Attached files
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EXCEL - IDEA: XBRL DOCUMENT - CUBIC ENERGY INC | Financial_Report.xls |
EX-31.2 - EX-31.2 - CUBIC ENERGY INC | a14-24834_1ex31d2.htm |
EX-32.1 - EX-32.1 - CUBIC ENERGY INC | a14-24834_1ex32d1.htm |
EX-32.2 - EX-32.2 - CUBIC ENERGY INC | a14-24834_1ex32d2.htm |
EX-31.1 - EX-31.1 - CUBIC ENERGY INC | a14-24834_1ex31d1.htm |
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q/A
(Amendment No. 1)
x QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
for the quarterly period ended March 31, 2014
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 001-34144
CUBIC ENERGY, INC.
(Exact name of registrant as specified in its charter)
Texas |
|
87-0352095 |
(State or other jurisdiction of incorporation) |
|
(IRS Employer Identification No.) |
9870 Plano Road
Dallas, TX 75238
(Address of principal executive offices)
(972) 686-0369
(Registrants telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x 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 x 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. See definition of large accelerated filer, accelerated filer and smaller reporting company in Rule 12b-2 of the Exchange Act.
Large accelerated filer o |
|
Accelerated filer o |
Non-accelerated filer o |
|
Smaller reporting company x |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No x
As of May 7, 2014, the registrant had 77,505,908 shares of common stock, $0.05 par value, outstanding.
Explanatory Note
This amendment to Quarterly Report on Form 10-Q/A amends the condensed consolidated financial statements included in this quarterly report on Form 10-Q/A to give effect to a change in accounting for warrants at fair value. The warrants liability related to the warrants issued in connection with the issuance of the Notes (as defined in Note F to the Condensed Consolidated Financial Statements) and the previously outstanding warrants issued to Wells Fargo Energy Capital, Inc. (WFEC) have been restated for the quarter ended March 31, 2014 and the nine-month period ended March 31, 2014 at their fair value. These warrants include certain anti-dilution provisions, which provide for exercise price adjustments in the event that any common stock equivalents are issued at an effective price per share that is less than the exercise price of the warrants. The Company recorded the fair value of the WFEC warrants as of July 1, 2013 as an out of period adjustment to income and a corresponding liability. The warrants issued in connection with the issuance of the Notes were issued during the quarter ended December 31, 2013, and are recorded as of the issuance date. In addition, the Companys asset retirement obligation (ARO) has been restated, due to changes in estimates of the ARO related to the properties acquired by the Company during the quarter ended December 31, 2013. Certain other corrections and reclassifications have been made but are not described in detail due to their immaterial nature.
Special note regarding forward-looking statements
This quarterly report on Form 10-Q/A contains forward-looking statements. All statements, other than statements of historical facts, are forward-looking statements. These forward-looking statements relate to, among other things, the following: our future financial and operating performance and results; our business strategy; market prices; and our plans and forecasts.
Forward-looking statements are identified by use of terms and phrases such as may, expect, estimate, project, plan, believe, intend, achievable, anticipate, will, continue, potential, should, could and similar words and phrases. Although we believe that the expectations reflected in these forward-looking statements are reasonable, they do involve certain assumptions, risks and uncertainties. Our actual results could differ materially from those anticipated in these forward-looking statements. You should consider carefully the statements in the Risk Factors section of our Annual Report on Form 10-K/A for our fiscal year ended June 30, 2013 and other sections of this report, which describe factors that could cause our actual results to differ from those set forth in the forward-looking statements, including, but not limited to, the following factors:
· our ability to generate sufficient cash flow from operations, borrowings or other sources to enable us to service our debt and fully develop our undeveloped acreage positions;
· our ability to integrate our recently consummated acquisitions;
· the volatility in commodity prices for oil and natural gas;
· the possibility that the industry may be subject to future regulatory or legislative actions (including additional taxes);
· the presence or recoverability of estimated oil and natural gas reserves and the actual future production rates and associated costs;
· the ability to replace oil and natural gas reserves;
· lease or title issues or defects to our oil and gas properties;
· environmental risks;
· drilling and operating risks;
· exploration and development risks;
· competition, including competition for acreage in oil and natural gas producing areas;
· managements ability to execute our plans to meet our goals;
· our ability to retain key members of senior management;
· our ability to obtain goods and services, such as drilling rigs and other oilfield equipment, and access to adequate gathering systems and pipeline take-away capacity, to execute our drilling program;
· general economic conditions, whether internationally, nationally or in the regional and local market areas in which we do business, may be less favorable than expected, including that the United States economic slow-down might continue to negatively affect the demand for natural gas, oil and natural gas liquids;
· continued hostilities in the Middle East and other sustained military campaigns or acts of terrorism or sabotage; and
· other economic, competitive, governmental, legislative, regulatory, geopolitical and technological factors that may negatively impact our business, operations or pricing.
