | | | 190 | | | | | | 190 | |||||||||||||||||||||||||||||||||||||||
Noncontrolling interest acquired in NGAS acquisition |
| | | | | | | | | | | 497 | 497 | |||||||||||||||||||||||||||||||||||||||
Issued shares of common stock for acquisition of NuLoch Resources |
38,132 | | | 381 | | | 281,794 | | | | | | 282,175 | |||||||||||||||||||||||||||||||||||||||
Issued exchangeable shares for acquisition of NuLoch Resources |
| 4,276 | | | 43 | | 31,600 | | | | | | 31,643 | |||||||||||||||||||||||||||||||||||||||
Issued shared of
common stock upon exchange of MHR Exchangeco exchangeable shares |
381 | (381 | ) | | 4 | (4 | ) | | | | | | | | | |||||||||||||||||||||||||||||||||||||
Net loss |
| | | | | | | (21,730 | ) | | | | 117 | (21,613 | ) | |||||||||||||||||||||||||||||||||||||
Other comprehensive income: |
| |||||||||||||||||||||||||||||||||||||||||||||||||||
Foreign currency translation |
| | | | | | | | 8 | | | | 8 | |||||||||||||||||||||||||||||||||||||||
Unrealized gain on available for sale securities |
| | | | | | | | (3,222 | ) | | | | (3,222 | ) | |||||||||||||||||||||||||||||||||||||
BALANCE, June 30, 2011 |
126,347 | 3,895 | 1,298 | $ | 1,263 | 39 | 64,905 | $ | 554,954 | $ | (77,197 | ) | (3,214 | ) | $ | (1,310 | ) | $ | (604 | ) | $ | 2,064 | $ | 540,900 | ||||||||||||||||||||||||||||
The accompanying notes are an integral part of these unaudited consolidated financial statements
4
Table of Contents
MAGNUM HUNTER RESOURCES CORPORATION
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(In thousands)
Six Months Ended | ||||||||
June 30, | ||||||||
2011 | 2010 | |||||||
Cash flows from operating activities |
||||||||
Net loss |
$ | (21,730 | ) | $ | (9,334 | ) | ||
Adjustments to reconcile net loss to net cash
provided by operating activities: |
||||||||
Noncontrolling Interest |
117 | 65 | ||||||
Depletion, depreciation, and accretion |
16,344 | 4,849 | ||||||
Amortization
of deferred financing costs included in interest expense |
2,812 | 541 | ||||||
Gain on sale of assets |
(1,559 | ) | (29 | ) | ||||
Share-based compensation |
12,014 | 4,123 | ||||||
Unrealized loss on derivative contracts |
166 | 679 | ||||||
Deferred taxes |
(197 | ) | | |||||
Changes in operating assets and liabilities: |
||||||||
Accounts receivable and accrued revenue |
(7,205 | ) | (1,408 | ) | ||||
Inventory |
(3,302 | ) | 53 | |||||
Prepaid expenses and other current assets |
(418 | ) | (403 | ) | ||||
Accounts payable |
12,923 | 751 | ||||||
Revenue payable |
5,129 | (63 | ) | |||||
Accrued Liabilities |
(5,136 | ) | 3,465 | |||||
Net cash provided by operating activities |
9,958 | 3,289 | ||||||
Cash flows from investing activities |
||||||||
Capital expenditures and advances |
(131,840 | ) | (17,215 | ) | ||||
Cash paid in acquisitions, net of cash received of
$2.5 million |
(78,523 | ) | (59,500 | ) | ||||
Change in restricted cash and deposits |
(5,450 | ) | (967 | ) | ||||
Proceeds from sales of assets |
1,824 | 30 | ||||||
Net cash used in investing activities |
(213,989 | ) | (77,652 | ) | ||||
Cash flows from financing activities |
||||||||
Net proceeds from sale of common stock and warrants |
13,892 | 24,423 | ||||||
Net proceeds from sale of preferred shares |
88,531 | 9,176 | ||||||
Proceeds from exercise of warrants and options |
5,835 | 12,884 | ||||||
Preferred stock dividend paid |
(6,065 | ) | (734 | ) | ||||
Cash paid upon conversion of Series B Preferred
Stock |
| (11,250 | ) | |||||
Proceeds from borrowings on debt |
228,044 | 70,433 | ||||||
Principal repayment of debt |
(119,477 | ) | (25,576 | ) | ||||
Payment of deferred financing costs |
(2,846 | ) | (2,630 | ) | ||||
Change in other long-term liabilities |
310 | | ||||||
Net cash provided by financing activities |
208,224 | 76,726 | ||||||
Effect of exchange rate changes on cash |
3 | | ||||||
Net increase (decrease) in cash and cash equivalents |
4,196 | 2,363 | ||||||
Cash and cash equivalents, beginning of period |
554 | 2,282 | ||||||
Cash and cash equivalents, end of period |
$ | 4,750 | $ | 4,645 | ||||
Supplemental disclosure of cash flow information |
||||||||
Cash paid for interest |
$ | 1,619 | $ | 1,230 | ||||
Non-cash transactions |
||||||||
Series B Preferred stock issued for acquisition of
Triad |
$ | | $ | 14,982 | ||||
Debt assumed in acquisition |
$ | 71,895 | $ | 3,412 | ||||
Common stock issued for payment of services |
$ | | $ | 165 | ||||
Common stock issued in conversion of Series B stock |
$ | | $ | 3,732 | ||||
Accrued capital expenditures |
$ | 47,597 | $ | | ||||
Common stock issued for acquisition |
$ | 345,537 | $ | | ||||
Exchangeable common stock issued for acquisition of
NuLoch Resources |
$ | 31,642 | $ | | ||||
The accompanying notes are an integral part of these unaudited consolidated financial statements
5
Table of Contents
NOTE 1BASIS OF PRESENTATION
The accompanying unaudited interim financial statements of Magnum Hunter Resources Corporation (the
Company or Magnum Hunter) have been prepared in accordance with accounting principles generally
accepted in the United States of America and the rules of the Securities and Exchange Commission,
and should be read in conjunction with the audited financial statements and notes thereto contained
in the Companys annual report on Form 10-K, as amended, for the year ended December 31, 2010. In
the opinion of management, all adjustments, consisting of normal recurring adjustments, necessary
for a fair presentation of the financial position and the results of operations for the interim
periods presented have been reflected herein. The results of operations for interim periods are
not necessarily indicative of the results to be expected for the full year. Notes to the
consolidated financial statements which would substantially duplicate the disclosure contained in
the audited consolidated financial statements as reported in the 2010 annual report on Form 10-K,
as amended, have been omitted.
Income or Loss per Share
Basic income or loss per common share is net income or loss available to common stockholders
divided by the weighted average of common shares outstanding during the period. Diluted income or
loss per common share is calculated in the same manner, but also considers the impact to net income
and common shares outstanding for the potential dilution from in-the-money common stock options and
warrants, and convertible debentures and preferred stock.
We have issued potentially dilutive instruments in the form of restricted common stock granted and
not yet issued, common stock warrants, and common stock options. The total number of potentially
dilutive securities at June 30, 2011 was 15,846,191. There were 11,793,934 potentially dilutive
securities outstanding at June 30, 2010. We did not include the potentially dilutive securities in
our calculation of diluted loss per share during either period because to include them would be
anti-dilutive due to our net loss during those periods.
The following table summarizes the types of potentially dilutive securities outstanding as of June
30, 2011 and 2010 (in thousands):
June 30, | ||||||||
2011 | 2010 | |||||||
Warrants |
284 | 2,218 | ||||||
Restricted Shares granted, not yet issued |
25 | 105 | ||||||
Common Stock Options |
15,537 | 9,470 |
NOTE 2 SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation and Presentation
The consolidated financial statements include the accounts of Magnum Hunter and our wholly-owned
subsidiaries, Eagle Ford Hunter, Inc. (f/k/a Sharon Hunter Resources, Inc.) (Sharon), Triad
Hunter, LLC, Alpha Hunter Drilling, LLC, Hunter Disposal, LLC, Eureka Hunter Pipeline, LLC, Eureka
Hunter Pipeline Partners, LLC, Hunter Real Estate, LLC, NGAS Hunter, LLC (f/k/a MHR Acquisition
Company I, LLC), Magnum Hunter Production, Inc., Magnum Hunter Resources GP, LLC, Magnum Hunter
Resources LP, MHR Callco Corporation, MHR Exchangeco Corporation, Williston Hunter Canada, Inc.,
Williston Hunter, Inc., Williston Hunter N D, LLC (f/k/a MHR Acquisition II, LLC), NGAS Gathering,
LLC, Sentra Corporation, Energy Hunter Securities, Inc (f/k/a NGAS Securities, Inc) and MHR
Acquisition Company III, LLC. We also have consolidated our 87.5% controlling interest in PRC
Williston, LLC (PRC) with noncontrolling interests recorded for the outside interest in PRC. All
significant intercompany balances and transactions have been eliminated.
Our financial statements are prepared in accordance with accounting principles generally
accepted in the United States of America. The preparation of our financial statements requires
management to make estimates and assumptions that affect the reported amounts of assets,
liabilities, revenues and expenses. These estimates are based on information that is currently
available to us and on various other assumptions that we believe to be reasonable under the
circumstances. Actual results could differ from those estimates under different assumptions and
conditions. Significant estimates are required for proved oil and gas reserves which may have a
material impact on the carrying value of oil and gas properties.
Critical accounting policies are defined as those significant accounting policies that are
most critical to an understanding of a companys financial condition and results of operations. We
consider an accounting estimate or judgment to be critical if (i) it requires assumptions to be
made that were uncertain at the time the estimate was made, and (ii) changes in the estimate or
different estimates that could have been selected, could have a material impact on our results of
operations or financial condition.
6
Table of Contents
Reclassification of Prior-Year Balances
Certain prior-year balances in the consolidated financial statements have been reclassified to
correspond with current-year classifications. As a result of the sale of our Cinco Terry oil and
gas properties on October 29, 2010, we reclassified the gain on sale and all prior operating income
and related interest expense for this property as discontinued operations.
NOTE 3 NEW ACCOUNTING PRONOUNCEMENTS
In May 2011, the FASB issued ASU 2011-04, Amendments to Achieve Common Fair Value Measurement and
Disclosure Requirements in U.S. GAAP and IFRSs. The amended guidance changes several aspects of
the fair value measurement guidance in ASC 820, Fair Value Measurement, further clarifying how to
measure and disclose fair value. This guidance amends the application of the highest and best use
concept to be used only in the measurement of fair value of nonfinancial assets, clarifies that the
measurement of the fair value of equity-classified financial instruments should be performed from
the perspective of a market participant who holds the instrument as an asset, clarifies that an
entity that manages a group of financial assets and liabilities on the basis of its net risk
exposure can measure those financial instruments on the basis of its net exposure to those risks,
and clarifies when premiums and discounts should be taken into account when measuring fair value.
The fair value disclosure requirements also were amended. The amendment is effective for the
Company at the beginning of January 2012, with early adoption prohibited. The adoption of this
amendment is not expected to materially affect the Companys financial statements.
In June 2011, the FASB issued ASU 2011-05, Presentation of Comprehensive Income which amended
requirements for the presentation of other comprehensive income (OCI), requiring presentation of
comprehensive income in either a single, continuous statement of comprehensive income or on
separate but consecutive statements, the statement of operations and the statement of OCI. The
amendment is effective for the Company at the beginning of fiscal year 2013 with early adoption
permitted. The adoption of this guidance will not impact the Companys financial position, results
of operations or cash flows and will only impact the presentation of OCI on the financial
statements.
NOTE 4 FAIR VALUE OF FINANCIAL INSTRUMENTS
Accounting standards define 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. The standards also establish a framework for measuring fair value and a valuation hierarchy
based upon the transparency of inputs used in the valuation of an asset or liability.
Classification within the hierarchy is based upon the lowest level of input that is significant to
the fair value measurement. The valuation hierarchy contains three levels:
| Level 1 Quoted prices (unadjusted) for identical assets or liabilities in active markets | ||
| Level 2 Quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; and model-derived valuations whose inputs or significant value drivers are observable | ||
| Level 3 Significant inputs to the valuation model are unobservable |
We used the following fair value measurements for certain of our assets and liabilities during the
three months ended June 30, 2011 and 2010:
Level 1 Classification:
Available for Sale Securities
At June 30, 2011, the Company held common stock of a company publicly traded on the TSX Venture
Exchange with quoted prices in active markets. Accordingly, the fair market value measurements of
these securities have been classified as Level 1.
Level 2 Classification:
Derivative Instruments
At June 30, 2011 and December 31, 2010, the Company had commodity derivative financial instruments
in place. The Company does not apply hedge accounting; therefore, the changes in fair value
subsequent to the initial measurement are recorded as income or expense. The estimated fair value
amounts of the Companys derivative instruments have been determined at discrete points in time
based on relevant market information which resulted in the Company classifying such derivatives as
Level 2. Although the
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Companys derivative instruments are valued using public indexes, the instruments themselves are
traded with unrelated counterparties and are not openly traded on an exchange. See Note 7
Financial Instruments and Derivatives, for additional information.
As of June 30, 2011 and December 31, 2010, the Companys derivative contracts were with major
financial institutions, all of which are senior lenders to the Company, and have investment grade
credit ratings which are believed to have a minimal credit risk. As such, the Company is exposed to
credit risk to the extent of nonperformance by the counterparties in the derivative contracts
discussed above; however, the Company does not anticipate such nonperformance.
The following tables present recurring financial assets and liabilities which are carried at fair
value as of June 30, 2011 and December 31, 2010:
Fair Value Measurements on a Recurring Basis | ||||||||||||
June 30, 2011 | ||||||||||||
(In thousands) | ||||||||||||
Level 1 | Level 2 | Level 3 | ||||||||||
Available for sale securities |
$ | 258 | | $ | | |||||||
Commodity derivatives |
$ | | $ | 94 | $ | | ||||||
Total assets at fair value |
$ | 258 | $ | 94 | $ | | ||||||
Commodity derivatives |
$ | | $ | 1,038 | $ | | ||||||
Total liabilities at fair value |
$ | | $ | 1,038 | $ | | ||||||
Fair Value Measurements on a Recurring Basis | ||||||||||||
December 31, 2010 | ||||||||||||
(In thousands) | ||||||||||||
Level 1 | Level 2 | Level 3 | ||||||||||
Commodity derivatives |
$ | | $ | | $ | | ||||||
Total assets as fair value |
$ | | $ | | $ | | ||||||
Commodity derivatives |
$ | | $ | 778 | $ | | ||||||
Total liabilities at fair value |
$ | | $ | 778 | $ | | ||||||
NOTE 5 ACQUISITIONS
Triad
On February 12, 2010, the Company completed the acquisition of the assets of privately-held Triad
Energy Corporation and certain of its affiliated entities
(collectively, Triad) from bankruptcy, resulting in
approximately five months of operating activity for these assets for the six months ended June 30,
2010. See our 2010 annual report on form 10-K, as amended, for details.
PostRock
On December 24, 2010, Magnum Hunter Resources Corporation and Triad Hunter, LLC entered into a
Purchase and Sale Agreement with Post Rock, pursuant to which Triad
Hunter, LLC agreed to acquire
certain oil and gas properties and leasehold mineral interests and related assets located in Wetzel
and Lewis Counties, West Virginia. The Purchase Agreement provided for the acquisition to be
completed in three phases for total consideration of $49.3 million consisting of 50% common stock
and 50% cash for the first two phases, and 100% cash for the third phase. Both of the two initial
phases were effective as of November 1, 2010.
The first phase of the acquisition closed on December 30, 2010. See our 2010 annual report on form
10-K, as amended, for details.
On January 14, 2011, we closed the second phase of the PostRock acquisition, the Lewis County
assets, for total consideration of approximately $13.3 million which consisted of 946,314 shares of
the Companys restricted common stock and a cash payment of approximately $5.8 million.
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On June 16, 2011, we closed the third phase of the PostRock acquisition comprising assets located
in Wetzel and Lewis Counties for a total purchase price of $4.9 million in cash before considering
applicable adjustments.
Wetzel County, West Virginia Asset Acquisition
On April 7, 2011, the Company purchased oil and gas properties and related assets located in Wetzel
County, West Virginia. The assets purchased included approximately 4,451 gross acres (2,225 net
acres) of oil and gas leases and mineral interests and existing wells with proven reserves.
We acquired the assets for a total purchase price of $20.0 million, payable in cash and customary
purchase price adjustments. Subject to the indemnification obligations set forth in the Purchase
Agreement, we assumed certain customary liabilities in connection with the acquisition.
NGAS
On April 13, 2011, the Company completed the acquisition of all of the outstanding common shares of
NGAS Resources, Inc, (NGAS) for total consideration of approximately $124.5 million consisting of
$15.3 million in cash, $53.1 million in debt assumed, 6,986,104 shares of our common stock valued
at approximately $55.8 million based on the closing stock price of $7.99 on April 13, 2011, and
$1.2 million in warrant liability, of which $1.0 million was paid out upon exercise of the cash
option, and included in the cash consideration, and 138,388 warrants are outstanding that are exercisable for common stock of the Company.
Including the repayment at closing of debt assumed, total cash payments in connection with the
acquisition were $62.3 million. The Company has liquidated NGAS into a wholly-owned subsidiary of
the Company, NGAS Hunter, LLC, and changed the name of its subsidiary NGAS Production Co. to Magnum
Hunter Production, Inc, and another subsidiary, NGAS Securities, Inc. to Energy Hunter Securities,
Inc.
The fair value of the net assets acquired, based on our preliminary assessment, approximated the
$124.5 million in total consideration paid.
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The following table summarizes the purchase price and the preliminary estimate of the fair values
of the net assets acquired of NGAS during the three months ended June 30, 2011 (in thousands)
except share information:
Fair value of total purchase price: |
||||
6,635,478 shares of common stock issued on April 13, 2011 at $7.99 per share |
$ | 53,017 | ||
Senior credit facility paid off at closing |
33,282 | |||
NGAS 6% Convertible notes paid off in cash at closing |
13,683 | |||
Contract payment in cash |
12,929 | |||
Other long-term debt assumed |
6,160 | |||
350,626 shares of common stock issued for change in control payments at $7.99 per share |
2,802 | |||
Tax on change of control payments paid in cash |
1,363 | |||
Common stock warrants settled in cash |
1,044 | |||
Common stock warrants issued in conversion of NGAS warrants |
190 | |||
Common stock options granted upon conversion of NGAS options |
| |||
Total |
$ | 124,470 | ||
Amounts recognized for assets acquired and liabilities assumed: |
||||
Working capital |
$ | (8,902 | ) | |
Oil and gas properties |
132,995 | |||
Equipment and other fixed assets |
9,055 | |||
Asset retirement obligation |
(8,678 | ) | ||
Total |
$ | 124,470 | ||
Working capital acquired: |
||||
Cash |
$ | 1,908 | ||
Accounts receivable |
3,662 | |||
Prepaid Expenses |
416 | |||
Inventory |
278 | |||
Accounts payable |
(7,483 | ) | ||
Revenue payable |
(1,547 | ) | ||
Payroll tax payable |
(206 | ) | ||
Advances |
(3,751 | ) | ||
Deferred compensation |
(379 | ) | ||
Accrued Liabilities |
(1,800 | ) | ||
Total working capital acquired |
$ | (8,902 | ) | |
NuLoch
On May 3, 2011, the Company completed the acquisition of all of the outstanding common shares of
NuLoch Resources, Inc., (NuLoch) for total consideration
of approximately $430.5 million
consisting of 38,131,848 shares of our common stock and 4,275,998 exchangeable shares of MHR
Exchangeco Corporation, an indirect wholly-owned Canadian subsidiary of the Company, which are
exchangeable for shares of the Company common stock, with a combined value of approximately $313.8
million based on the closing stock price of $7.40 on May 3, 2011, $18.8 million in debt assumed,
and deferred tax liability of approximately $97.9 million. The company has changed the name of
NuLoch to Williston Hunter Canada, Inc. and its subsidiary NuLoch America Corporation to Williston
Hunter, Inc., collectively, (Williston).
The fair value of the net assets acquired, based upon our preliminary estimate, approximated the
$430.5 million in consideration paid.
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The following table summarizes the purchase price and the preliminary estimate of the fair values
of the net assets of NuLoch acquired during the three months ended
June 30, 2011 (in thousands except per share data):
Fair value of total purchase price: |
||||
38,131,846 shares of common stock issued on May 3, 2011 at $7.40 per share |
$ | 282,176 | ||
4,275,998 exchangeable shares at $7.40 per share |
31,642 | |||
Debt assumed |
18,770 | |||
Net deferred tax liability |
97,912 | |||
Total |
$ | 430,500 | ||
Amounts recognized for assets acquired and liabilities assumed: |
||||
Working capital |
$ | (20,711 | ) | |
Oil and gas properties |
447,540 | |||
Equipment and other fixed assets |
5,167 | |||
Asset retirement obligation |
(1,496 | ) | ||
Total |
$ | 430,500 | ||
Working capital acquired: |
||||
Cash |
$ | 640 | ||
Accounts receivable |
5,951 | |||
Prepaid expenses |
359 | |||
Accounts payable |
(27,661 | ) | ||
Total working capital acquired |
$ | (20,711 | ) | |
The consolidated statement of operations includes Triads revenue of $5.7 million and $9.6 million,
respectively for the three and six months ended June 30, 2010 and Triads operating loss of
$211,000 and operating income of $1.4 million for the three and six months ended June 30, 2010. The
consolidated statement of operations includes PostRocks revenue of $1.3 million for the six months
ended June 30, 2011 and PostRocks operating income of $797,000 for the six months ended June 30,
2011. The consolidated statement of operations includes NGASs revenue of $6.4 million for the six
months ended June 30, 2011 and NGASs operating loss of $999,000 for the six months ended
June 30, 2011. The consolidated statement of operations includes NuLochs revenue of $2.1 million
for the six months ended June 30, 2011 and NuLochs operating loss of $452,000 for the six months
ended June 30, 2011.
The following summary, prepared on a pro forma basis, presents the results of operations for
the three and six months ended June 30, 2011 and 2010, as if the acquisition of Triad, the PostRock
assets, NGAS, and NuLoch, along with transactions necessary to finance the acquisitions, had
occurred as of the beginning of the respective periods. This unaudited pro forma information
includes the effects of adjustments for interest expense, depreciation and depletion expense, and
dividend expense. The pro forma results are not necessarily indicative of what actually would have
occurred if the acquisition had been completed as of the beginning of the period presented, nor are
they necessarily indicative of future consolidated results.
Three Months Ended | Three Months Ended | Six Months Ended | Six Months Ended | |||||||||||||
June 30, | June 30, | June 30, | June 30, | |||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
(in thousands, except per-share data) | ||||||||||||||||
Total operating revenue |
$ | 35,149 | $ | 26,370 | $ | 65,195 | $ | 49,686 | ||||||||
Total operating costs and expenses |
60,820 | 38,839 | 95,113 | 72,475 | ||||||||||||
Operating loss |
(25,671 | ) | (12,469 | ) | (29,918 | ) | (22,789 | ) | ||||||||
Interest expense and other |
(1,123 | ) | 181 | (5,843 | ) | (1,233 | ) | |||||||||
Net loss
attributable to Magnum Hunter Resources Corporation |
(26,794 | ) | (12,288 | ) | (35,761 | ) | (24,022 | ) | ||||||||
Dividends on preferred stock |
(3,457 | ) | (446 | ) | (6,065 | ) | (905 | ) | ||||||||
Net loss attributable to common stock holders |
$ | (30,251 | ) | $ | (12,734 | ) | $ | (41,826 | ) | $ | (24,927 | ) | ||||
Loss per common share, basic and diluted |
$ | (0.17 | ) | $ | (0.08 | ) | $ | (0.33 | ) | $ | (0.22 | ) | ||||
NOTE 6 DISCONTINUED OPERATIONS
On October 29, 2010, we entered into a definitive purchase and sale agreement for the sale of our
10.0% non-operated working interest in the Cinco Terry oil and gas property located in Crockett
County, Texas, which closed on October 29, 2010. See our 2010
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annual report on form 10-K, as
amended, for details. The operating results of the Cinco Terry property for the three and six
months ended June 30, 2010 have been reclassified as discontinued operations in the consolidated
statements of operations as detailed in the table below:
Three months ended | Six months ended | |||||||
June 30, 2010 | June 30, 2010 | |||||||
(in thousands) | (in thousands) | |||||||
Oil and Gas Sales and other revenues |
$ | 1,402 | $ | 2,570 | ||||
Operating expenses |
(624 | ) | (1,389 | ) | ||||
Other income (expense) |
(113 | ) | (226 | ) | ||||
Income from discontinued operations |
$ | 665 | $ | 955 | ||||
NOTE 7 FINANCIAL INSTRUMENTS AND DERIVATIVES
We enter into certain commodity derivative instruments which are effective in mitigating commodity
price risk associated with a portion of our future monthly natural gas and crude oil production and
related cash flows. Our oil and gas operating revenues and cash flows are directly impacted by changes in
commodity product prices, which are volatile and cannot be accurately predicted. Our objective for
holding these commodity derivatives is to protect the operating revenues and cash flows related to
a portion of our future crude oil and natural gas sales from the risk of significant declines in commodity prices,
which helps insure our ability to fund our capital budget. We have not designated any of our
commodity derivatives as hedges under the applicable accounting standards.
As of June 30, 2011, we had the following derivative instruments in place:
Natural Gas | Period | MMBTU/day | Price per MMBTU | |||||||||
Collars |
Jul 2011 - Dec 2011 | 2,143 | $ | 5.37 - $7.43 | ||||||||
Jan 2012 - Dec 2012 | 1,910 | $ | 5.00 - $8.65 | |||||||||
Swaps |
Jul 2011 - Dec 2011 | 113 | $ | 5.98 | ||||||||
Jan 2012 - Dec 2012 | 100 | $ | 6.15 |
Crude Oil | Period | Bbls/day | Price per Bbl | |||||||||
Collars |
Jul 2011 - Dec 2011 | 997 | $ | 71.44 - $100.74 | ||||||||
Jan 2012 - Dec 2012 | 312 | $ | 85.21 - $108.69 | |||||||||
Swaps |
Jul 2011 - Dec 2011 | 43 | $ | 85.09 | ||||||||
Floors sold (put) |
Jul 2011 - Dec 2011 | 147 | $ | 60.00 | ||||||||
Jan 2012 - Dec 2012 | 50 | $ | 55.00 | |||||||||
Floors purchased (put) |
July 2011 - Sep 2011 | 935 | $ | 84.14 | ||||||||
Oct 2011 - Dec 2011 | 1260 | $ | 84.37 | |||||||||
Jan 2012 - Dec 2012 | 153 | $ | 80.00 |
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The following table summarizes the fair value of our derivative contracts as of the dates
indicated:
Gross Derivative Assets | Gross Derivative Liabilities | |||||||||||||||||||
(in thousands) | (in thousands) | |||||||||||||||||||
Derivatives not designated as hedging | Balance Sheet | December 31, | December 31, | |||||||||||||||||
instruments | Classification | June 30, 2011 | 2010 | June 30, 2011 | 2010 | |||||||||||||||
Commodity |
||||||||||||||||||||
Derivative assets - long term | $ | 201 | $ | | $ | (107 | ) | $ | | |||||||||||
Derivative liability | 2,012 | 1,743 | (2,847 | ) | (2,461 | ) | ||||||||||||||
Derivative liability - long term | 483 | 500 | (687 | ) | (559 | ) | ||||||||||||||
Total Commodity |
$ | 2,696 | $ | 2,243 | $ | (3,641 | ) | $ | (3,020 | ) | ||||||||||
The following table summarizes the net gain (loss) on derivative contracts for the three and six months ended June 30, 2011:
Six Months Ended | Three Months Ended | |||||||
June 30, 2011 | June 30, 2011 | |||||||
(in thousands) | (in thousands) | |||||||
Realized (loss) |
(508 | ) | (517 | ) | ||||
Unrealized gain (loss) |
(166 | ) | 3,184 | |||||
Net gain (loss) |
(674 | ) | 2,667 |
Six Months Ended | Three Months Ended | |||||||
June 30, 2010 | June 30, 2010 | |||||||
(in thousands) | (in thousands) | |||||||
Realized gain |
3,088 | 601 | ||||||
Unrealized gain (loss) |
(679 | ) | 676 | |||||
Net gain |
2,409 | 1,277 |
NOTE 8 ASSET RETIREMENT OBLIGATIONS
The Company records a liability for the fair value of an assets retirement obligation in the
period in which it is incurred and the corresponding cost is capitalized by increasing the carrying
amount of the related long-lived asset. The liability is accreted to its then present value each
period, and the capitalized cost is depreciated over the estimated useful life of the related
asset. We have included estimated future costs of abandonment and dismantlement in our successful
efforts amortization base and amortize these costs as a component of our depreciation, depletion,
and accretion expense in the accompanying consolidated financial statements.
The following table summarizes the Companys asset retirement obligation transactions during the
six month period ended June 30, 2011:
(in thousands) | ||||
Asset retirement obligation at beginning of period |
$ | 4,455 | ||
Assumed in NGAS acquisition |
8,678 | |||
Assumed in NuLoch acquisition |
1,496 | |||
Liabilities incurred |
10 | |||
Liabilities settled |
| |||
Accretion expense |
354 | |||
Revisions in estimated liabilities |
(25 | ) | ||
Asset retirement obligation at end of period |
14,968 | |||
Less: current portion |
(369 | ) | ||
Asset retirement obligation at end of period |
$ | 14,599 | ||
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NOTE 9 NOTES PAYABLE
Notes payable at June 30, 2011 consisted of the following:
June 30, 2011 | ||||
(in thousands) | ||||
Various
equipment notes payable with maturity dates April 2012 - August 2021, interest rates of 0.00% - 6.34% |
$ | 8,877 | ||
Senior
revolving credit facility Interest rate of 4.5%, due April 13, 2016 |
139,000 | |||
$ | 147,877 | |||
Less: current portion |
(2,086 | ) | ||
Total Long-Term Debt |
$ | 145,791 | ||
The following table presents the approximate annual maturities of debt:
(in thousands) | ||||
2011 |
$ | 787 | ||
2012 |
2,312 | |||
2013 |
861 | |||
2014 |
868 | |||
Thereafter |
143,049 | |||
Total |
$ | 147,877 | ||
Notes Payable
On April 13, 2011 the Company assumed various notes payable for equipment and a building upon the
closing of the acquisition of NGAS. The promissory notes have maturity dates ranging from September 2012 to
April 2021 and bear interest rates of 0.00% to 5.875%. As of June 30, 2011, there was $6.1 million
outstanding on these promissory notes.
Second Amended and Restated Credit Facility
On
April 13, 2011, the Company entered into a Second Amended and
Restated Credit Agreement, (the Senior Credit Facility or
revolving credit facility). The
Senior Credit Facility amended and restated, in its entirety, that certain Amended and
Restated Credit Agreement dated February 12, 2010.
The Senior
Credit Facility provides for an asset-based, senior secured revolving credit
facility maturing April 13, 2016, with a new borrowing base of $145 million. The initial borrowing
base was set at $120 million upon the completion of the Companys acquisition of NGAS. The
borrowing base was subsequently increased to $145 million upon the completion of the Companys
acquisition of NuLoch, which closed on May 3, 2011. The Senior
Credit Facility is governed by a
semi-annual borrowing base redetermination derived from the Companys proved crude oil and natural
gas reserves, and based on such redeterminations, the borrowing base may be decreased or may be
increased up to a maximum commitment level of $250 million. The borrowing base is subject to such
periodic redeterminations commencing November 1, 2011.
The facility may be used for loans and, subject to a $10,000,000 sublimit, letters of credit. The
facility provides for a commitment fee of 0.5% based on the unused portion of the borrowing base
under the facility.
Borrowings under the facility will, at the Companys election, bear interest at either: (i) an
alternate base rate (ABR) equal to the higher of (A) the Prime Rate, (B) the Federal Funds
Effective Rate plus 0.5% per annum and (C) the LIBO Rate for a one month interest period on such
day plus 1.0%; or (ii) the adjusted LIBO Rate, which is the rate stated on Reuters BBA Libor Rates
LIBOR01 market for one, two, three, six or twelve months, as adjusted for statutory reserve
requirements for eurocurrency liabilities, plus, in each of the cases described in clauses (i) and
(ii) above, an applicable margin ranging from 1.25% to 2.25% for ABR loans and from 2.25% to 3.25%
for adjusted LIBO Rate loans.
If an event of default occurs and is continuing, the lenders may increase the interest rate then in
effect by an additional 2% per annum
plus the rate applicable to ABR loans.
The Senior
Credit Facility contains negative covenants that, among other things, restrict the ability of the
Company to, with certain exceptions: (1) incur indebtedness; (2) grant liens; (3) make certain
payments; (4) change the nature of its business; (5) dispose of all or substantially all of its
assets or enter into mergers, consolidations or similar transactions; (6) make investments, loans
or advances; (7)
14
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pay cash dividends, unless certain conditions are met, and subject to a basket
of $20,000,000 per year available for payment of dividends on preferred stock; and (8) enter into
transactions with affiliates. The Senior Credit Facility also requires the
Company to satisfy certain financial covenants, including maintaining (1) a ratio of consolidated
current assets to consolidated current liabilities of not less than 1.0 to 1.0; (2) a ratio of
EBITDAX to interest of not less than 2.5 to 1.0; and (3) a ratio of total debt to EBITDAX of not
more than (a) 4.5 to 1.0 for the fiscal quarters ending June 30, 2011 and September 30, 2011 and
(b) 4.0 to 1.0 for each fiscal quarter ending thereafter. The Company is also required to enter
into certain commodity hedging agreements pursuant to the terms of
the facility.
The
obligations of the Company under the facility may be accelerated upon the occurrence of an
event of default. Events of default include customary events for a financing agreement of this
type, including, without limitation, payment defaults, defaults in the performance of affirmative
or negative covenants, the inaccuracy of representations or warranties, bankruptcy or related
defaults, defaults relating to judgments and the occurrence of a change in control.