All forward-looking statements are expressly qualified in their entirety by the cautionary statements in this paragraph and elsewhere in this document. Other than as required under the securities laws, we do not assume a duty to update these forward-looking statements, whether as a result of new information, subsequent events or circumstances, changes in expectations or otherwise.
CUBIC ENERGY, INC.
PART I - FINANCIAL INFORMATION
CUBIC ENERGY, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
|
|
March 31, |
|
|
| ||
|
|
2014 (unaudited) |
|
June 30, 2013 |
| ||
|
|
(Restated) |
|
|
| ||
Assets |
|
|
|
|
| ||
Current assets: |
|
|
|
|
| ||
Cash and cash equivalents |
|
$ |
9,357,481 |
|
$ |
260,576 |
|
Accounts receivable - trade |
|
2,673,630 |
|
586,174 |
| ||
Due from affiliate |
|
|
|
1,678 |
| ||
Other prepaid expenses |
|
514,952 |
|
156,892 |
| ||
Total current assets |
|
12,546,063 |
|
1,005,320 |
| ||
Property and equipment: |
|
|
|
|
| ||
Oil and gas properties, full cost method: |
|
|
|
|
| ||
Proved properties (including wells and related equipment and facilities) |
|
123,629,500 |
|
33,828,079 |
| ||
Unproven properties |
|
9,331,147 |
|
|
| ||
Office and other equipment |
|
47,810 |
|
30,227 |
| ||
Property and equipment, at cost |
|
133,008,457 |
|
33,858,306 |
| ||
Less accumulated depreciation, depletion and amortization |
|
24,860,672 |
|
19,134,081 |
| ||
Property and equipment, net |
|
108,147,785 |
|
14,724,225 |
| ||
Other assets: |
|
|
|
|
| ||
Cash restricted under loan agreement |
|
5,000,000 |
|
|
| ||
Deferred loan costs, net |
|
2,376,430 |
|
|
| ||
Prepaid drilling costs |
|
1,171,106 |
|
|
| ||
Acquisition costs - deposits |
|
|
|
2,300,000 |
| ||
Total other assets |
|
8,547,536 |
|
2,300,000 |
| ||
|
|
|
|
|
| ||
Total assets |
|
$ |
129,241,384 |
|
$ |
18,029,545 |
|
|
|
|
|
|
|
|
|
Liabilities and stockholders deficit |
|
|
|
|
| ||
Current liabilities: |
|
|
|
|
| ||
Notes payable - WFEC - term note |
|
$ |
|
|
$ |
5,000,000 |
|
Note payable - WFEC - revolver |
|
|
|
20,865,110 |
| ||
Notes payable - due to affiliate |
|
|
|
2,000,000 |
| ||
Fair value of derivatives |
|
5,949,967 |
|
|
| ||
Due to affiliates |
|
597,253 |
|
2,000,000 |
| ||
Accounts payable and accrued expenses |
|
3,744,190 |
|
1,331,609 |
| ||
Total current liabilities |
|
10,291,410 |
|
31,196,719 |
| ||
Long-term liabilities |
|
|
|
|
| ||
Long-term debt, Senior Notes |
|
40,250,755 |
|
|
| ||
Long-term debt, WFEC note |
|
24,880,936 |
|
|
| ||
Total long-term liabilities |
|
65,131,691 |
|
|
| ||
Asset retirement obligation |
|
1,802,958 |
|
|
| ||
Warrants liability |
|
21,393,340 |
|
|
| ||
Fair value of derivatives |
|
38,325,396 |
|
|
| ||
|
|
|
|
|
| ||
Total liabilities |
|
|
136,944,795 |
|
|
31,196,719 |
|
|
|
|
|
|
| ||
Redeemable preferred stock - Series C, authorized 98,751.823 shares; $0.01 stated value, voting, redeemable at $0.01; 98,751.823 shares issued and outstanding at March 31, 2014 and none at June 30, 2013 |
|
988 |
|
|
| ||
Stockholders equity (deficit): |
|
|
|
|
| ||
Preferred stock - $.01 par value; authorized 10,000,000 shares; |
|
|
|
|
| ||
Preferred stock - 8% Series A, authorized 165,000 shares $100 stated value, voting, redeemable at $120, convertible at $1.20 per common share, canceled February 2014 |
|
|
|
1,181 |
| ||
Additional paid-in capital - preferred stock - Series A (see Note D) |
|
|
|
11,810,119 |
| ||
Preferred stock 9.5% Series B, authorized 35,000 shares $1,000 stated value, voting, convertible at $0.50 per common share; with 16,540.589 outstanding at March 31, 2014 and none at June 30, 2013 |
|
3,043,468 |
|
|
| ||
Additional paid-in capital - preferred stock - Series B (see Note D) |
|
12,107,907 |
|
|
| ||
Common stock - $.05 par value; authorized 200,000,000 shares; issued and outstanding 77,505,908 shares at March 31, 2014 and 77,360,908 shares at June 30, 2013 |
|
3,875,297 |
|
3,868,047 |
| ||
Additional paid-in capital - common stock |
|
56,954,045 |
|
56,910,545 |
| ||
Accumulated deficit |
|
(83,685,116 |
) |
(85,757,066 |
) | ||
Total stockholders deficit |
|
(7,704,399 |
) |
(13,167,174 |
) | ||
|
|
$ |
129,241,384 |
|
$ |
18,029,545 |
|
The accompanying notes are an integral part of these statements.