Subject to
certain permitted liens, the Companys obligations under the
facility have been secured
by the grant of a first priority lien on no less than 80% of the value of the proved oil and gas
properties of the Company and its subsidiaries, which liens include those properties acquired
through the acquisition of NGAS, and additional liens were granted on the properties acquired upon
the closing of the NuLoch acquisition.
In
connection with the facility, the Company and certain of its subsidiaries also entered into
certain customary ancillary agreements and arrangements, which, among other things, provide that
the indebtedness, obligations and liabilities of the Company arising under or in connection with
the facility are unconditionally guaranteed by such unrestricted subsidiaries.
At
June 30, 2011, the Company had loans outstanding under the
facility of $139 million.
NOTE 10 SHARE BASED COMPENSATION
We recognized share-based compensation expense of $10.7 million and $12.0 million for the three and
six months ended June 30, 2011, and we recognized $2.8 million and $4.1 million for the three and
six months ended June 30, 2010.
A summary of common stock option and stock appreciation rights activity for the six months ended
June 30, 2011 is presented below:
Weighted- | ||||||||
Average | ||||||||
Shares | Exercise Price | |||||||
Outstanding at beginning of period |
12,779,282 | $ | 2.65 | |||||
Granted |
5,417,792 | $ | 7.84 | |||||
Exercised |
(2,402,500 | ) | $ | 1.43 | ||||
Cancelled |
(257,825 | ) | $ | 2.73 | ||||
Outstanding at end of period |
15,536,749 | $ | 4.65 | |||||
Exercisable at end of period |
7,494,992 | $ | 2.51 | |||||
A summary of the Companys non-vested common stock options as of June 30, 2011 is presented
below.
Non-vested Common Stock Options | Shares | |||
Non-vested at beginning of period |
5,215,532 | |||
Granted |
5,417,792 | |||
Vested |
(2,335,242 | ) | ||
Cancelled |
(256,325 | ) | ||
Non-vested at end of period |
8,041,757 | |||
Total unrecognized compensation cost related to the non-vested common stock options was $21.8
million and $2.5 million as of June 30, 2011 and 2010, respectively. The cost at June 30, 2011, is
expected to be recognized over a weighted-average period of 1.41 years. At June 30, 2011, the
aggregate intrinsic value for common stock options was $38.7 million; and the weighted average
remaining contract life was 6.05 years.
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The assumptions used in the fair value method calculation for the six months ended June 30, 2011
are disclosed in the following table:
Six Months Ended | ||||
June 30, 2011 (1) | ||||
Weighted average value per common stock option granted during the period (2) |
$ | 4.37 | ||
Assumptions (3) : |
||||
Weighted average stock price volatility |
64.72 | % | ||
Weighted average risk free rate of return |
2.08 | % | ||
Weighted average expected term |
6.47 years |
(1) | Our estimated future forfeiture rate is zero. | |
(2) | Calculated using the Black-Scholes fair value based method for service and performance based grants and the Lattice Model for market based grants. | |
(3) | We have not paid dividends on our common stock. |
In addition, the Company has issued restricted stock to certain employees and directors. A
summary of the Companys non-vested restricted shares as of June 30, 2011 is presented below:
Weighted Average | ||||||||
Non-vested Shares | Shares | Price Per Share | ||||||
Non-vested at December 31, 2010 |
300,074 | $ | 4.43 | |||||
Granted |
13,624 | 7.49 | ||||||
Vested |
(93,624 | ) | 2.40 | |||||
Forfeited |
| | ||||||
Non-vested at June 30, 2011 |
220,074 | $ | 5.48 | |||||
Total unrecognized compensation cost related to the above non-vested, restricted shares
amounted to $973,000 and $87,000 as of June 30, 2011 and 2010, respectively. The cost at June 30,
2011, is expected to be recognized over a weighted-average period of 2.39 years.
NOTE 11 SHAREHOLDERS EQUITY
On April 29, 2011, at the annual shareholders meeting, our shareholders approved an amendment to
the Companys Certificate of Incorporation that increased the Companys authorized number of shares
of Common Stock to 250,000,000 and approved an amendment to the Companys amended and restated 2006
Stock Incentive Plan to increase the aggregate number of shares of common stock to be issued under
the plan to 20,000,000.
Common Stock
During the six months ended June 30, 2011, the Company issued 120,100 shares of the Companys
common stock in connection with share-based compensation which had fully vested to senior
management and officers of the Company. This includes 12,792 shares which had previously vested as
of December 31, 2010.
During the six months ended June 30, 2011, the Company issued 1,713,598 shares of common stock in
open market transactions at an average price of $8.27 per share pursuant to an At the Market
sales agreement (ATM) we have with our sales agent for total net proceeds of approximately $13.9
million. Sales of shares of our common stock by our sales agent have been made in privately
negotiated transactions or in any method permitted by law deemed to be an At The Market offering
as defined in Rule 415 promulgated under the Securities Act of 1933, as amended, at negotiated
prices, at prices prevailing at the time of sale or at prices related to such prevailing market
prices, including sales made directly on the NYSE or sales made through a market maker other than
on an exchange. Our sales agent has made all sales using commercially reasonable efforts
consistent with its normal sales and trading practices on mutually agreed upon terms between our
sales agent and us.
On January 14, 2011, the Company issued 946,314 shares of common stock valued at approximately $7.5
million based on a closing stock price of $7.97 as consideration on the closing of the second phase
of the PostRock acquisition.
On April 13, 2011, the Company issued 6,635,478 shares of common stock valued at approximately $53
million based on a closing stock price of $7.99 as consideration on the closing of the acquisition
of NGAS. In connection with the acquisition, the Company issued 350,626 shares of common stock
valued at approximately $2.8 million to NGAS employees as change in control payments.
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On May 3, 2011, the Company issued 38,131,846 shares of common stock valued at approximately $282.2
million based on a closing stock price of $7.40 as consideration on the closing of the acquisition
of NuLoch.
During the six months ended June 30, 2011, the Company issued 801,980 shares of the Companys
common stock upon the exercise of warrants for total proceeds of approximately $2.4 million.
During the six months ended June 30, 2011, the Company issued 2,402,500 common shares upon the
exercise of fully vested common stock options for proceeds of approximately $3.4 million.
During the six months ended June 30, 2011, the Company issued 380,652 common shares upon the
exchange of exchangeable shares of MHR Exchangeco Corporation, an indirect wholly-owned Canadian
subsidiary of the Company.
Exchangeable Common Stock
On May 3, 2011, in connection with the acquisition of NuLoch, the Company issued 4,275,998
exchangeable shares of MHR Exchangeco Corporation, which are exchangeable for shares of the Company
at a one for one ratio. The shares of MHR Exchangeco were valued at approximately $31.6 million.
Each exchangeable share is exchangeable for one share of our common stock at any time after
issuance at the option of the holder and will be redeemable at the option of the Company, through
Exchangeco, after one year or upon the earlier of certain specified events. During the six months
ended June 30, 2011, 380,652 of the exchangeable shares have been exchanged for common shares of
the Company. As of June 30, 2011, 3,895,346 exchangeable shares were outstanding.
Series C Cumulative Perpetual Preferred Stock
During the six months ended June 30, 2011, the Company sold 1,190,544 shares of our 10.25% Series C
Cumulative Perpetual Preferred Stock, under our ATM sales agreement for net proceeds of $29.1
million. The sales during the six months ended June 30, 2011 have fully subscribed the authorized
4,000,000 shares of Series C Cumulative Perpetual Preferred Stock. During the six months ended
June 30, 2011, the Company paid dividends of $5.1 million to holders of our Series C Cumulative
Perpetual Preferred Stock. The Series C Preferred Stock cannot be converted into common stock of
the Company but may be redeemed by the Company, at the Companys option, on or after December 14,
2011. The Series C Preferred Stock is recorded as temporary equity because a forced redemption by the holder(s),
upon certain circumstances as a result of a change in control, is outside the Companys control.
Series D Cumulative Preferred Stock
During the six months ended June 30, 2011, the Company sold 1,298,095 shares of our 8.0% Series D
Cumulative Perpetual Preferred Stock with a liquidation preference of $50.00 per share, of which
400,000 were sold in an underwritten offering and 898,095 were sold under the ATM sales agreement,
for net proceeds of $59.5 million. The Series D Preferred Stock cannot be converted into common
stock of the Company but may be redeemed by the Company, at the Companys option, on or after March
14, 2014 for par value or $50.00 per share or in certain circumstances prior to such date as a
result of a change in control. The Company pays cumulative dividends on the Series D Preferred
Stock at a fixed rate of 8.0% per annum of the $50.00 per share liquidation preference. During the
six months ended June 30, 2011, the Company paid dividends of $941,000 to holders of our Series D
Cumulative Preferred Stock.
Common Stock Warrants
During the six months ended June 30, 2011, 771,812 of our $3.00 common stock warrants and 30,168 of
our $2.50 common stock warrants were exercised for total combined proceeds of approximately $2.4
million and 15,000 of our $3.00 common stock warrants expired.
On April 13, 2011, at the time of the NGAS acquisition, NGAS had 4,609,038 warrants outstanding
which were converted, based on the exchange ratio of 0.0846, to 389,924 warrants exercisable for
Magnum common stock. The warrants had a cash out option, which remained available to the holder
for 30 days from the date of the acquisition, based on fair market value of the warrants at April
13, 2011. The Company paid cash of $1.0 million upon exercise of the cash out option on the
warrants exercisable for 251,536 shares of the Companys common stock. At June 30, 2011, common
stock warrants exercisable for 138,388 shares of the Companys common stock, valued at
approximately $190,000 were outstanding. The warrants consisted of 97,780 warrants with an exercise price of $15.13 and $40,608 warrants with an exercise price of $19.04.
17
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NOTE 12 RELATED PARTY TRANSACTIONS
We rented an airplane for business use at various times from Pilatus Hunter, LLC, an entity 100%
owned by Mr. Evans, our Chairman and CEO. Airplane rental expenses totaled $105,000 and $228,000,
for the three and six months ended June 30, 2011, respectively and $64,000 and $188,000 for the
three and six months period ended June 30 2010, respectively.
We obtained accounting services and use of office space from GreenHunter Energy, Inc., an entity
for which Mr. Evans is an officer and major shareholder and for which Mr. Ormand is also a director.
Professional services expenses totaled $28,000 and $46,000, for the three and six months ended June
30, 2011, respectively, and $30,000 and $60,000 for the three and six months ended June 30, 2010,
respectively.
We entered into a one year lease for a corporate apartment from an executive of the Company for
monthly rent of $4,500 for use by several executives of the Company employee. During the six months ended June 30, 2011
the Company paid rent of $9,000 pertaining to the lease.
As of June 30, 2011, our net accounts payable to Pilatus Hunter, LLC was $16,000 and our net
accounts payable to GreenHunter Energy, Inc. was $10,000.
NOTE 13 COMMITMENTS AND CONTINGENCIES
On June 24, 2011, the Company entered into a
three year drilling contract for our Eagleford operating activities from October 31, 2011,
through October 31, 2014. Our remaining maximum liability under the drilling contract, which would
apply if we terminated the contract before the end of its term, is approximately $19.5 million as
of June 30, 2011.
On June 29, 2011, the Company entered into a twelve month drilling contract for our Eagleford operating activities. Our remaining maximum
liability under the drilling contract, which would apply if we terminated the contract before the
end of its term, is approximately $3.0 million as of June 30, 2011.
NOTE 14 CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS
The Company and certain of its wholly-owned subsidiaries including Eagle Ford Hunter, Triad Hunter,
Hunter Disposal, NGAS Hunter, Williston Hunter ND LLC (collectively Guarantor Subsidiaries),
may fully and unconditionally guarantee the obligations of the Company under any debt securities
that it may issue pursuant to a universal shelf registration statement, on a joint and several
basis, on Form S-3. Condensed consolidating financial information for Magnum Hunter Resources
Corporation and subsidiaries as of June 30, 2011 and December 31, 2010, and for the three and six
months ended June 30, 2011 and 2010, was as follows:
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Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Balance Sheets
(in thousands)
(in thousands)
As of June 30, 2011 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
ASSETS |
||||||||||||||||||||
Current assets |
$ | 12,825 | $ | 27,882 | $ | 8,027 | $ | | $ | 48,734 | ||||||||||
Intercompany accounts receivable |
569,706 | | | (569,706 | ) | | ||||||||||||||
Property and equipment (using successful efforts accounting) |
12,150 | 379,738 | 549,278 | | 941,166 | |||||||||||||||
Investment in subsidiaries |
199,191 | | 124,281 | (323,472 | ) | | ||||||||||||||
Other assets |
2,856 | 770 | 620 | | 4,246 | |||||||||||||||
Total Assets |
$ | 796,728 | $ | 408,390 | $ | 682,206 | $ | (893,178 | ) | $ | 994,146 | |||||||||
LIABILITIES AND STOCKHOLDERS EQUITY |
||||||||||||||||||||
Current liabilities |
$ | 14,320 | $ | 49,213 | $ | 28,609 | $ | | $ | 92,142 | ||||||||||
Intercompany accounts payable |
| 128,167 | 435,941 | (564,108 | ) | | ||||||||||||||
Long-term liabilities |
140,092 | 18,798 | 102,214 | | 261,104 | |||||||||||||||
Redeemable preferred stock |
100,000 | | | | 100,000 | |||||||||||||||
Shareholders equity |
542,316 | 212,212 | 115,442 | (329,070 | ) | 540,900 | ||||||||||||||
Total Liabilities and Stockholders Equity |
$ | 796,728 | $ | 408,390 | $ | 682,206 | $ | (893,178 | ) | $ | 994,146 | |||||||||
As of December 31, 2010 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
ASSETS |
||||||||||||||||||||
Current assets |
$ | 4,809 | $ | 6,436 | $ | 1,881 | $ | | $ | 13,126 | ||||||||||
Intercompany accounts receivable |
131,691 | | | (131,691 | ) | | ||||||||||||||
Property and equipment (using successful efforts accounting) |
12,049 | 149,647 | 70,905 | | 232,601 | |||||||||||||||
Investment in subsidiaries |
80,877 | | | (80,877 | ) | | ||||||||||||||
Other assets |
2,723 | 512 | 5 | | 3,240 | |||||||||||||||
Total Assets |
$ | 232,149 | $ | 156,595 | $ | 72,791 | $ | (212,568 | ) | $ | 248,967 | |||||||||
LIABILITIES AND STOCKHOLDERS EQUITY |
||||||||||||||||||||
Current liabilities |
$ | 24,852 | $ | 13,480 | $ | 5,903 | $ | | $ | 44,235 | ||||||||||
Intercompany accounts payable |
| 56,326 | 75,365 | (131,691 | ) | | ||||||||||||||
Long-term liabilities |
24,386 | 3,023 | 3,765 | | 31,174 | |||||||||||||||
Redeemable preferred stock |
70,236 | | | | 70,236 | |||||||||||||||
Shareholders equity |
112,675 | 83,766 | (12,242 | ) | (80,877 | ) | 103,322 | |||||||||||||
Total Liabilities and Stockholders Equity |
$ | 232,149 | $ | 156,595 | $ | 72,791 | $ | (212,568 | ) | $ | 248,967 | |||||||||
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Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Operations
(in thousands)
(in thousands)
For the Three Months Ended June 30, 2011 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
Revenues |
$ | 319 | $ | 25,651 | $ | 8,020 | $ | (553 | ) | $ | 33,437 | |||||||||
Expenses |
22,412 | 20,036 | 6,693 | (551 | ) | 48,590 | ||||||||||||||
Loss from continuing operations before equity in net income of
subsidiary |
(22,093 | ) | 5,615 | 1,327 | (2 | ) | (15,153 | ) | ||||||||||||
Equity in net income of subsidiary |
7,055 | | | (7,055 | ) | | ||||||||||||||
Net income (loss) |
(15,038 | ) | 5,615 | 1,327 | (7,057 | ) | (15,153 | ) | ||||||||||||
Deferred tax benefit |
| | 197 | | 197 | |||||||||||||||
Less: Net income attributable to non-conrolling interest |
| | (84 | ) | | (84 | ) | |||||||||||||
Net income
(loss) from continuing operations attributable to Magnum Hunter Resources Corporation |
(15,038 | ) | 5,615 | 1,440 | (7,057 | ) | (15,040 | ) | ||||||||||||
Dividends on preferred stock |
(3,457 | ) | | | | (3,457 | ) | |||||||||||||
Net loss attributable to common shareholders |
(18,495 | ) | 5,615 | 1,440 | (7,057 | ) | (18,497 | ) | ||||||||||||
For the Three Months Ended June 30, 2010 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
Revenues |
$ | 362 | $ | 5,607 | $ | 3,208 | $ | (776 | ) | $ | 8,401 | |||||||||
Expenses |
6,276 | 5,861 | 3,256 | (776 | ) | 14,617 | ||||||||||||||
Loss from continuing operations before equity in net losses of subsidiary |
(5,914 | ) | (254 | ) | (48 | ) | | (6,216 | ) | |||||||||||
Equity in net loss of subsidiary |
(299 | ) | | | 299 | | ||||||||||||||
Net loss |
(6,213 | ) | (254 | ) | (48 | ) | 299 | (6,216 | ) | |||||||||||
Less: Net loss attributable to non-conrolling interest |
| | 3 | | 3 | |||||||||||||||
Net loss
from continuing operations attributable to Magnum Hunter Resources Corporation |
(6,213 | ) | (254 | ) | (45 | ) | 299 | (6,213 | ) | |||||||||||
Income from discontinued operations |
665 | | | | 665 | |||||||||||||||
Net loss |
(5,548 | ) | (254 | ) | (45 | ) | 299 | (5,548 | ) | |||||||||||
Dividends on preferred stock |
(446 | ) | | | | (446 | ) | |||||||||||||
Net loss attributable to common shareholders |
$ | (5,994 | ) | $ | (254 | ) | $ | (45 | ) | $ | 299 | $ | (5,994 | ) | ||||||
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For the Six Months Ended June 30, 2011 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
Revenues |
$ | 615 | $ | 38,551 | $ | 11,096 | $ | (1,504 | ) | $ | 48,758 | |||||||||
Expenses |
32,882 | 28,923 | 10,266 | (1,503 | ) | 70,568 | ||||||||||||||
Loss from continuing operations before equity in net income of
subsidiary |
(32,267 | ) | 9,628 | 830 | (1 | ) | (21,810 | ) | ||||||||||||
Equity in net income of subsidiary |
10,539 | | | (10,539 | ) | | ||||||||||||||
Net income (loss) |
(21,728 | ) | 9,628 | 830 | (10,540 | ) | (21,810 | ) | ||||||||||||
Deferred tax benefit |
| | 197 | | 197 | |||||||||||||||
Less: Net income attributable to non-conrolling interest |
| | (117 | ) | | (117 | ) | |||||||||||||
Net income
(loss) from continuing operations attributable to Magnum Hunter Resources Corporation |
(21,728 | ) | 9,628 | 910 | (10,540 | ) | (21,730 | ) | ||||||||||||
Dividends on preferred stock |
(6,065 | ) | | | | (6,065 | ) | |||||||||||||
Net loss attributable to common shareholders |
(27,793 | ) | 9,628 | 910 | (10,540 | ) | (27,795 | ) | ||||||||||||
For the Six Months Ended June 30, 2010 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
Revenues |
$ | 724 | $ | 9,784 | $ | 5,778 | $ | (1,230 | ) | $ | 15,056 | |||||||||
Expenses |
12,814 | 8,134 | 5,562 | (1,230 | ) | 25,280 | ||||||||||||||
Loss from continuing operations before equity in net losses of subsidiary |
(12,090 | ) | 1,650 | 216 | | (10,224 | ) | |||||||||||||
Equity in net loss of subsidiary |
1,801 | | | (1,801 | ) | | ||||||||||||||
Net loss |
(10,289 | ) | 1,650 | 216 | (1,801 | ) | (10,224 | ) | ||||||||||||
Less: Net loss attributable to non-conrolling interest |
| | (65 | ) | | (65 | ) | |||||||||||||
Net loss
from continuing operations attributable to Magnum Hunter Resources Corporation |
(10,289 | ) | 1,650 | 151 | (1,801 | ) | (10,289 | ) | ||||||||||||
Income from discontinued operations |
955 | | | | 955 | |||||||||||||||
Net loss |
(9,334 | ) | 1,650 | 151 | (1,801 | ) | (9,334 | ) | ||||||||||||
Dividends on preferred stock |
(708 | ) | | | | (708 | ) | |||||||||||||
Net loss attributable to common shareholders |
$ | (10,042 | ) | $ | 1,650 | $ | 151 | $ | (1,801 | ) | $ | (10,042 | ) | |||||||
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Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Cash Flows
(in thousands)
(in thousands)
For the Six Months Ended June 30, 2011 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
Cash flow from operating activities |
$ | (109,839 | ) | $ | 87,677 | $ | 32,120 | $ | | $ | 9,958 | |||||||||
Cash flow from investing activities |
(94,296 | ) | (88,113 | ) | (31,580 | ) | | (213,989 | ) | |||||||||||
Cash flow from financing activities |
208,397 | 124 | (297 | ) | | 208,224 | ||||||||||||||
Net increase (decrease) in cash |
4,262 | (312 | ) | 243 | | 4,193 | ||||||||||||||
Effect of foreign currency translation |
| | 3 | | 3 | |||||||||||||||
Cash at beginning of period |
1,556 | (1,094 | ) | 92 | | 554 | ||||||||||||||
Cash at end of period |
$ | 5,818 | $ | (1,406 | ) | $ | 338 | $ | | $ | 4,750 | |||||||||
For the Six Months Ended June 30, 2010 | ||||||||||||||||||||
Magnum Hunter | ||||||||||||||||||||
Magnum Hunter | Resources | |||||||||||||||||||
Resources | Guarantor | Non Guarantor | Corporation | |||||||||||||||||
Corporation | Subsidiaries | Subsidiaries | Eliminations | Consolidated | ||||||||||||||||
Cash flow from operating activities |
$ | (397 | ) | $ | 3,273 | $ | 413 | $ | | $ | 3,289 | |||||||||
Cash flow from investing activities |
(68,794 | ) | (8,169 | ) | (689 | ) | | (77,652 | ) | |||||||||||
Cash flow from financing activities |
76,825 | (129 | ) | 30 | | 76,726 | ||||||||||||||
Net decrease in cash |
7,634 | (5,025 | ) | (246 | ) | | 2,363 | |||||||||||||
Cash at beginning of period |
(1,707 | ) | 3,727 | 262 | | 2,282 | ||||||||||||||
Cash at end of period |
$ | 5,927 | $ | (1,298 | ) | $ | 16 | $ | | $ | 4,645 | |||||||||
NOTE 15 SUBSEQUENT EVENTS
We sold an additional 90,606 shares of our Series D Cumulative Perpetual Preferred Stock at prices
ranging from $48.00 per share to $48.10 per share for net proceeds of approximately $4.3 million,
pursuant to our ATM sales agreement subsequent to June 30, 2011, through the date of this report.
There are a total of 1,388,701 shares of Series D Preferred Stock outstanding as of the date of
this report.
Senior Credit Facility
On July 13, 2011, the Company entered into the first amendment of our Senior Credit Facility to
increase our borrowing base available under the Senior Credit Facility by $25 million from $145
million to $170 million effective June 30, 2011, an increase of 17% in the borrowing base. The
applicable interest rate margin of the Senior Credit Facility will range from 2.50% to LIBOR plus
3.50%, depending on the amount drawn at any given time on the Senior Credit Facility. Other
amendments to the facility include the elimination of interest rate floor provisions.
At August 5, 2011, the Company had loans outstanding under the Senior Credit Facility of $159 million.
Amended Term Loan Agreement
On August 2, 2011, a subsidiary of the company entered into an amendment to a term loan to increase
the borrowing by $4.4 million. The proceeds from the additional borrowing are being used to acquire two
new drilling rigs which will be used as collateral on the loan.
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North Dakota Williston Basin Properties
On August 4, 2011, Williston Hunter ND, LLC, a wholly-owned subsidiary of the Company, entered into
a Purchase and Sale Agreement (PSA) with a privately-held company (Seller) for all of the
Sellers operated working interest ownership in oil and gas mineral leases and 191 wells on
approximately 15,500 gross acres located within four counties of the Williston Basin of North
Dakota. Gross production from the properties is approximately 833 BOE per day. Total proved
reserves attributable to the acquired properties are estimated at 2.6 million barrels of oil
equivalent. Magnum Hunter presently owns an approximate 47% working interest in these oil and gas
properties. Upon closing of this transaction, Magnum Hunter will own an approximate 95% working
interest in these properties. The effective date of the transaction is April 1, 2011. Magnum Hunter
intends to close the purchase transaction on or before August 18, 2011.
Magnum Hunter will pay to the Seller a total purchase price of $57 million, to be paid at closing
in the form of $55.0 million in cash and $2.0 million in Magnum Hunter restricted common stock. The
number of shares of Magnum Hunter common stock will be determined based on the volume weighted
average price of the Companys common stock during the five trading days prior to closing. Magnum
Hunter intends to fund the cash portion of this purchase through existing liquidity and borrowings
under the Companys senior credit facility. Additionally, the Seller will retain an overriding
royalty interest in certain of the properties in various amounts not to exceed 2%. No existing debt
of Seller will be assumed by Williston Hunter in connection with the closing of the acquisition.
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Item 2. MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS |
The following discussion is intended to assist in understanding our results of operations and our
financial condition. This section should be read in conjunction with managements discussion and
analysis contained in our Annual Report on Form 10-K, as amended, for the year ended December 31,
2010, filed with the Securities and Exchange Commission (SEC). Our consolidated financial
statements and the accompanying notes included elsewhere in this Quarterly Report on Form 10-Q
contain additional information that should be referred to when reviewing this material. Certain
statements in this discussion may be forward-looking. These forward-looking statements involve
risks and uncertainties, which could cause actual results to differ from those expressed in this
report. A glossary containing the meaning of the oil and gas industry terms used in this
Managements discussion and analysis follows the Results of operations table in this Item 2.
Cautionary statements regarding forward-looking statements
Various statements in this report, including those that express a belief, expectation or intention,
as well as those that are not statements of historical fact, are forward-looking statements. The
forward-looking statements may include projections and estimates concerning the timing and success
of specific projects and our future reserves, production, revenues, income and capital spending.
When we use the words will, believe, intend, expect, may, should, anticipate,
could, estimate, plan, predict, project or their negatives, other similar expressions or
the statements that include those words, it usually is a forward-looking statement.
The forward-looking statements contained in this report are largely based on our expectations,
which reflect estimates and assumptions made by our management. These estimates and assumptions
reflect our best judgment based on currently known market conditions and other factors. Although we
believe such estimates and assumptions to be reasonable, they are inherently uncertain and involve
a number of risks and uncertainties that are beyond our control. In addition, managements
assumptions about future events
may prove to be inaccurate. We caution all readers that the forward-looking statements contained in
this report are not guarantees of future performance, and we cannot assure any reader that such
statements will be realized or the forward-looking events and circumstances will occur. Actual
results may differ materially from those anticipated or implied in the forward-looking statements
due to the factors detailed below and discussed in our 2010 Annual Report on Form 10-K, as amended,
and subsequent filings. All forward-looking statements speak only as of the date of this report. We
do not intend to publicly update or revise any forward-looking statements as a result of new
information, future events or otherwise. These cautionary statements qualify all forward-looking
statements attributable to us, or persons acting on our behalf. The risks, contingencies and
uncertainties relate to, among other matters, the following:
| global economic and financial market conditions, | |
| our business strategy, | |
| estimated quantities of oil and gas reserves, | |
| uncertainty of commodity prices in oil and gas, | |
| disruption of credit and capital markets, | |
| our financial position, | |
| our cash flow and liquidity, | |
| replacing our oil and gas reserves, | |
| our inability to retain and attract key personnel, | |
| uncertainty regarding our future operating results, | |
| uncertainties in exploring for and producing oil and gas, | |
| high costs, shortages, delivery delays or unavailability of drilling rigs, equipment, labor or other services, |
24
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| disruptions to, capacity constraints in or other limitations on the pipeline systems which deliver our gas and other processing and transportation considerations, | |
| our inability to obtain additional financing necessary to fund our operations and capital expenditures and to meet our other obligations, | |
| competition in the oil and gas industry, | |
| marketing of oil, gas and natural gas liquids, | |
| exploitation of our current asset base or property acquisitions, | |
| the effects of government regulation and permitting and other legal requirements, | |
| plans, objectives, expectations and intentions contained in this report that are not historical, and | |
| other factors discussed in our 2010 Annual Report on Form 10-K, as amended, and subsequent filings, including this Quarterly Report on Form 10-Q. |
General and Business Overview
We are an independent oil and gas company engaged in the acquisition, development and production of
oil and natural gas, primarily in West Virginia, Ohio, Kentucky, North Dakota, Texas, and Louisiana
in the United States and in Canada in the provinces of Alberta and Saskatchewan. The Company is
presently active in three of the most attractive shale resource plays in the United States, the
Marcellus Shale, Eagle Ford Shale and Williston Basin / Bakken Shale. The Company is a Delaware
corporation and was incorporated in 1997. In 2005, Magnum Hunter began oil and gas operations
under the name Petro Resources Corporation. In May 2009, Magnum
Hunter restructured its senior management team and refocused its business strategy, and in July
2009 changed its name to Magnum Hunter Resources Corporation.
The Companys new management implemented a business strategy consisting of exploiting the Companys
inventory of lower risk drilling locations and the acquisition of undeveloped leases and long-lived
proved reserves with significant exploitation and development opportunities primarily located in
unconventional resource plays. As a result of this strategy, the Company has substantially
increased its assets and production base through a combination of acquisitions and ongoing
development drilling efforts. The Companys proved reserves, production, and percentage of operated
properties has increased substantially, its inventory of acreage and drilling locations in resource
plays has grown substantially, and its management team has been expanded to accommodate this growth.
Recently, management has focused on further developing and exploiting unconventional resource
plays, the acquisition of additional operated properties and the development of associated
midstream opportunities directly related to these regions.
Recent Events
PostRock Acquisition. On December 24, 2010, the Companys subsidiary, Triad Hunter, LLC (Triad
Hunter) entered into a transaction for the acquisition of certain Marcellus Shale oil and gas
properties and leasehold mineral interests located in Wetzel and Lewis Counties, West Virginia from
affiliates of PostRock Energy Corporation.
On December 30, 2010, Triad Hunter closed on the first phase of the transaction for $31.0 million
consisting of (i) $14 million in cash and (ii) approximately 2.25 million newly issued restricted
common shares (approximately $7 million). On January 14, 2011, Triad Hunter closed on the second
phase of the transaction for the acquisition of certain Marcellus Shale assets located in Lewis
County for a total purchase price of $13.3 million. The purchase price consisted of (i) $5.875
million in cash and (ii) 946,314 newly issued restricted common shares of Magnum Hunter
(approximately $7.5 million). On June 16, 2011, Triad Hunter closed on the third phase of the
transaction for the acquisition of certain Marcellus Shale assets located in Lewis County for a
total purchase price of $4.9 million in cash before considering applicable adjustments.
Wetzel County, West Virginia Asset Acquisition. On April 7, 2011, Triad Hunter, LLC, a
wholly-owned subsidiary of the Company, entered into an agreement with Windsor Marcellus LLC,
pursuant to which Triad Hunter, LLC agreed to purchase certain oil and gas properties and leasehold
mineral interests and related assets located in Wetzel County, West Virginia for total
consideration of $20.0 million in cash. The closing of the acquisition of the Windsor Assets
occurred on April 7, 2011. The Windsor Assets also include approximately 2,225 net contiguous
acres. The fair value of the net assets acquired from Windsor, based on our preliminary
assessment, approximated the $20.0 million in consideration paid.
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NGAS Resources Acquisition. On April 13, 2011, the Company completed the acquisition of all of the
outstanding common shares of NGAS Resources, Inc, (NGAS) for total consideration of approximately
$124.5 million consisting of $15.3 million in cash, $53.1 million in debt assumed, 6,986,104 shares
of our common stock valued at approximately $55.8 million based on the closing stock price of $7.99
on April 13, 2011, and $1.2 million in warrant liability, of which $1.0 million was paid out upon
exercise of the cash option, and included in the cash consideration, and 138,388 warrants are outstanding that are exercisable for common
stock of the Company. Including the repayment at closing of debt assumed, total cash payments in
connection with the acquisition were $62.3 million. The Company has changed the name of NGAS to
NGAS Hunter, LLC, its subsidiary NGAS Production Co. to Magnum Hunter Production, Inc, and another
subsidiary, NGAS Securities, Inc. to Energy Hunter Securities, Inc. The fair value of the net
assets acquired from NGAS, based on our preliminary assessment, approximated the $124.5 million in
consideration paid.
NuLoch Resources Acquisition. On May 3, 2011, the Company completed the acquisition of all of the
outstanding common shares of NuLoch Resources, Inc, (NuLoch) for total consideration of
approximately $430.5 million consisting of 38,131,848 shares of our common stock and 4,275,998
exchangeable shares of MHR Exchangeco Corporation, an indirect wholly-owned Canadian subsidiary of
the Company, which are exchangeable for shares of the Company common stock, with a combined value
of approximately $313.8 million based on the closing stock price of $7.40 on May 3, 2011, $18.8
million in debt assumed, and deferred tax liability of approximately $97.9 million. The company
has changed the name of NuLoch to Williston Hunter Canada, Inc. and its subsidiary NuLoch America
Corporation to Williston Hunter, Inc., collectively, (Williston). The fair value of the net
assets acquired from NuLoch, based on our preliminary assessment, approximated the $430.5 million in
consideration paid.