CUBIC ENERGY, INC.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(unaudited)
|
|
Three months ended |
|
Nine months ended |
| ||||||||
|
|
March 31, |
|
March 31, |
| ||||||||
|
|
2014 |
|
2013 |
|
2014 |
|
2013 |
| ||||
Revenues: |
|
|
|
|
|
|
|
|
| ||||
Oil and gas sales |
|
$ |
5,219,837 |
|
$ |
968,980 |
|
$ |
10,841,391 |
|
$ |
3,012,016 |
|
Total revenues |
|
5,219,837 |
|
968,980 |
|
10,841,391 |
|
3,012,016 |
| ||||
Costs and expenses: |
|
|
|
|
|
|
|
|
| ||||
Oil and gas production and operating costs |
|
3,105,635 |
|
325,906 |
|
6,409,143 |
|
1,579,221 |
| ||||
Accretion of asset retirement obligations |
|
113,318 |
|
|
|
226,635 |
|
|
| ||||
General and administrative expenses |
|
1,444,340 |
|
562,692 |
|
4,735,950 |
|
1,581,451 |
| ||||
Depreciation, depletion and non-loan-related amortization |
|
2,685,149 |
|
751,075 |
|
5,726,591 |
|
2,537,883 |
| ||||
Total operating costs and expenses |
|
7,348,442 |
|
1,639,673 |
|
17,098,319 |
|
5,698,555 |
| ||||
Operating loss |
|
(2,128,605 |
) |
(670,693 |
) |
(6,256,928 |
) |
(2,686,539 |
) | ||||
Non-operating income (expense): |
|
|
|
|
|
|
|
|
| ||||
Other income |
|
3,933 |
|
536 |
|
9,427 |
|
666,074 |
| ||||
Interest expense |
|
(5,695,528 |
) |
(1,258,240 |
) |
(12,580,873 |
) |
(2,110,403 |
) | ||||
Loss on derivative contracts |
|
(5,601,123 |
) |
|
|
(12,221,932 |
) |
|
| ||||
Amortization of loan costs |
|
(233,492 |
) |
(260,000 |
) |
(464,390 |
) |
(260,000 |
) | ||||
Gain on acquisition of assets at fair market value |
|
|
|
|
|
22,578,000 |
|
|
| ||||
Change in fair value of warrants liability |
|
5,547,121 |
|
|
|
12,017,693 |
|
|
| ||||
Total non-operating income (expense) |
|
(5,979,089 |
) |
(1,517,704 |
) |
9,337,925 |
|
(1,704,329 |
) | ||||
Income (loss) before income taxes |
|
(8,107,694 |
) |
(2,188,397 |
) |
3,080,997 |
|
(4,390,868 |
) | ||||
Provision for income taxes |
|
|
|
|
|
|
|
|
| ||||
Net income (loss) |
|
$ |
(8,107,694 |
) |
$ |
(2,188,397 |
) |
$ |
3,080,997 |
|
$ |
(4,390,868 |
) |
Dividends on preferred shares |
|
(387,458 |
) |
(228,500 |
) |
(1,009,047 |
) |
(681,800 |
) | ||||
Net income (loss) attributable to common stockholders |
|
$ |
(8,495,152 |
) |
$ |
(2,416,897 |
) |
$ |
2,071,950 |
|
$ |
(5,072,668 |
) |
Net income (loss) per common share - basic |
|
$ |
(0.11 |
) |
$ |
(0.03 |
) |
$ |
0.03 |
|
$ |
(0.06 |
) |
Net income (loss) per common share - diluted |
|
$ |
(0.11 |
) |
$ |
(0.03 |
) |
$ |
0.02 |
|
$ |
(0.06 |
) |
Weighted average common shares outstanding - basic |
|
77,500,392 |
|
77,265,047 |
|
77,479,184 |
|
77,232,049 |
| ||||
Weighted average common shares outstanding - diluted |
|
77,500,392 |
|
77,265,047 |
|
93,756,501 |
|
77,232,049 |
|
The accompanying notes are an integral part of these statements.
CUBIC ENERGY, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
|
|
Nine months ended |
| ||||
|
|
March 31, |
| ||||
|
|
2014 |
|
2013 |
| ||
Cash flows from operating activities: |
|
|
|
|
| ||
Net income (loss) |
|
$ |
3,080,997 |
|
$ |
(4,390,868 |
) |
Adjustments to reconcile net income (loss) to cash provided (used) by operating activities: |
|
|
|
|
| ||
Depreciation, depletion and amortization |
|
5,726,591 |
|
3,440,043 |
| ||
Bargain purchase gain |
|
(22,578,000 |
) |
|
| ||
Accretion of asset retirement obligation |
|
226,635 |
|
|
| ||
Amortization of loan costs |
|
464,390 |
|
|
| ||
Amortization of debt discount |
|
5,585,553 |
|
|
| ||
Unrealized loss on derivative contracts |
|
12,221,932 |
|
|
| ||
Settlement of derivative swaps |
|
(19,935 |
) |
|
| ||
Change in fair value of warrants liability |
|
(12,017,693 |
) |
|
| ||
Paid-in-kind interest expense |
|
2,834,798 |
|
15,223 |
| ||
Stock issued for compensation |
|
50,750 |
|
17,366 |
| ||
Change in assets and liabilities: |
|
|
|
|
| ||
(Increase) decrease in accounts receivable - trade |
|
(2,087,456 |
) |
1,847,125 |
| ||
(Increase) decrease in due from affiliates |
|
598,931 |
|
|
| ||
(Increase) decrease in other prepaid expenses |
|
(358,060 |
) |
28,578 |
| ||
Increase (decrease) in accounts payable and accrued expenses |
|
2,375,609 |
|
(709,170 |
) | ||
Increase in due to affiliates |
|
|
|
8,016 |
| ||
Net cash provided (used) by operating activities |
|
$ |
(3,894,958 |
) |
$ |
256,313 |
|
Cash flows from investing activities: |
|
|
|
|
| ||
Acquisition and development of oil and gas properties |
|
(8,049,680 |
) |
(431,843 |
) | ||
Prepaid drilling costs |
|
(1,171,106 |
) |
|
| ||
Increase in capital portion of due to affiliates |
|
|
|
1,602 |
| ||
Purchase of office equipment |
|
|
|
(1,807 |
) | ||
Reimbursement of advances on development costs |
|
|
|
10,079,583 |
| ||
Net cash paid for acquisitions of properties |
|
(64,278,148 |
) |
|
| ||
Net cash provided (used) by investing activities |
|
$ |
(73,498,934 |
) |
$ |
9,647,535 |
|
Cash flows from financing activities: |
|
|
|
|
| ||
Proceeds from long-term debt |
|
31,831,392 |
|
|
| ||
Proceeds from issuance of warrants |
|
33,411,033 |
|
|
| ||
Proceeds from derivative contract |
|
35,091,536 |
|
|
| ||
Proceeds from revolver |
|
4,015,826 |
|
|
| ||
Increase in restricted cash |
|
(5,000,000 |
) |
|
| ||
Repayment of advances from affiliates |
|
(2,000,000 |
) |
|
| ||
Payment of long-term debt |
|
(5,000,000 |
) |
(9,134,890 |
) | ||
Settlement costs paid under derivative contract |
|
(3,018,170 |
) |
|
| ||
Loan costs incurred and other |
|
(2,840,820 |
) |
(260,000 |
) | ||
Net cash provided (used) by financing activities |
|
$ |
86,490,797 |
|
$ |
(9,394,890 |
) |
Net increase in cash and cash equivalents |
|
$ |
9,096,905 |
|
$ |
508,958 |
|
Cash and cash equivalents: |
|
|
|
|
| ||
Beginning of period |
|
260,576 |
|
275,527 |
| ||
End of period |
|
$ |
9,357,481 |
|
$ |
784,485 |
|
Other information: |
|
|
|
|
| ||
Cash interest paid on debt |
|
$ |
6,386,785 |
|
$ |
1,208,250 |
|
Non-cash investing and financing activities: |
|
|
|
|
| ||
Issuance of preferred stock in connection with acquisition of properties |
|
368,000 |
|
|
| ||
Note payable and accrued interest due to affiliate converted to preferred stock |
|
2,114,986 |
|
|
| ||
Increase in prepaid drilling credit for acquisition and development of oil and gas properties |
|
|
|
562,325 |
| ||
Preferred stock dividends accrued |
|
1,009,047 |
|
681,800 |
| ||
Conversion of accrued dividend to preferred stock |
|
305,160 |
|
670,400 |
| ||
Non-cash additions to oil and gas properties through ARO |
|
1,576,323 |
|
|
|
The accompanying notes are an integral part of these statements.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Note A Organization:
Cubic Energy, Inc., a Texas corporation (the Company or Cubic), has two wholly owned direct subsidiaries (Cubic Asset Holding, LLC, a Delaware limited liability company (Cubic Asset Holding), and Cubic Louisiana Holding, LLC, a Delaware limited liability company (Cubic Louisiana Holding)) and two wholly owned indirect subsidiaries (Cubic Asset LLC, a Delaware limited liability company and a direct subsidiary of Cubic Asset Holding (Cubic Asset), and Cubic Louisiana, LLC, a Delaware limited liability company and a direct subsidiary of Cubic Louisiana Holding (Cubic Louisiana)). Except where otherwise indicated, references to the Company or Cubic include its subsidiaries. The Company is an independent, upstream energy company engaged in the development and production of, and exploration for, crude oil and natural gas. The Companys oil and gas assets and activities are concentrated in Louisiana and Texas.
The Companys corporate strategy with respect to its asset acquisition and development efforts is to position the Company in low risk opportunities while building mainstream high yield reserves. The acquisition of its legacy acreage in DeSoto and Caddo Parishes, managed by Cubic Louisiana, put the Company in a reservoir rich environment in the Hosston, Cotton Valley and Bossier/Haynesville Shale formations, with additional shallow formations to exploit as well. The Company has had success on this acreage with wells drilled, achieving production from the Hosston formation, the Cotton Valley formation and the Bossier/Haynesville Shale formation. The Companys bolt-on working interests in DeSoto and Caddo Parishes, managed by Cubic Asset, expand the Companys investment in this environment.
The Companys recent acquisition of acreage in Leon and Robertson Counties, Texas, puts the Company in the additional reservoir rich environments in the Bossier, Eagle Ford, Woodbine, Austin Chalk, Buda, Glen Rose and Georgetown formations, with additional shallow formations to exploit as well.
Note B Acquisition of Properties
Acquisition of Properties from Gastar
On October 2, 2013, the Company consummated the transactions contemplated by the Purchase and Sale Agreement dated as of April 19, 2013 (the Gastar Agreement) with Gastar Exploration Texas, LP (Gastar) and Gastar Exploration USA, Inc. Pursuant to the Gastar Agreement, the Company acquired proved reserves, oil & natural gas production and undeveloped leasehold interests in Leon and Robertson Counties, Texas. The acquired properties include approximately 17,400 net acres of leasehold interests. The acquisition price paid by the Company at closing was $39,188,830, following various adjustments set forth in the Gastar Agreement, and net of the various deposits paid prior to the closing date. For purposes of allocating revenues and expenses and capital costs between Gastar and us, such amounts were netted effective January 1, 2013 and have been recorded as an adjustment to the purchase price.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Acquisition of Properties from Navasota
On September 27, 2013, the Company entered into a Purchase and Sale Agreement (the Navasota Agreement) with Navasota Resources Ltd., LLP (Navasota). On October 2, 2013, pursuant to the Navasota Agreement, the Company acquired proved reserves, oil & natural gas production and undeveloped leasehold interests in Leon and Robertson Counties, Texas. The leasehold interests acquired from Navasota generally consist of additional fractional interests in the properties acquired pursuant to the Gastar Agreement, comprising approximately 6,400 net acres. The acquisition price paid by the Company was $19,400,000, prior to certain post-closing adjustments.