Senior Credit Facility. On April 13, 2011, the
Company entered into a Second Amended and Restated
Credit Agreement (the Senior Credit Facility) by and among the Company, Bank of
Montreal, as Administrative Agent, Capital One, N.A., as Syndication Agent, Amegy Bank National
Association, KeyBank National Association and UBS Securities LLC, as Co-Documentation Agents, BMO
Capital Markets, as Lead Arranger and Sole Bookrunner, and the lenders party thereto. The Senior Credit Facility amended and restated, in its entirety, that certain Amended and Restated
Credit Agreement dated February 12, 2010, as amended (the Amended and Restated Credit Agreement),
among the Company, Bank of Montreal, as Administrative Agent, Capital One, N.A., as Syndication
Agent, BMO Capital Markets and Capital One, N.A., as Co-Arrangers and Joint Bookrunners, and the
lenders party thereto. New participating banks that have been added to the facility are Citibank,
N.A., Credit Suisse AG, Deutsche Bank Trust Company Americas, and Union Bank, N.A.
The Senior Credit Facility provides for an asset-based, senior secured revolving credit
facility maturing April 13, 2016, with a new borrowing base of $145
million. The initial borrowing base was set at $120 million upon the completion of the Companys
acquisition of NGAS. The borrowing base increased to $145 million upon the completion of the
Companys acquisition of NuLoch Resources, Inc. (NuLoch), which closed on May 3, 2011. The
Senior Credit Facility is governed by a semi-annual borrowing base redetermination derived from the
Companys proved crude oil and natural gas reserves, and based on such redeterminations, the
borrowing base may be decreased or may be increased up to a maximum commitment level of $250
million. The borrowing base is subject to such periodic redeterminations commencing November 1,
2011.
The terms of the Senior Credit Facility provide that the facility may be used
for loans and, subject to a $10,000,000 sublimit, letters of credit. The facility provides for a commitment fee of 0.5% based on the unused portion of the borrowing base
under the facility.
Borrowings
under the facility will, at the Companys election, bear interest at either:
(i) an alternate base rate (ABR) equal to the higher of (A) the Prime Rate, (B) the Federal Funds
Effective Rate plus 0.5% per annum and (C) the LIBO Rate for a one month interest period on such
day plus 1.0%; or (ii) the adjusted LIBO Rate, which is the rate stated on Reuters BBA Libor Rates
LIBOR01 market for one, two, three, six or twelve months, as adjusted for statutory reserve
requirements for eurocurrency liabilities, plus, in each of the cases described in clauses (i) and
(ii) above, an applicable margin ranging from 1.25% to 2.25% for ABR loans and from 2.25% to 3.25%
for adjusted LIBO Rate loans.
If an event of default occurs and is continuing, the lenders may increase the interest rate then in
effect by an additional 2% per annum plus the rate applicable to ABR loans.
The Senior Credit Facility contains negative covenants that, among other things, restrict
the ability of the Company to, with certain exceptions: (1) incur indebtedness; (2) grant liens;
(3) make certain payments; (4) change the nature of its business; (5) dispose of all or
substantially all of its assets or enter into mergers, consolidations or similar transactions; (6)
make investments, loans or advances; (7) pay cash dividends, unless certain conditions are met, and
subject to a basket of $20,000,000 per year available for payment of dividends on preferred
stock; and (8) enter into transactions with affiliates. The facility also
requires the Company to satisfy certain financial covenants, including maintaining (1) a ratio of
consolidated current assets to consolidated current liabilities of not less than 1.0 to 1.0
including the excess availability in its credit facility; (2) a ratio of EBITDAX to interest of not
less than 2.5 to 1.0; and (3) a ratio of total debt to EBITDAX of not more than (a) 4.5 to 1.0 for
the fiscal quarters
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ending June 30, 2011 and September 30, 2011 and (b) 4.0 to 1.0 for each fiscal
quarter ending thereafter. The Company is also required to enter into
certain minimum commodity hedging
agreements pursuant to the terms of the facility.
The obligations of the Company under the facility may be accelerated upon
the occurrence of an Event of Default (as such term is defined in the facility). Events of Default include customary events for a financing agreement of this type,
including, without limitation, payment defaults, defaults in the performance of affirmative or
negative covenants, the inaccuracy of representations or warranties, bankruptcy or related
defaults, defaults relating to judgments and the occurrence of a Change in Control (as such term is
defined in the facility).
Subject to certain permitted liens, the Companys obligations under
the facility have been secured by the grant of a first priority lien on no less than 80% of the value
of the proved oil and gas properties of the Company and its subsidiaries, which liens include those
properties acquired through the acquisition of NGAS and NuLoch.
In connection with the facility, the Company and certain of its
subsidiaries also entered into certain
customary ancillary agreements and arrangements, which, among other things, provide that the
indebtedness, obligations and liabilities of the Company arising under or in connection with the
facility are unconditionally guaranteed by such subsidiaries.
On July 13, 2011, the Company entered into the first amendment of the Senior Credit Facility to
increase our borrowing base available under the Senior Credit Facility by $25 million from $145
million to $170 million effective June 30, 2011, an increase of 17% in the borrowing base. The
applicable interest rate margin of the Senior Credit Facility will range from 2.50% to LIBOR plus
3.50%, depending on the amount drawn at any given time on the Senior Credit Facility. Other
amendments to the facility include the elimination of interest rate floor provisions and the
ability to increase the borrowing base to $177.5 million provided the Company enters into certain
hedging positions as provided in the amendment to the facility.
Cash
Raised Through Equity Financings. We raised substantial cash in the total amount of $113.6 million gross proceeds
through equity transactions in 2011 through August 5, 2011. Those transactions included:
| $14.2 million in gross proceeds from common equity issuance in 2011 through August 5, 2011 (at an average price of $8.27 per share) | ||
| $29.8 million in gross proceeds from the issuance of our 10.25% Series C Cumulative Perpetual Preferred Stock, at a price of $25.00 per share during 2011 through August 5, 2011 | ||
| $5.8 million in gross proceeds from the exercise of warrants and common stock options for 2011 through August 5, 2011 | ||
| $63.8 million in gross proceeds from the issuance of our 8.0% Series D Cumulative Preferred Stock for 2011 through August 5, 2011 |
We plan to continue raising both preferred and common equity in the future depending on our capital
expenditures program acquisition activities and market conditions.
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Results of Operations
The following table sets forth summary information regarding oil, natural gas and NGLs, revenues,
production, average product prices and average production costs and expenses for the three and six
months ended June 30, 2011 and 2010, respectively. See a glossary of terms used below the table.
Three Months Ended | Six Months Ended | |||||||||||||||
June 30, | June 30, | |||||||||||||||
2011 | 2010 | 2011 | 2010 | |||||||||||||
Revenues (in thousands) |
||||||||||||||||
Oil |
$ | 17,304 | $ | 5,978 | $ | 27,646 | $ | 10,598 | ||||||||
Gas |
7,674 | 963 | 11,293 | 2,470 | ||||||||||||
NGLs |
1,042 | | 1,042 | | ||||||||||||
Total oil and gas sales |
$ | 26,020 | $ | 6,941 | $ | 39,981 | $ | 13,068 | ||||||||
Field operations revenue |
$ | 5,764 | $ | 1,397 | $ | 7,123 | $ | 1,916 | ||||||||
Field operations expense |
3,299 | 1,446 | 4,454 | 1,717 | ||||||||||||
Production |
||||||||||||||||
Oil (MBbls) |
179 | 84 | 299 | 148 | ||||||||||||
Gas (MMcfs) |
1,468 | 254 | 2,171 | 459 | ||||||||||||
NGL (MBbls) |
26 | | 26 | | ||||||||||||
Total (MBoe) |
450 | 127 | 687 | 225 | ||||||||||||
Total (Boe/d) |
4,947 | 1,393 | 3,795 | 1,242 | ||||||||||||
Average prices |
||||||||||||||||
Oil (per Bbl) |
$ | 96.42 | $ | 70.88 | $ | 92.49 | $ | 71.46 | ||||||||
Gas (per Mcf) |
5.23 | 3.79 | 5.20 | 5.38 | ||||||||||||
NGL (per Bbl) |
39.89 | | 39.89 | | ||||||||||||
Total average price (per Boe) |
$ | 57.80 | $ | 54.78 | $ | 58.21 | $ | 58.14 | ||||||||
Costs and expenses (per Boe) |
||||||||||||||||
Lease operating expense |
$ | 16.42 | $ | 23.24 | $ | 15.13 | $ | 23.26 | ||||||||
Severance tax and marketing |
3.63 | 5.69 | 4.04 | 5.47 | ||||||||||||
Exploration expense |
0.94 | 2.84 | 1.07 | 2.03 | ||||||||||||
General and
administrative expense * |
52.67 | 51.31 | 44.51 | 59.04 | ||||||||||||
Depletion, depreciation and accretion |
24.02 | 22.75 | 23.80 | 18.25 |
(*) | General and administrative expense includes: | |||
(i) | acquisition related expenses of $6.1 million ($13.54 per Boe) for the three months in 2011 and $90,000 ($0.71 per Boe) for the three months in 2010; | |||
(ii) | acquisition related expenses of $7.8 million ($11.40 per Boe) for the six months in 2011 and $1.4 million ($6.21 per Boe) for the six months in 2010; and | |||
(iii) | non-cash stock compensation of $10.6 million ($23.61 per Boe) for the three months in 2011 and $2.8 million ($21.85 per Boe) for the three months in 2010; and | |||
(iv) | non-cash stock compensation of $12.0 million ($17.49 per Boe) for the six months in 2011 and $4.1 million ($18.34 per Boe) for the six months in 2010. |
Glossary of terms used:
Bbl. One stock tank barrel, of 42 U.S. gallons liquid volume, used herein to reference oil or
condensate.
MBbl. Thousand barrels of oil or condensate.
Mcf. Thousand cubic feet of natural gas.
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MMBtu. Million British thermal units.
MMcf. Million cubic feet of natural gas.
Boe. Barrels of oil equivalent, converts at rate of six Mcf equals one Boe
MBoe. Thousand barrels of oil equivalent
/d. Per day when used with volumetric units or dollars.
NGLs. Natural Gas Liquids
Three Months Ending June 30, 2011 and 2010
Oil and gas production. Oil and gas production increased 255% to 450 MBoe for the three months
ended June 30, 2011, from 127 MBoe for the three months ended June 30, 2010. Production for the
2011 period was approximately 46% oil and NGLs and 54% natural gas compared to 67% oil and 33%
natural gas for the 2010 period. Our average daily production on a Boe basis increased 255% to
4,947 Boe per day for the 2011 period compared to 1,393 Boe per day for the 2010 period. The
increase in production is primarily attributable to the results of the acquisitions of NGAS and
NuLoch as well as our drilling program in the Marcellus and Eagle Ford Shales in the fourth quarter
of 2010 and the first half of 2011. Eagle Ford and Marcellus production accounted for 70 and 73
Mboe, respectively, of the production increase in the second quarter of 2011. Additional
production increases are due to the inclusion of the production from NGAS and NuLoch acquisitions,
which resulted in change of approximately 136 and 29 Mboe, respectively. Production from the
acquired NuLoch wells was approximately 30.1 MBoe lower than normal due to adverse weather related shut-in of
wells. We successfully completed 4 gross (1.96 net) horizontal wells in the Eagle Ford Shale and 2
gross (0.83 net) wells in the Marcellus Shale during the three months ended June 30, 2011. We
experienced production declines of 6 Mboe in our Williston Basin production, 1 Mboe in our Gulf Coast production, and 5 Mboe
in our other South Texas properties. Weather related shut-in of wells caused production to be 22.2 Mboe lower than normal at our Williston Basin properties. We expect our oil and gas production to continue to increase
during the remainder of 2011 due to our acquisition of both NGAS and NuLoch in the second quarter of
2011 as well as our continued drilling programs, we anticipate to increase production from drilling operations for the remainder of 2011.
Oil and gas sales. Oil and gas sales increased $19 million, or 275%, for the three months ended
June 30, 2011 to $26 million from $6.9 million for the three months ended June 30, 2010. The
increase in oil and gas sales principally resulted from increased production as described above.
The average price we received for our oil production increased $25.53 per barrel (36%) to $96.42
per barrel, while the average price received for gas production increased $1.44 per Mcf (38%) to
$5.23 per Mcf. Of the $19 million increase in
oil and gas sales, approximately $7 million, or 35%, was attributable to an increase in oil and gas
prices, while approximately $12 million, or 65% of the increase in oil and gas sales was
attributable to the increase in production volumes. The prices we receive for our products are
generally tied to commodity index prices. We periodically enter into commodity derivative contracts
in an attempt to offset some of the variability in prices. (See the discussion of commodity
derivative activities in Note 7 to our condensed consolidated financial statements.)
Field operations revenue and expense. Field operations revenue increased 313% to approximately
$5.8 million as compared to $1.4 million in the 2010 period. Field operations expense was $3.3
million for the three months ended June 30, 2011 as compared to $1.4 million for the three months
ended June 30, 2010. As a result, net field service income increased by $2.5 million for the three
months ended June 30, 2011 over the 2010 period. Approximately $1.6 million of the increase in
income resulted from the operations of the Eureka Hunter subsidiary. Another $903,000 of the
increase resulted from the gas compression and transportation activities of the NGAS Hunter
subsidiary for the three months ended June 30, 2011. Field service revenue includes revenue and
expense from services provided to third parties for drilling, well servicing, natural gas
transportation, salt water disposal, and operating services.
Lease operating expense. Our lease operating expenses increased $4.5 million, or 151%, for the
three months ended June 30, 2011 to $7.4 million ($16.42 per Boe) from $2.9 million ($23.24 per
Boe) for the three months ended June 30, 2010. The decline in the operating expense per Boe is due
to the effect of adding new production from lower cost resource plays and acquisition of producing
assets.
Severance taxes and marketing. Our severance taxes increased $1.2 million, or 198%, for the three
months ended June 30, 2011, to $1.8 million from $587,000 for the three months ended June 30, 2010.
All of the increase in severance taxes was attributable to the increase in oil and gas production.
Marketing expenses decreased by $101,000, or 76%, for the three months ended June 30, 2011, to
$33,000 from $133,000 for the three months ended June 30, 2010 due to production declines at our
existing Williston Basin properties.
Exploration expense. We incurred $423,000 of exploration expense for the three months ended June
30, 2011, compared to $359,000 for the three months ended June 30, 2010 due to higher geological
and geophysical costs as well as delay rentals paid in our Appalachian Basin region.
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Depletion, depreciation and accretion. Our depletion, depreciation and accretion expense increased
$7.9 million, or 275%, to $10.8 million for the three months ended June 30, 2011 from $2.9 million
for the three months ended June 30, 2010 due to increased production in the 2011 period. Our DD&A
per Boe increased by $1.27, or 5.6%, to $24.02 per Boe for the three months ended June 30, 2011,
compared to $22.75 per Boe for the three months ended June 30, 2010. The increase in DD&A expense
per BOE was primarily attributable to the higher cost to drill and equip our new Eagle Ford and
Marcellus Shale wells, which are horizontally drilled wells and which require more expensive
completion techniques than traditional vertically-drilled wells.
General and administrative. Our general and administrative expenses (G&A) increased $17.2 million,
or 265%, to $24 million ($52.67 per Boe) for the three months ended June 30, 2011 from $6.5 million
($51.31 per Boe) for the three months ended June 30, 2010. G&A expenses increased overall during
the 2011 period due to expansion activities of the Company, partially offset by a decrease in bonus
and other accruals. Non-cash stock compensation totaled approximately $10.6 million for the 2011
period and $2.8 million for the 2010 period. Also included in G&A in the 2011 period are
acquisition related costs of approximately $6.1 million which were for legal, consulting and other
costs related to the acquisitions of NGAS, Nuloch, and the PostRock
assets in the second quarter of 2011.
Acquisition expenses incurred in the 2010 period of $90,000 were related to the acquisition of
Triad in February 2010. These costs were expensed due to accounting standards which require that
acquisition costs must be expensed rather than capitalized as part of the cost of the asset being
acquired for years beginning in 2010. We expect overall G&A costs to increase in the aggregate in
2011, but for recurring, cash G&A expenses to begin to decline on a Boe basis due to the ongoing
expansion activities of the Company.
Interest expense, net. Our interest expense, net of interest income, increased approximately $2.9
million, or 277% to $3.9 million for the three months ended June 30, 2011, from $1.0 million for
the three months ended June 30, 2010. Approximately $2.3 million of this increase is the result of
a non-cash write off of the unamortized balance of deferred financing fees from the credit facility
that was replaced by the Senior Credit Facility in April of 2011. The
remaining $300,000 of the increase was substantially the result of our higher average debt level
during 2011 partially offset by lower interest rates.
Commodity derivative activities. Realized gains and losses from our commodity derivative activity
decreased our earnings by approximately $517,000 and increased our earnings by approximately
$602,000 for the three months ended June 30, 2011 and 2010, respectively. Realized gains and losses
are derived from the relative movement of oil and gas prices on the products we sell in relation to
the range of prices in our derivative contracts for the respective three months. The unrealized
gain on commodity derivatives was approximately $3.2 million for the 2011 period and $676,000 for
the 2010 period. As commodity prices increase, the fair value of the open portion of those
positions decreases. As commodity prices decrease, the fair value of the open portion of those
positions increases. Historically, we have not designated our derivative instruments as cash-flow
hedges. We record our open derivative instruments at fair value on our consolidated balance sheets
as either unrealized gains or losses on commodity derivatives. We record
all changes in realized and unrealized gains and losses on our consolidated statements of
operations under the caption entitled Gain (loss) on derivative contracts. Our gain or loss from
realized and unrealized derivative contracts was a gain of approximately $2.7 million and a gain of
approximately $1.3 million for the three months ended June 30, 2011 and 2010, respectively. (See
Note 7 to our condensed consolidated financial statements for more information.)
Deferred tax benefit. The Company recorded a deferred tax benefit at the applicable statutory rates
of $197,000 during the three months ended June 30, 2011, as a result of the operating loss incurred
by Williston Hunter Canada, Inc, and Williston Hunter, Inc during the period. These entities
recorded the deferred tax benefit because they are separate tax entities from Magnum Hunter
Resources Corporation and its other subsidiaries. There are no deferred tax benefits recorded for
Magnum Hunter Resources Corporation and its U.S. based subsidiaries for the three months ended
June 30, 2011.
Net income attributable to non-controlling interest. Net income attributable to non-controlling
interest was approximately $84,000 for the three months ended June 30, 2011 versus a loss of $2,000
for same period in 2010. This represents 12.5% of the gain or loss incurred by our subsidiary, PRC
Williston. We record a non-controlling interest in the results of operations of this subsidiary
because we are contractually obligated to make distributions to the holders of this interest
whenever we make distributions to ourselves from the subsidiary company.
Loss from Continuing Operations. We had a loss from continuing operations of $15.0 million for the
2011 period versus a loss of $6.2 million for the 2010 period, an increase of $8.8 million, or 142%
This was due to an increase in operating loss of $7.5 million and interest expense of $2.9 million
offset by an increase in gain on derivative contracts of $1.4 million.
Income from Discontinued Operations. On October 29, 2010, we closed on a divestiture of our Cinco
Terry properties effective October 1, 2010. We have reclassified $955,000 of Cinco Terry operating
income less interest expense to discontinued operations for the three month period ended June 30,
2010. As a result of this divestiture, our previously reported average daily production volume of
366 Boepd from this property for the 2010 period has been excluded from our reported total average
daily production volumes.
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Dividends on Preferred Stock. Total dividends on our Series B, Series C, and Series D Preferred
Stock were approximately $3.5 million for the three months ended June 30, 2011, versus $446,000 for
the three months ended June 30, 2010. The Series C Preferred Stock had a stated value of
approximately $100 million and $14.8 million at June 30, 2011 and 2010, respectively and carries a
cumulative dividend rate of 10.25% per annum. The Series D Preferred Stock had a stated value of
$64.9 million and $0 at June 30, 2011 and 2010, respectively and carries a cumulative dividend rate
of 8.0% per annum. We redeemed all outstanding shares of Series B Preferred Stock in June 2010.
Net Loss attributable to Common Shareholders. Net loss attributable to common shareholders was
$18.5 million in the 2011 period versus $6.0 million in the 2010 period. Our net loss per common
share, basic and diluted, was $0.16 per share for the three months ended June 30, 2011, compared to
$0.10 per share for the 2010 period. Our weighted average shares outstanding increased by
approximately 50.5 million shares, or 81%, to approximately 112.6 million shares from the 2010
period to the 2011 period due predominately to the NuLoch and NGAS acquisitions. Our net loss per share from continuing operations was $0.16 per share
for the three months ended June 30, 2011, versus $0.11 per share for the 2010 period. We had
income from discontinued operations of $0.01 per share in the 2010 period from the Cinco Terry
assets, which were sold on October 29, 2010.
Six Months Ending June 30, 2011 and 2010
Oil and gas production. Oil and gas production increased 206% to 687 MBoe for the six months ended
June 30, 2011, from 225 MBoe for the six months ended June 30, 2010. Production for the 2011
period was approximately 47% oil and NGLs and 53% natural gas compared to 66% oil and 34% natural
gas for the 2010 period. Our average daily production on a Boe basis increased 206% to 3,795 Boe
per day for the 2011 period compared to 1,242 Boe per day for the 2010 period. The increase in
production is primarily attributable to the results of the acquisitions of NGAS and NuLoch as well
as our drilling program in the Marcellus and Eagle Ford Shales in the fourth quarter of 2010 and
the first half of 2011. Eagle Ford and Marcellus production accounted for 116 and 127 Mboe,
respectively, of the production increase in the second quarter of 2011. Other production increases
are due to the inclusion of the production from NGAS and NuLoch acquisitions, which resulted in
change of approximately 136 and 29 Mboe, respectively. Production from the acquired NuLoch wells
was approximately 30.1 MBoe lower than normal due to weather related shut-in of wells. We
successfully completed 9 gross (5.4 net) horizontal wells in the Eagle Ford Shale and 5 gross (3.5
net) wells in the Marcellus Shale during the six months ended June 30, 2011. We experienced
production declines of 14 Mboe in our Williston basin production, 2 Mboe in our Gulf Coast
production and 8 Mboe in our other South Texas properties. Weather
related shut-in of wells caused production to be 22.2 Mboe lower than
normal at our Williston Basin properties. We expect our oil
and gas production to continue to increase during the remainder of 2011 due to our acquisition of
both NGAS and NuLoch in the second quarter of 2011 as well as our
continued drilling
programs, we anticipate to increase production from drilling
operations for the remainder of 2011.
Oil and gas sales. Oil and gas sales increased $26.9 million, or 206%, for the six months ended
June 30, 2011 to $40.0 million from $13.1 million for the six months ended June 30, 2010. The
increase in oil and gas sales principally resulted from increased production
as described above. The average price we received for our oil production increased $21.02 per
barrel (29%) to $92.49 per barrel, while the average price received for gas production decreased
$0.18 per Mcf (3.4%) to $5.20 per Mcf. Our average price for gas decreased due to market trends in
the price for natural gas and prior fixed base gas contracts expiring. Of the $26.9 million
increase in oil and gas sales, approximately $5.9 million, or 21%, was attributable to an increase
in oil prices, net of a decrease in gas prices, while approximately $21.0 million, or 78% of the
increase in oil and gas sales was attributable to the increase in production volumes. The prices we
receive for our products are generally tied to commodity index prices. We periodically enter into
commodity derivative contracts in an attempt to offset some of the variability in prices. (See the
discussion of commodity derivative activities in Note 7 to our condensed consolidated financial
statements.)
Field operations revenue and expense. Field operations revenue increased 272% to approximately
$7.1 million as compared to $1.9 million in the 2010 period. Field operations expense was $4.5
million for the six months ended June 30, 2011 as compared to $1.8 million for the six months ended
June 30, 2010. As a result, net field service income increased by $2.6 million for the three months
ended June 30, 2011 over the 2010 period. Approximately $1.7 million of the increase in income
resulted from the operations of the Eureka Hunter subsidiary. Another $903,000 of the increase
resulted from the gas compression and transportation activities of the NGAS Hunter subsidiary
acquired during April 2011. Field service revenue includes revenue and expense from services
provided to third parties for drilling, well servicing, natural gas transportation, salt water
disposal, and operating services.
Lease operating expense. Our lease operating expenses increased $5.2 million, or 99%, for the six
months ended June 30, 2011 to $10.4 million ($15.13 per Boe) from $5.2 million ($23.26 per Boe)
for the six months ended June 30, 2010. The decline in the per Boe operating expense is due to the
effect of adding new production, principally in the Marcellus and Eagle Ford Fields, at a lower
cost per unit produced when compared to the per unit operating cost in our older, legacy fields.
Severance taxes and marketing. Our severance taxes increased $1.7 million, or 175%, for the six
months ended June 30, 2011, to $2.6 million from $958,000 for the six months ended June 30, 2010.
All of the increase in severance taxes was attributable to the increase
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in oil and gas production.
Marketing expenses decreased by $132,000, or 49%, for the six months ended June 30, 2011, to
$139,000 from $271,000 for the six months ended June 30, 2010 due to production declines at our
existing Williston Basin properties.
Exploration expense. We incurred $738,000 of exploration expense for the six months ended June 30,
2011, compared to $457,000 for the six months ended June 30, 2010 due to higher geological and
geophysical costs as well as delay rentals paid in our Appalachian Basin region.
Depletion, depreciation and accretion. Our depletion, depreciation and accretion expense increased
$12.2 million, or 299%, to $16.3 million for the six months ended June 30, 2011 from $4.1 million
for the six months ended June 30, 2010 due to increased production in the 2011 period. Our DD&A per
Boe increased by $5.55, or 30%, to $23.80 per Boe for the six months ended June 30, 2011, compared
to $18.25 per Boe for the six months ended June 30, 2010. The increase in DD&A expense per BOE was
primarily attributable to the higher cost to drill and equip our new Eagle Ford and Marcellus Shale
wells, which are horizontally drilled wells and which require more expensive completion techniques
than traditional, vertically-drilled wells.
General and administrative. Our general and administrative expenses (G&A) increased $17.3 million,
or 130%, to $30.6 million ($44.51 per Boe) for the six months ended June 30, 2011 from $13.3
million ($59.04 per Boe) for the six months ended June 30, 2010. G&A expenses increased overall
during the 2011 period due to expansion activities of the Company, partially offset by a decrease
in bonus and other accruals. Non-cash stock compensation totaled approximately $12.0 million
($17.49 per Boe) for the 2011 period and $4.1 million ($18.34 per Boe) for the 2010 period. Also
included in G&A in the 2011 period are acquisition related costs of approximately $7.8 million
which were for legal, consulting and other costs related to the acquisitions of NGAS and Nuloch in
April and May of 2011, respectively. Acquisition expenses incurred in the 2010 period of $1.4
million were related to the acquisition of Triad in February 2010. These costs were expensed due
to accounting standards which require that acquisition costs must be expensed rather than
capitalized as part of the cost of the asset being acquired for years beginning in 2010. We expect
overall G&A costs to increase in the aggregate in 2011, but for recurring, cash based G&A expenses
to continue to decline on a Boe basis due to the ongoing expansion activities of the Company.
Interest expense, net. Our interest expense, net of interest income, increased approximately $3.0
million, or 174% to $4.7 million for the six months ended June 30, 2011, from $1.7 million for the
six months ended June 30, 2010. Approximately $2.3 million of this increase is the result of a
non-cash write off of the unamortized balance of deferred financing fees from the credit facility
that was replaced by the Senior Credit Facility in April 2011. The remaining
$300,000 of the increase was substantially the result of our higher average debt level during 2011
partially offset by lower interest rates.
Commodity derivative activities. Realized gains and losses from our commodity derivative activity
decreased our earnings by approximately $508,000 and increased our earnings by approximately $3.1
million for the six months ended June 30, 2011 and 2010, respectively. Realized gains and losses
are derived from the relative movement of oil and gas prices on the products we sell in relation to
the range of prices in our derivative contracts for the respective six months. The unrealized loss
on commodity derivatives was approximately $166,000 for the 2011 period and $700,000 for the 2010
period. As commodity prices increase, the fair value of the open portion of those positions
decreases. As commodity prices decrease, the fair value of the open portion of those positions
increases. Historically, we have not designated our derivative instruments as cash-flow hedges. We
record our open derivative instruments at fair value on our consolidated balance sheets as either
unrealized gains or losses on commodity derivatives. We record all changes in realized and
unrealized gains and losses on our consolidated statements of operations under the caption entitled
Gain (loss) on derivative contracts. Our realized and unrealized derivative contracts generated
a loss of approximately $674,000 and a gain of approximately $2.4 million for the six months ended
June 30, 2011 and 2010, respectively. (See Note 7 to our condensed consolidated financial
statements for more information.)
Deferred tax benefit. The Company recorded a deferred tax benefit at the applicable statutory rates
of $197,000 during the six months ended June 30, 2011, as a result of the operating loss incurred
by Williston Hunter Canada, Inc, and Williston Hunter, Inc during the period. These entities
recorded the deferred tax benefit because they are separate tax entites from Magnum Hunter
Resources Corporation and its other subsidiaries. There are no deferred tax benefits recorded for
Magnum Hunter Resources Corporation and its U.S. based subsidiaries for the six months ended June
30, 2011.
Net income attributable to non-controlling interest. Net income attributable to non-controlling
interest was approximately $117,000 for the six months ended June 30, 2011 versus $65,000 for same
period in 2010. This represents 12.5% of the gain or loss incurred by our subsidiary, PRC
Williston. We record a non-controlling interest in the results of operations of this subsidiary
because we are contractually obligated to make distributions to the holders of this interest
whenever we make distributions to ourselves from the subsidiary company.
Loss from Continuing Operations. We had a loss from continuing operations of $21.7 million for the
2011 period versus a loss of $10.3 million for the 2010 period, an increase of $11.4 million, or
111%. This was due to a increase in operating loss of $5.6 million offset by an increase in loss
on derivative contracts of $3.1 million and an increase in interest expense of $3.0 million.
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Income from Discontinued Operations. On October 29, 2010, we closed on a divestiture of our Cinco
Terry properties effective October 1, 2010. We have reclassified $1.0 million of Cinco Terry
operating income less interest expense to discontinued operations for the six month period ended
June 30, 2010. As a result of this divestiture, our previously reported average daily production
volume of 324 Boepd from this property for the 2010 period has been excluded from our reported
total average daily production volumes.
Dividends on Preferred Stock. Total dividends on our Series B, Series C, and Series D Preferred
Stock were approximately $6.1 million for the six months ended June 30, 2011, versus $708,000 for
the six months ended June 30, 2010. The Series C Preferred Stock had a stated value of
approximately $100 million and $14.8 million at June 30, 2011 and 2010, respectively and carries a
cumulative dividend rate of 10.25% per annum. The Series D Preferred Stock had a stated value of
$64.9 million and $0 at June 30, 2011 and 2010, respectively and carries a cumulative dividend rate
of 8.0% per annum. We redeemed all outstanding shares of Series B Preferred Stock in June 2010.
Net Loss attributable to Common Shareholders. Net loss attributable to common shareholders was
$27.8 million in the 2011 period versus $10.0 million in the 2010 period. Our net loss per common
share, basic and diluted was $0.29 per share for the six months ended June 30, 2011, compared to
$0.17 per share for the 2010 period. Our weighted average shares outstanding increased by
approximately 32.1 million shares, or 52%, to approximately 94.2 million shares from the 2010
period to the 2011 period principally as a result of the shares issued to acquire NuLoch and NGAS.
Our net loss per share from continuing operations was $0.29 per share for the six months ended June
30, 2011, versus $0.19 per share for the 2010 period. We had income from discontinued operations
of $0.02 per share in the 2010 period from the Cinco Terry assets which were sold on October 29,
2010.
Liquidity and Capital Resources
We
generally will rely on cash generated from operations, borrowings
under our revolving Senior Credit Facility and, to the extent that credit and capital market conditions will allow, public and
private equity and debt offerings to satisfy our liquidity needs. Our ability to fund planned
capital expenditures and to make acquisitions depends upon our future operating performance,
availability of borrowings under our revolving credit facility, and more broadly, on the
availability of equity and debt financing, which is affected by prevailing economic conditions in
our industry and financial, business and other factors, some of which are beyond our control. We
cannot predict whether additional liquidity from equity or debt
financings beyond our revolving credit facility will be available on acceptable terms, or at all, in the foreseeable future.
Our cash flow from operations is driven by commodity prices, production volumes and the effect of
commodity derivatives. Prices for oil and gas are affected by national and international economic
and political environments, national and global supply and demand for hydrocarbons, seasonal
influences of weather and other factors beyond our control. Our working capital is significantly
influenced by changes in commodity prices, and significant declines in prices will cause a decrease
in our production volumes and exploration and development expenditures. Cash flows from operations
are primarily used to fund exploration and development of our oil and gas properties.
We intend to fund 2011 capital expenditures, excluding any acquisitions, primarily out of
internally-generated cash flows and, as necessary, borrowings under our revolving credit facility,
exercises of outstanding common stock options and warrants, and selective
issuances of equity securities under our ATM facility. As of June 30, 2011, we had approximately
$9.6 million of cash on hand, including $4.8 million of restricted cash, and $31.0 million
available to borrow under our revolving credit facility, for total liquidity of approximately $40.6
million on that date. On April 13, 2011, in conjunction with our acquisition of NGAS, our
revolving credit agreement was amended and restated and our borrowing base was increased to $120
million. On May 3, 2011, in conjunction with the acquisition of NuLoch, our borrowing base was
further increased to $145 million, providing an additional $25 million of availability. On July
13, 2011, the revolving credit facility was amended and our borrowing base was increased to $170
million effective June 30, 2011, providing an additional $25 million of availability, with the
ability to increase the borrowing base to $177.5 million if the Company enters into certain swap
agreements. From July 1, 2011, through August 5, 2011, we realized additional proceeds from
issuance of new Series D Preferred Stock totaling approximately $4.3 million.