Acquisition of Properties from Tauren
The Company entered into and consummated the transactions contemplated by a Purchase and Sale Agreement dated as of October 2, 2013 (the Tauren Agreement) with Tauren Exploration, Inc. (Tauren), an entity controlled by Calvin A. Wallen, III, the Chairman of the Board, President and Chief Executive Officer of the Company. Pursuant to the Tauren Agreement, the Company acquired well bores, proved reserves, oil & natural gas production and undeveloped leasehold interests in the Cotton Valley formation in DeSoto and Caddo Parishes, Louisiana. The acquired properties include approximately 5,600 net acres of leasehold interests. The acquisition price paid by the Company was $4,000,000 in cash and 2,000 shares of the Companys Series B Convertible Preferred Stock with an aggregate fair market value of $368,000 and a stated value of $2,000,000. The Tauren Agreement was unanimously approved by the Companys board of directors, excluding Mr. Wallen. This transaction resulted in a $22,578,000 bargain purchase gain for the Company that was recorded in the statement of operations for the quarter ended December 31, 2013.
|
|
|
|
Gastar Acquired |
|
Navasota Acquired |
|
Tauren Acquired |
| ||||
Purchase Price Allocation - ($000s) |
|
Total |
|
Properties |
|
Properties |
|
Properties |
| ||||
Assets acquired: |
|
|
|
|
|
|
|
|
| ||||
Unproved oil and natural gas properties |
|
$ |
7,101 |
|
$ |
6,029 |
|
$ |
1,072 |
|
$ |
|
|
Proved developed and undeveloped oil and natural gas properties |
|
$ |
89,373 |
|
$ |
42,446 |
|
19,981 |
|
26,946 |
| ||
Liabilities assumed: |
|
|
|
|
|
|
|
|
| ||||
Asset retirement obligations |
|
1,500 |
|
1,005 |
|
495 |
|
|
| ||||
Net assets acquired |
|
$ |
94,974 |
|
$ |
47,470 |
|
$ |
20,558 |
|
$ |
26,946 |
|
|
|
Nine Months |
|
Three Months |
| ||||||||
|
|
Ended March 31, |
|
Ended March 31, |
| ||||||||
*Pro forma Results of Operations |
|
2014 |
|
2013 |
|
2014 |
|
2013 |
| ||||
Oil and natural gas revenues |
|
$ |
14,676,233 |
|
$ |
16,079,533 |
|
$ |
5,219,837 |
|
$ |
5,299,903 |
|
Net income (loss) |
|
$ |
3,922,189 |
|
$ |
1,072,733 |
|
$ |
(8,495,154 |
) |
$ |
(149,689 |
) |
Basic earnings (loss) per share |
|
$ |
0.051 |
|
$ |
0.014 |
|
$ |
(0.110 |
) |
$ |
(0.002 |
) |
Diluted earnings (loss) per share |
|
$ |
0.042 |
|
$ |
0.011 |
|
$ |
(0.110 |
) |
$ |
(0.002 |
) |
* Pro forma Results of Operations include direct revenues and expenses from all acquired properties (i.e. Gastar, Navasota and Tauren), and revenues and net loss for Cubic during the respective periods.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
The Company utilized relevant market assumptions to determine fair value and allocate the purchase price, such as future commodity prices, projections of estimated natural gas and oil reserves, expectations for future development and operating costs, projections of future rates of production, expected recovery rates and market multiples for similar transactions. The Companys assessment of the fair value of the properties acquired from Tauren, along with consideration of data prepared by a third party, resulted in a fair market valuation of $26,946,000. As a result of incorporating the valuation information into the purchase price allocation, a bargain purchase gain of $22,578,000 was recognized. Because the fair market value of the acquired properties was determined to be in excess of the consideration paid, in accordance with the provisions of ASC 805-30-25-4, the Company reassessed whether it had fully identified all of the assets and liabilities obtained in the acquisition. Further, it instructed certain of its advisors to do the same. As part of its reassessment, the Company also reevaluated the consideration transferred and whether there were any non-controlling interests in the acquired property. No additional assets or liabilities were identified. The consideration transferred consisted of cash and preferred stock; no additional consideration was given, including any such consideration as contemplated by ASC 805-30-30-7. The Company had a valuation of the preferred stock performed by our advisors. It revisited the terms, assumptions and conditions used in that valuation and found that the preferred stock was appropriately valued. The Company also determined that there were no non-controlling interests in the acquired property. The bargain purchase gain was primarily attributable to the non-strategic nature of the divestiture to the seller, coupled with favorable economic trends in the industry and the geographic region in which the acquired properties are located. The Company believes the estimates used in the fair market valuation and purchase price allocation are reasonable and that the significant effects of the acquisition are properly reflected.