There are several factors that will affect our liquidity for the remainder of 2011. We anticipate
having increased operating cash flows as a result of the NGAS acquisition and NuLoch acquisition,
restored production in the Williston Basin, and the successful results of our ongoing drilling
program in all three core regions, offset by increased interest expense due to higher debt levels
and higher dividend costs due to the issuance of our Series D Preferred Stock. We also expect to
have increased salary and other administrative costs associated with the increased number of
employees resulting from the acquisitions closed during the first half of 2011 and subsequent
acquisition activity of the Company. Our borrowing base under our
revolving credit facility was
increased to $145 million and $170 million on May 3, 2011, and June 30, 2011, respectively. We
expect the additional operating cash flows from the new acquisitions, additional liquidity under
the revolving credit facility, and cash provided by the issuance of equity securities in
2011 to provide the cash necessary to meet all currently budgeted operating and capital expenditure
requirements for the remainder of the 2011 fiscal year.
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The following table summarizes our sources and uses of cash for the periods noted:
Six Months Ended June 30, | ||||||||
2011 | 2010 | |||||||
(In thousands) | ||||||||
Cash flows provided by operating activities |
$ | 9,958 | $ | 3,289 | ||||
Cash flows used in investing activities |
(213,989 | ) | (77,652 | ) | ||||
Cash flows provided by financing activities |
208,224 | 76,727 | ||||||
Net increase (decrease) in cash and
cash equivalents |
$ | 4,193 | $ | 2,364 | ||||
Operating Activities
In comparing the six month periods ended June 30, 2011 and 2010, our cash flows from operations
increased by approximately $6.7 million due mainly to improved operating results before
depreciation and depletion expense.
Investing Activities
Our cash flows used in investing activities for the six months ended June 30, 2011 were $214.0
million, which primarily were a result of the acquisition activity undertaken by the Company during
the quarter. The Company used $60.4 million in cash in the NGAS acquisition, net of cash acquired
of $1.9 million and $18.1 million in cash in the Nuloch acquisition, net of cash acquired of
$640,000. During the six months ended June 30, 2011, we used $5.5 million of cash for deposits on
equipment, and we received proceeds from the sale of assets of $1.8 million. During the six months
ended June 30, 2011, we used $131.8 million in cash for capital expenditures which includes $20
million cash in the acquisition of the Wetzel County assets from Windsor Marcellus, LLC, $4.9
million cash in the third phase of the acquisition of assets from PostRock, and $105 million for
capital expenditures under our 2011 capital expenditures budget as described below.
Our cash flows used in investing activities for the first six months in 2010 were for the Triad
acquisition of approximately $59.5 million, approximately $11.4 million for the acquisition of
undeveloped leasehold interests, primarily in the Eagle Ford Shale in South Texas and the Marcellus
Shale in West Virginia, approximately $1.3 million for exploratory drilling in South Texas,
approximately $3.3 million gross ($2.6 million net after applying previously paid drilling
advances) in development drilling in our Cinco Terry field (which has since been divested) as well
as our North Dakota and East Chalkley fields, and approximately $1.7 million in pipeline and other
development expenditures, resulting in approximately $17.9 million in gross capital expenditures
($17.2 million net of drilling advances) in the 2010 period. We also made advances of
approximately $967,000 and had proceeds from the sale of assets of approximately $30,000 in the
2010 period.
Financing Activities
We borrowed $228.0 million under our revolving credit facility and made principal repayments of
$119.0 million during the 2011 period versus borrowing $70.0 million and repaying $25.0 million in
the 2010 period. In the 2011 period, we realized $5.8 million from the exercise of common stock
options and warrants. We issued 1,190,544 shares of our Series C Cumulative Perpetual Preferred
Stock in the 2011 period for net proceeds of $29.1 million, and we issued 1,298,095 shares of our
Series D Preferred Stock for net proceeds of $59.5 million.
The amount borrowed under the revolving credit facility in 2010 was principally used to fund the
Triad acquisition. We spent approximately $2.6 million for deferred financing costs on the
amendment and restatement of our revolving credit facility and the expansion of our borrowing base
to $75.0 million. We received approximately $433,000 in proceeds and repaid approximately $576,000
of other loans in the 2010 period. We received approximately $24.4 million net from the issuance
of approximately 8.5 million shares of our common stock, approximately $13.0 million from exercise
of approximately 4,800,000 of our $2.00 common stock warrants, 1,400,000 of our
$2.50 common stock warrants and approximately $9.2 million net from the issuance of 379,310 shares
of our Series C Preferred Stock in the 2010 period. We also paid approximately $11.25 million upon
redemption of 3,000,000 shares of our Series B Preferred Stock and issued 1,000,000 shares of
common stock upon conversion of 1,000,000 shares of our Series B Preferred Stock, we paid
approximately $734,000 in dividends on our Series B and Series C Preferred Stock, and approximately
$116,000 for surrendered stock options in the 2010 period.
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2011 Capital Expenditures
The following table summarizes our estimated capital expenditures excluding acquisitions for 2011.
We intend to fund 2011 capital expenditures, excluding any acquisitions, primarily out of
internally-generated cash flows, cash provided by the issuance of new
common and preferred stock, and, as necessary, borrowings under our revolving credit facility.
Year Ending | ||||
December 31, | ||||
2011 | ||||
(In thousands) | ||||
Williston Basin |
||||
Shale drilling |
$ | 70,000 | ||
Appalachian Basin |
||||
Marcellus Shale drilling |
70,000 | |||
Eureka Hunter Pipeline |
40,000 | |||
Eagle Ford |
||||
Eagle Ford Shale Drilling |
75,000 | |||
Total capital expenditures |
$ | 255,000 | ||
Our capital expenditure budget for 2011 is subject to change depending upon a number of factors,
including economic and industry conditions at the time of drilling, prevailing and anticipated
prices for oil and gas, the results of our development and exploration efforts, the availability of
sufficient capital resources for drilling prospects, our financial results, the availability of
leases on reasonable terms and our ability to obtain permits for the drilling locations.
We believe that cash flows from operations, available cash, cash provided by the issuance of new
common and preferred stock, and borrowings under our revolving credit facility will finance
substantially all of our anticipated capital needs through 2011. We may also use our revolving
credit facility for possible acquisitions and temporary working capital needs. Further, we may
decide to opportunistically access the public or private equity or debt markets for potential
acquisitions, working capital or other liquidity needs, if such financings are available on
acceptable terms.
Senior
Credit Facility
On
April 13, 2011, we entered into the Senior
Credit Facility which increased
the maximum commitment to $250 million. The borrowing base has been established at $145 million,
and the initial borrowing base was set at $120 million upon the completion of the Companys
acquisition of NGAS Resources, Inc, which closed April 13, 2011. The borrowing base increased to
the New Borrowing Base level of $145 million upon the closing of the Companys acquisition of
Williston Basin focused NuLoch Resources, Inc, which closed on May 3, 2011.
On July 13, 2011, we entered into the First Amendment to the Senior
Credit Facility effective June 30, 2011. The First Amendment increased the Companys borrowing base to
$170 million and provided for an additional increase in borrowing base to $177.5 million if the
Company enters into certain swap agreements as set forth in the First Amendment.
The Senior
Credit Facility provides for a semi-annual redetermination of the borrowing
base, which is based on the value assigned to the Companys proved crude oil and natural gas
reserves as determined by third party engineering consultants. The New Borrowing Base has been
established based upon the proved reserve values as of December 31, 2010, from a combination of
NGASs, NuLochs and the Companys total proved reserves. Based on values assigned to crude oil
and natural gas properties which may be either acquired or drilled over time, the Companys
borrowing base may increase up to the maximum $250 million commitment level. The Senior
Credit Facility replaces Magnum Hunters $150 million three-year term secured revolving credit
facility, which had a borrowing base of $71.5 million. The Senior
Credit Facility also
provides for an interest rate margin ranging from LIBOR plus 3.25% depending on the level of
outstanding borrowings at any given time under the facility, which is a
lower cost of funds that the prior senior bank facility.
Covenants
The Senior
Credit Facility requires the Company to satisfy certain affirmative financial
covenants, including maintaining (i) a ratio of consolidated current assets to consolidated current
liabilities of not less than 1.0 and 1.0, (ii) a ratio of EBITDAX to interest of not less than 2.5
to 1.0, and (iii) a ratio of total debt to EBITDAX of not more than (a) 4.5 to 1.0 for the fiscal
quarters ending June 30, 2011 and September 30, 2011 and (b) 4.0 to 1.0 for each fiscal quarter
ending thereafter. The Company is also required to enter into certain commodity hedging agreements
pursuant to the terms of the facility.
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To date, we have experienced no disruptions in our ability to access our revolving credit facility.
However, our lenders have substantial ability to reduce our borrowing base by a majority vote of the bank group on the basis of
subjective factors. These subjective factors include valuation of loan collateral based on methodology, assumptions and
discount rates as such lenders customarily use in evaluating
oil and gas properties.
Related Party Transactions
We rented an airplane for business use at various times from Pilatus Hunter, LLC, an entity 100%
owned by Mr. Evans, our Chairman and CEO. Airplane rental expenses totaled $105,000 and $228,000,
for the three and six months ended June 30, 2011, respectively, and $64,000 and $188,000 for the
three and six months period end June 30 2010, respectively.
We obtained accounting services and use of office space from GreenHunter Energy, Inc., an entity
for which Mr. Evans is an officer and major shareholder and for which Mr. Ormand, our Chief
Financial Officer and a director, is a director. Professional services expenses totaled $28,000 and
$46,000, and for the three and six months ended June 30, 2011, respectively, and $30,000 and
$60,000 for the three and six months ended June 30, 2010, respectively.
We entered into a one year lease for a corporate apartment from an executive of the Company for
monthly rent of $4,500 for use by a Company employee. During the six months ended June 30, 2011
the Company paid rent of $9,000 pertaining to the lease.
As of June 30, 2011, our net accounts payable to Pilatus Hunter, LLC was $16,000 and our net
accounts payable to GreenHunter Energy, Inc. was $10,000.
Contractual Commitments
Our contractual commitments consist of long-term debt, accrued interest on long-term debt,
operating lease obligations, asset retirement obligations and employment agreements with executive
officers.
Our long-term debt comprises borrowings under our revolving credit facility and term equipment debt
assumed in the Triad acquisition. Interest on revolving debt is based on the rate applicable under
our revolving credit facility, which was 4.5% at June 30, 2011. The term equipment debt has an
average interest rate of approximately 6.03% at June 30, 2011. (See Note 9 in our condensed
consolidated financial statements.)
As of June 30, 2011, we rent various office spaces in Houston, Texas, that total approximately
22,966 square feet at a cost of $37,925 per month for the remaining terms ranging from eight to
fifty-nine months. Triad had various lease commitments for periods ranging from six to
seventy-seven months at June 30, 2011, and with monthly payments of approximately $24,618 as of
that date.
On September 25, 2010 the Company entered into a twelve month drilling contract. Our remaining
maximum liability under the drilling contract, which would apply if we terminated the contract
before the end of its term, was approximately $1.1 million as of June 30, 2011.
On December 14, 2010, the Company entered into a twelve month drilling contract for the 2011 year.
Our remaining maximum liability under the drilling contract, which would apply if we terminated the
contract before the end of its term, was approximately $1.2 million as of June 30, 2011.
On June 24, 2011, the Company entered into a 3 year drilling contract from October 31, 2011,
through October 31, 2014. Our remaining maximum liability under the drilling contract, which would
apply if we terminated the contract before the end of its term, was approximately $19.5 million as
of June 30, 2011.
On June 29, 2011, the Company entered into a twelve month drilling contract. Our remaining maximum
liability under the drilling contract, which would apply if we terminated the contract before the
end of its term, was approximately $3.0 million as of June 30, 2011.
Our asset retirement obligation represents the estimated present value of the amount we will incur
to plug, abandon and remediate our producing properties at the end of their productive lives, in
accordance with applicable federal, state and local laws. We determine our asset retirement
obligation by calculating the present value of estimated cash flows related to the liability. The
retirement obligation is recorded as a liability at its estimated present value as of the assets
inception, with an offsetting increase to proved properties. Periodic accretion of discount of the
estimated liability is recorded as an expense in the income statement.
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We have outstanding employment agreements with four of our officers for terms ranging up to fifteen
months. Our maximum commitment under the employment agreements, which would apply if the employees
covered by these agreements were all terminated without cause, was approximately $1.1 million at
June 30, 2011.
The following table summarizes our contractual commitments as of June 30, 2011 (in thousands):
Contractual Obligations | Total | 2011 | 2012 - 2013 | 2014 - 2015 | After 2015 | |||||||||||||||
Long-term debt(1) |
$ | 147,877 | $ | 787 | $ | 3,173 | $ | 143,790 | $ | 127 | ||||||||||
Interest on long-term debt(2) |
24,197 | 3,165 | 12,590 | 8,442 | | |||||||||||||||
Operating lease obligations(3) |
2,514 | 501 | 1,049 | 613 | 351 | |||||||||||||||
Asset retirement obligations(4) |
14,968 | 1,619 | 1,217 | 1,688 | 10,444 | |||||||||||||||
Employment agreements with officers |
1,105 | 1,105 | | | | |||||||||||||||
Drilling contract commitment |
24,841 | 6,440 | 13,513 | 4,888 | | |||||||||||||||
Total |
$ | 215,502 | $ | 13,617 | $ | 31,542 | $ | 159,421 | $ | 10,922 | ||||||||||
(1) | See Note 9 to our consolidated financial statements for a discussion of our long-term debt. | |
(2) | Interest payments have been calculated by applying the interest rate of 4.5% effective at June 30, 2011, on our revolving credit facility debt and 5.4% to the outstanding term debt balance at June 30, 2011. | |
(3) | Operating lease obligations are for office space and equipment. | |
(4) | See Note 8 to our consolidated financial statements for a discussion of our asset retirement obligations. |
Off-Balance Sheet Arrangements
From time to time, we enter into off-balance sheet arrangements and transactions that can give rise
to off-balance sheet obligations. As of June 30, 2011, the off-balance sheet arrangements and
transactions that we have entered into include operating lease agreements. We do not believe that
these arrangements are reasonably likely to materially affect our liquidity or availability of, or
requirements for, capital resources.
Item 3. Quantitative and qualitative disclosures about market risk.
Some of the information below contains forwardlooking statements. The primary objective of the
following information is to provide forward-looking quantitative and qualitative information about
our potential exposure to market risks. The term market risk refers to the risk of loss arising
from adverse changes in oil and gas prices and other related factors. The disclosure is not meant
to be a precise indicator of expected future losses, but rather an indicator of reasonably possible
losses. This forward-looking information provides an indicator of how we view and manage our
ongoing market risk exposures. Our market risk sensitive instruments were entered into for
commodity derivative and investment purposes, not for trading purposes.
Commodity Price Risk
Given the current economic outlook, we expect the commodity prices to remain volatile. Even modest
decreases in commodity prices can materially affect our revenues and cash flow. In addition, if
commodity prices remain suppressed for a significant amount of time, we could be required under
successful efforts accounting rules to perform a write down of our oil and gas properties.
We may
enter into financial swaps and collars to mitigate the risk of commodity price fluctuations.
We do not designate such instruments as cash flow hedges. Accordingly, we record open commodity
derivative positions on our consolidated balance sheets at fair value and recognize changes in such
fair values as income (expense) on our consolidated statements of operations as they occur.
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At June 30, 2011, we had the following commodity derivative positions outstanding:
Natural Gas | Period | MMBTU/day | Price per MMBTU | |||||||||||||
Collars |
Jul 2011 - Dec 2011 | 2,143 | $ | 5.37 - $7.43 | ||||||||||||
Jan 2012 - Dec 2012 | 1,910 | $ | 5.00 - $8.65 | |||||||||||||
Swaps |
Jul 2011 - Dec 2011 | 113 | $ | 5.98 | ||||||||||||
Jan 2012 - Dec 2012 | 100 | $ | 6.15 |
Crude Oil | Period | Bbls/day | Price per Bbl | |||||||||||||
Collars |
Jul 2011 - Dec 2011 | 997 | $ | 71.44 - $100.74 | ||||||||||||
Jan 2012 - Dec 2012 | 312 | $ | 85.21 - $108.69 | |||||||||||||
Swaps |
Jul 2011 - Dec 2011 | 43 | $ | 85.09 | ||||||||||||
Floors sold (put) |
Jul 2011 - Dec 2011 | 147 | $ | 60.00 | ||||||||||||
Jan 2012 - Dec 2012 | 50 | $ | 55.00 | |||||||||||||
Floors purchased (put) |
July 2011 - Sep 2011 | 935 | $ | 84.14 | ||||||||||||
Oct 2011 - Dec 2011 | 1260 | $ | 84.37 | |||||||||||||
Jan 2012 - Dec 2012 | 153 | $ | 80.00 |
At June 30, 2011, and December 31, 2010, the fair value of our open derivative contracts was a net
liability of approximately $945,000 and $778,000, respectively.
Bank of Montreal and KeyBank National Association are currently the only counterparties to our
commodity derivatives positions. We are exposed to credit losses in the event of nonperformance by
the counterparties on our commodity derivatives positions. However, we do not anticipate
nonperformance by the counterparties over the term of the commodity derivatives positions. Bank of
Montreal is the administrative agent and a participant in our revolving credit facility, and
KeyBank is a participant in our revolving credit facility, and the collateral for the outstanding
borrowings under our revolving credit facility is also used as collateral for our commodity derivatives.
Unrealized gains and losses, at fair value, are included on our consolidated balance sheets as
current or non-current assets or liabilities based on the anticipated timing of cash settlements
under the related contracts. Changes in the fair value of our commodity derivative contracts are
recorded in earnings as they occur and included in other income (expense) on our consolidated
statements of operations. We estimate the fair values of swap contracts based on the present value
of the difference in exchange-quoted forward price curves and contractual settlement prices
multiplied by notional quantities. We internally valued the collar, call, and put contracts using
industry-standard option pricing models and observable market inputs. We use our internal
valuations to determine the fair values of the contracts that are reflected on our consolidated
balance sheets. Realized gains and losses are also included in other income (expense) on our
consolidated statements of operations.
For the three and six months ended June 30, 2011, we recognized a gain of $2.7 million and a loss
$674,000, respectively, related to oil and natural gas derivative contracts, which included
$517,000 and $509,000, respectively, of realized loss from contracts settled in cash, and $3.2
million of unrealized gains and $166,000 of unrealized losses related to unsettled contracts.
Unrealized gains and losses are based on the changes in the fair value of derivative instruments
covering positions beyond June 30, 2011. During the three and six months ended June 30, 2010, we
recognized a gain of $1.3 million and $2.4 million, respectively, related to oil and natural gas
derivative contracts, which included $100,000 and $3.1 million, respectively, of realized gain from
contracts settled in cash, and $1.2 million in unrealized gains and $700,000 in unrealized losses,
respectively, related to unsettled contracts. Unrealized gains and losses for the 2010 period are
based on the changes in the fair value of derivative instruments covering positions beyond June 30,
2010.
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Table of Contents
Item 4. Controls and procedures.
Evaluation of disclosure controls and procedures
We maintain disclosure controls and procedures that are designed to ensure that information
required to be disclosed in the reports we file under the Securities Exchange Act of 1934, as
amended (the Exchange Act), are recorded, processed, summarized and reported within the time
periods specified in the SECs rules and forms. Such controls include those designed to ensure that
information for disclosure is accumulated and communicated to management, including the Chairman
and Chief Executive Officer (CEO) and Chief Financial Officer (CFO), as appropriate, to allow
timely decisions regarding required disclosure.
Our management, with the participation of our CEO and CFO, has evaluated the effectiveness of our
disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) as of June
30, 2011. Based on this evaluation, the CEO and CFO have concluded that, as of June 30, 2011, our
disclosure controls and procedures were effective to ensure that information required to be
disclosed by us in the reports that we file or submit under the Exchange Act is (1) recorded,
processed, summarized and reported within the time periods specified in the SECs rules and forms,
and (2) accumulated and communicated to our management, including our CEO and CFO, as appropriate
to allow timely decisions regarding required disclosure.
On April 13, 2011, we acquired all of the outstanding stock of NGAS Resources, Inc. (NGAS) and on
May 3, 2011 we acquired all of the outstanding stock of NuLoch Resources, Inc. (NuLoch). In
connection with integrating NGAS and NuLoch, we are evaluating and, where necessary, implementing
changes in controls and procedures at NGAS and NuLoch as the integration proceeds. This process may
result in additions or changes to our internal control over financial reporting. Except for the
acquisitions, there were no other changes in our internal control over financial reporting during
the quarter ended June 30, 2011, that materially affected, or are reasonably likely to materially
affect, our internal controls
Internal control over financial reporting
There were no changes made in our internal control over financial reporting (as defined in Rule
13a-15(f) under the Exchange Act) during the six months ended June 30, 2011, that have materially
affected, or are reasonably likely to materially affect, our internal control over financial
reporting.
Limitations inherent in all controls
Our management, including the CEO and CFO, recognizes that the disclosure controls and procedures
and internal controls (discussed above) cannot prevent all errors or all attempts at fraud. Any
controls system, no matter how well crafted and operated, can only provide reasonable, and not
absolute, assurance of achieving the desired control objectives. Because of the inherent
limitations in any control system, no evaluation or implementation of a control system can provide
complete assurance that all control issues and all possible instances of fraud have been or will be
detected.
PART II. OTHER INFORMATION
Item 1. Legal Proceedings.
There have been no material developments in the legal proceedings described in Part I, Item 3.
Legal Proceedings of our Annual Report on Form 10-K, as amended, for the year ended December 31,
2010.
Item 1A. Risk factors.
In addition to the other information set forth in this report, you should carefully consider the
risks discussed in the following reports that we have filed with the SEC, which risks could
materially affect our business, financial condition and results of operations: Annual Report on
Form 10-K, as amended, for the year ended December 31, 2010, under the headings Items 1. and 2.
Business and Properties Markets and Customers; Competition; and Regulation, Item 1A. Risk
Factors, and Item 7A. Quantitative and Qualitative Disclosures about Market Risk and Quarterly
Report on Form 10-Q for the quarter ended March 31, 2011, under the headings Item 1A. Risk
Factors.
Except as provided below, there have been no material changes to the risk factors discussed in our
Annual Report on Form 10-K, as amended, for the year ended December 31, 2010 and Quarterly Report
on Form 10-Q for the quarter ended March 31, 2011, which is accessible on the SECs website at
www.sec.gov and our website at www.magnumhunterresourcess.com.
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Table of Contents
Item 2. Unregistered Sales of Equity Securities and the Use of Proceeds.
Recent Sales of Unregistered Securities
During the six months ended June 30, 2011, the Company sold from time to time an aggregate of
801,980 shares of its common stock pursuant to the exercise of certain warrants, as follows:
(a) The Company sold an aggregate of 771,812 shares of its common stock pursuant to the
exercise of certain warrants issued by the Company in 2006, at an exercise price of $3.00 per
share, for total gross proceeds of approximately $2,315,416. The warrants were issued by the
Company in connection with a private placement by the Company of units, consisting of shares
of common stock and warrants to purchase shares of common stock, to fund the purchase of
certain assets by the Company.
(b) The Company sold an aggregate of 30,168 shares of common stock pursuant to the
exercise of certain warrants issued by the Company in November 2009, at an exercise price of
$2.50 per share, for total gross proceeds of approximately $75,420. The warrants were issued
by the Company in connection with an offering by the Company of units, consisting of shares
of common stock and warrants to purchase shares of common stock, to a limited number of
investors for cash, which was registered under the Securities Act. These investors consisted
of certain directors and officers of the Company and certain of their friends and associates.
All the shares described above were issued or sold by the Company in reliance on the exemption from
registration afforded by Section 4(2) of the Securities Act and/or Regulation D promulgated
thereunder.
ITEM 6. EXHIBITS
Exhibit | ||
Number | Description | |
2.1
|
Arrangement Agreement between the Registrant, Exchangeco, and NuLoch (Incorporated by reference from the Registrants Current Report on Form 8-K filed on January 25, 2011).+ | |
2.2
|
Purchase and Sale Agreement by and among Triad Hunter, LLC and Windsor Marcellus (Incorporated by reference from the Registrants Current Report on Form 8-K filed on April 12, 2011.)+ | |
2.3
|
Purchase and Sale Agreement by and among Triad Hunter, LLC, Quest Eastern Resource LLC and PostRock Energy Corporation (Incorporated by reference from the Registrants Current Report on Form 8-K filed on June 21, 2011). + | |
2.4 |
Purchase and Sale Agreement by and among Eagle Operating Inc., Williston Hunter ND, LLC and for the limited purposes set forth therein, Magnum Hunter Resources Corporation (Incorporated by reference from the Registrant Current Report on Form 8-K filed on August 5, 2010).+ | |
3.1
|
Restated Certificate of Incorporation of the Registrant, filed February 13, 2002 (Incorporated by reference from the Registrants Registration Statement on Form SB-2 filed on March 21, 2006). | |
3.1.1
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed May 8, 2003 (Incorporated by reference from the Registrants Registration Statement on Form SB-2 filed on March 21, 2006). | |
3.1.2
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed June 6, 2005 (Incorporated by reference from the Registrants Registration Statement on Form SB-2 filed on March 21, 2006). | |
3.1.3
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed July 18, 2007 (Incorporated by reference from the Registrants quarterly report on Form 10-QSB filed on August 14, 2007). | |
3.1.4
|
Certificate of Ownership and Merger Merging Magnum Hunter Resources Corporation with and into Petro Resources Corporation, filed July 13, 2009 (Incorporated by reference from the Registrants current report on Form 8-K filed on July 14, 2009). | |
3.1.5
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed November 3, 2010 (Incorporated by reference from the Registrants current report on Form 8-K filed on November 2, 2010). | |
3.2
|
Amended and Restated Bylaws of the Registrant, dated March 15, 2001 as amended on April 14, 2006, October 12, 2006, and May 26, 2011. | |
4.1
|
Form of certificate for common stock (Incorporated by reference from the Registrants 2010 annual report on Form 10-K filed on February 18, 2011). | |
4.2
|
Certificate of Designation of Rights and Preferences of 10.25% Series C Cumulative Perpetual Preferred Stock, dated December 10, 2009 (Incorporated by reference from the Registrants Registration Statement on Form 8-A filed on December 10, 2009). | |
4.2.1
|
Certificate of Amendment of Certificate of Designation of Rights and Preferences of 10.25% Series C Cumulative Perpetual Preferred Stock, dated August 2, 2010 (Incorporated by reference from the Registrants Quarterly Report on Form 10-Q filed on May 9, 2011). |
40
Table of Contents
Exhibit | ||
Number | Description | |
4.2.2
|
Certificate of Amendment of Certificate of Designation of Rights and Preferences of 10.25% Series C Cumulative Perpetual Preferred Stock, dated September 8, 2010 (Incorporated by reference from the Registrants current report on Form 8-K filed on September 15, 2010). | |
4.2.3
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed March 16, 2011 (Incorporated by reference from the Registrants current report on Form 8-K filed on March 17, 2011). | |
4.3 |
Certificate of Designation of Rights and Preferences of 8.0% Series D Cumulative Preferred Stock (Incorporated by reference from the Registrants Current Report on Form 8-K filed on March 17, 2011). | |
10.1
|
Second Amended and Restated Credit Agreement (Incorporated by reference from the Registrants Current Report on Form 8-K filed on April 14, 2011). + | |
10.2
|
First Amendment to Second Amended and Restated Credit Agreement (Incorporated by reference from the Registrants Current Report on Form 8-K filed on July 19, 2011). + | |
10.3
|
Amendment to the Magnum Hunter Resources Corporation Amended and Restated Stock Incentive Plan (Incorporated by reference from the Registrants Proxy Statement on Annex C of Schedule 14A filed on April 1, 2011). | |
12.1
|
Ratio of Earnings to Fixed Charges | |
31.1
|
Certification of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |
31.2
|
Certification of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |
32.1
|
Certification of the Chief Executive Officer and Chief Financial Officer provided pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | |
101.INS**
|
XBRL Instance Document | |
101.SCH**
|
XBRL Taxonomy Extension Schema Document | |
101.CAL**
|
XBRL Taxonomy Extension Calculation Linkbase Document | |
101.LAB**
|
XBRL Taxonomy Extension Label Linkbase Document | |
101.PRE**
|
XBRL Taxonomy Extension Presentation Linkbase Document | |
101.DEF**
|
XBRL Taxonomy Extension Definition Presentation Linkbase Document |
** | These exhibits are furnished herewith. In accordance with Rule 406T of Regulation S-T, these exhibits are not deemed to be filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are not deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under these sections. | |
+ | The exhibits and the schedules to this exhibit have been omitted pursuant to Item 601(b)(2) of Regulation S-K and will be provided to the SEC upon request. |
41
Table of Contents
SIGNATURES
In accordance with the requirements of the Exchange Act, the registrant caused this report to
be signed on its behalf by the undersigned, thereto duly authorized.
MAGNUM HUNTER RESOURCES CORPORATION |
||||
Date: August 8, 2011 | /s/ Gary C. Evans | |||
Gary C. Evans, | ||||
Chairman and Chief Executive Officer | ||||
Date: August 8, 2011 | /s/ Ronald D. Ormand | |||
Ronald D. Ormand, | ||||
Executive Vice President and Chief Financial Officer |
||||
Exhibit Index
Exhibit | ||
Number | Description | |
2.1
|
Arrangement Agreement between the Registrant, Exchangeco, and NuLoch (Incorporated by reference from the Registrants Current Report on Form 8-K filed on January 25, 2011).+ | |
2.2
|
Purchase and Sale Agreement by and among Triad Hunter, LLC and Windsor Marcellus (Incorporated by reference from the Registrants Current Report on Form 8-K filed on April 12, 2011.)+ | |
2.3
|
Purchase and Sale Agreement by and among Triad Hunter, LLC, Quest Eastern Resource LLC and PostRock Energy Corporation (Incorporated by reference from the Registrants Current Report on Form 8-K filed on June 21, 2011). + | |
2.4 |
Purchase and Sale Agreement by and among Eagle Operating Inc., Williston Hunter ND, LLC and for the limited purposes set forth therein, Magnum Hunter Resources Corporation (Incorporated by reference from the Registrant Current Report on Form 8-K filed on August 5, 2010).+ | |
3.1
|
Restated Certificate of Incorporation of the Registrant, filed February 13, 2002 (Incorporated by reference from the Registrants Registration Statement on Form SB-2 filed on March 21, 2006). | |
3.1.1
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed May 8, 2003 (Incorporated by reference from the Registrants Registration Statement on Form SB-2 filed on March 21, 2006). | |
3.1.2
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed June 6, 2005 (Incorporated by reference from the Registrants Registration Statement on Form SB-2 filed on March 21, 2006). | |
3.1.3
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed July 18, 2007 (Incorporated by reference from the Registrants quarterly report on Form 10-QSB filed on August 14, 2007). | |
3.1.4
|
Certificate of Ownership and Merger Merging Magnum Hunter Resources Corporation with and into Petro Resources Corporation, filed July 13, 2009 (Incorporated by reference from the Registrants current report on Form 8-K filed on July 14, 2009). | |
3.1.5
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed November 3, 2010 (Incorporated by reference from the Registrants current report on Form 8-K filed on November 2, 2010). | |
3.2
|
Amended and Restated Bylaws of the Registrant, dated March 15, 2001 as amended on April 14, 2006, October 12, 2006, and May 26, 2011. | |
4.1
|
Form of certificate for common stock (Incorporated by reference from the Registrants 2010 annual report on Form 10-K filed on February 18, 2011). | |
4.2
|
Certificate of Designation of Rights and Preferences of 10.25% Series C Cumulative Perpetual Preferred Stock, dated December 10, 2009 (Incorporated by reference from the Registrants Registration Statement on Form 8-A filed on December 10, 2009). | |
4.2.1
|
Certificate of Amendment of Certificate of Designation of Rights and Preferences of 10.25% Series C Cumulative Perpetual Preferred Stock, dated August 2, 2010 (Incorporated by reference from the Registrants quarterly report on Form 10-Q filed on August 12, 2010). (Incorporated by reference from the Registrants Quarterly Report on Form 10-Q filed on May 9, 2011). |
42
Table of Contents
Exhibit | ||
Number | Description | |
4.2.2
|
Certificate of Amendment of Certificate of Designation of Rights and Preferences of 10.25% Series C Cumulative Perpetual Preferred Stock, dated September 8, 2010 (Incorporated by reference from the Registrants current report on Form 8-K filed on September 15, 2010). | |
4.2.3
|
Certificate of Amendment of Certificate of Incorporation of the Registrant, filed March 16, 2011 (Incorporated by reference from the Registrants current report on Form 8-K filed on March 17, 2011). | |
4.3 |
Certificate of Designation of Rights and Preferences of 8.0% Series D Cumulative Preferred Stock (Incorporated by reference from the Registrants Current Report on Form 8-K filed on March 17, 2011). | |
10.1
|
Second Amended and Restated Credit Agreement (Incorporated by reference from the Registrants Current Report on Form 8-K filed on April 14, 2011). + | |
10.2
|
First Amendment to Second Amended and Restated Credit Agreement (Incorporated by reference from the Registrants Current Report on Form 8-K filed on July 19, 2011). + | |
10.3
|
Amendment to the Magnum Hunter Resources Corporation Amended and Restated Stock Incentive Plan (Incorporated by reference from the Registrants Proxy Statement on Annex C of Schedule 14A filed on April 1, 2011). | |
12.1
|
Ratio of Earnings to Fixed Charges | |
31.1
|
Certification of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |
31.2
|
Certification of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 | |
32.1
|
Certification of the Chief Executive Officer and Chief Financial Officer provided pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 | |
101.INS**
|
XBRL Instance Document | |
101.SCH**
|
XBRL Taxonomy Extension Schema Document | |
101.CAL**
|
XBRL Taxonomy Extension Calculation Linkbase Document | |
101.LAB**
|
XBRL Taxonomy Extension Label Linkbase Document | |
101.PRE**
|
XBRL Taxonomy Extension Presentation Linkbase Document | |
101.DEF**
|
XBRL Taxonomy Extension Definition Linkbase Document |
** | These exhibits are furnished herewith. In accordance with Rule 406T of Regulation S-T, these exhibits are not deemed to be filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are not deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under these sections. | |
+ | The exhibits and the schedules to this exhibit have been omitted pursuant to Item 601(b)(2) of Regulation S-K and will be provided to the SEC upon request. |
43