In connection with these acquisitions, the Company incurred expenses of $1,726,906 which are recognized in general and administrative expenses in the statement of operations.
Note C Summary of Significant Account Policies:
Basis of presentation
The accounting policies followed by the Company are set forth in the Companys financial statements that are a part of its Annual Report on Form 10-K for the fiscal year ended June 30, 2013 and should be read in conjunction with the financial statements contained herein.
The financial information included herein as of March 31, 2014, and for the three and nine month periods ended March 31, 2014, and 2013, are unaudited, pursuant to accounting principles for interim financial information generally accepted in the United States of America, and the rules of the Securities and Exchange Commission.
The Company believes that the disclosures are adequate to make the information presented not misleading. The information presented reflects all adjustments (consisting solely of normal recurring adjustments), which are, in the opinion of management, necessary for a fair statement of results for the periods.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Restatement Correction of Error
As noted, the financial information for the three and nine months ended March 31, 2014 has been restated to reflect the change in fair value of warrants liability. The Companys outstanding warrants include certain anti-dilution provisions, which provide exercise price adjustments in the event that any common stock equivalents are issued at an effective price per share that is less than the exercise price of the warrants. The fair value of the warrants liability was not recorded for the year ended June 30, 2013 or previous years. Upon exercise or expiration of a warrant, the fair value of the warrant at that time will be reclassified to equity from a liability.
The Company recorded a liability related to the fair value of the warrants issued in connection with the issuance and sale of the Notes on October 2, 2013 in an amount equal to the value assigned to the Class A Warrants of $23,700,437 and the value assigned to the Class B Warrants of $9,710,596, or an aggregate of $33,411,033, upon issuance. The subsequent decrease in the warrants fair value during the nine months ended March 31, 2014, has been reflected as a decrease in the warrants liability and a charge to net income of $13,357,742.
Additionally, the financial information for the nine months ended March 31, 2014 has been restated to reflect the change in fair value of warrants liability for the previously issued warrants exercisable into 8,500,000 shares of common stock that are held by Wells Fargo Energy Capital, Inc. (WFEC), since their re-pricing in December 2012. The Company re-priced and extended these warrants in connection with the amendment of its Credit Agreement with WFEC in December 2012. The warrants were modified to provide for an exercise price of $0.20 per share with the exercise term extended to December 31, 2017. The fair value of the warrants liability was not recorded for the year ended June 30, 2013 or previous years. The Company, however, recorded the liability related to the fair value of these warrants as of July 1, 2013 ($1,805,898) as an out-of-period charge to net income and corresponding liability on July 1, 2013. The subsequent increase in the warrants fair value during the nine months ended March 31, 2014, has been reflected as a net decrease in the warrants liability and a charge to net income of $465,849.
The following table is a summary of the warrant liability activity measured at fair value using Level 3 inputs:
|
|
Warrants liability |
| |
WFEC warrants, balance at July 1, 2013 |
|
$ |
1,805,898 |
|
Granted |
|
|
| |
Class A and B warrants, balance at October 2, 2013 |
|
33,411,033 |
| |
Cancelled, forfeited or expired |
|
|
| |
Change in fair value |
|
|
| |
Class A and B warrants |
|
(13,357,742 |
) | |
WFEC warrants |
|
(465,849 |
) | |
Balance at March 31, 2014 |
|
$ |
21,393,340 |
|
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
The estimated fair value of the warrants issued in connection with the Notes was determined using the Monte Carlo Simulation option pricing model, assuming there will be no dividend, using the applicable exercisable periods, a risk-free rate of return of approximately 0.89% and an expected stock volatility of approximately 80%. The estimated fair value for warrants associated with the WFEC Credit Agreement was determined using the Black-Scholes option pricing model, assuming there will be no dividend, using the applicable exercisable periods, a risk-free rate of return of approximately 0.89% and an expected volatility of 80%.
Earnings per share
The Company has adopted the provisions of Financial Accounting Standards Board, Accounting Standards Codification (FASB ASC) 260, Earnings per Share. FASB ASC 260 reporting requirements replace primary and fully-diluted earnings per share (EPS) with basic and diluted EPS. Basic EPS is calculated by dividing net income (available to common shareholders) by the weighted average number of common shares outstanding for the period. Diluted EPS reflects the potential dilution that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.
Potential dilutive securities (e.g., preferred stock, stock warrants and convertible debt) have been considered, but because the Company reported a net loss in the three month periods ended March 31, 2014 and 2013, their effects would be anti-dilutive. The weighted average number of common and common equivalent shares outstanding was 77,500,392 and 77,265,047 for the quarters ended March 31, 2014 and 2013, respectively, and were 77,479,184 and 77,232,049 for the nine month periods ended March 31, 2014 and 2013, respectively. The net income for the nine months ended March 31, 2014 has been considered potentially dilutive and the weighted average number of diluted common and common equivalent shares outstanding was 93,756,501.
|
|
Nine Months Ended March 31, |
|
Three Months Ended March 31, |
| ||||||||
|
|
|
| ||||||||||
|
|
2014 |
|
2013 |
|
2014 |
|
2013 |
| ||||
Oil and natural gas revenues |
|
$ |
10,841,391 |
|
$ |
3,012,016 |
|
$ |
5,219,837 |
|
$ |
968,980 |
|
Net income (loss) |
|
$ |
2,071,950 |
|
$ |
(5,072,668 |
) |
$ |
(8,495,152 |
) |
$ |
(2,416,897 |
) |
Basic earnings (loss) per share |
|
$ |
0.03 |
|
$ |
(0.07 |
) |
$ |
(0.11 |
) |
$ |
(0.03 |
) |
Diluted earnings (loss) per share |
|
$ |
0.02 |
|
$ |
(0.07 |
) |
$ |
(0.11 |
) |
$ |
(0.03 |
) |
Note D Stockholders Equity:
Stock issuances
In August 2009, the Company entered into Subscription and Registration Rights Agreements with certain investors pursuant to which the Company issued an aggregate of 2,104,001 shares of common stock and warrants exercisable into 1,052,000 shares of common stock. The remaining August 2009 unexercised warrants are currently exercisable into 787,294 shares of common stock at $0.6747 per share and expire July 31, 2014.
Preferred Stock
The Companys board has the power, without further vote of shareholders, to authorize the issuance of up to 10,000,000 shares of preferred stock and to fix and determine the terms, limitations and relative rights and
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
preferences of any shares of the preferred stock. This power includes the authority to establish voting, dividend, redemption, conversion, liquidation and other rights of any such shares. The preferred stock may be divided into such number of series as the board determines.
The board of directors has established three series of preferred stock, one of which has been canceled:
Series A Convertible Preferred Stock The Series A Convertible Preferred Stock had a stated value of $100 per share, was entitled to dividends in the amount of 8% per annum, was convertible into the common stock at $1.20 per share of common stock and was redeemable by the Company at $120 per share. The Series A convertible preferred stock was canceled in February 2014.
Series B Convertible Preferred Stock The Series B Convertible Preferred Stock has a stated value of $1,000 per share, is entitled to dividends in the amount of 9.5% per annum and is convertible into our common stock at $0.50 per share of common stock. The holders of the Series B Convertible Preferred Stock are entitled to vote (on an as-converted basis), together with holders of common stock, as a single class with respect to all matters presented to holders of common stock. As of March 31, 2014, there were 16,540.589 shares of Series B Convertible Preferred Stock outstanding.
Series C Redeemable Voting Preferred Stock The Series C Redeemable Voting Preferred Stock has a stated value of $0.01 per share. The holders of Series C Redeemable Voting Preferred Stock are entitled to vote, together with the holders of our common stock, as a single class with respect to all matters presented to holders of common stock. The holders of Series C Redeemable Voting Preferred Stock are entitled, in the aggregate, to a number of votes equal to the number of shares of common stock that would be issuable upon the exercise of all of the outstanding Class A Warrants and Class B Warrants (as defined below) on a Full Physical Settlement basis (as defined in the Warrant and Preferred Stock Agreement). The holders of Series C Redeemable Voting Preferred Stock are not entitled to receive any dividends. The Series C Redeemable Voting Preferred Stock may be redeemed at the option of the holders thereof at any time at the stated value per share. There were 98,751.823 shares of Series C Redeemable Voting Preferred Stock issued and outstanding as of March 31, 2014.
Conversion of Wallen Note and Series A Convertible Preferred Stock into Series B Convertible Preferred Stock
The Company entered into and consummated the transactions contemplated by a Conversion and Preferred Stock Purchase Agreement dated as of October 2, 2013 (the Conversion Agreement) with Calvin A. Wallen III, the Companys Chairman, President and Chief Executive Officer and Langtry Mineral & Development, LLC, an entity controlled by Mr. Wallen (Langtry). Pursuant to the terms of the Conversion Agreement, (a) Langtry was issued 12,047 shares of Series B Convertible Preferred Stock, with an aggregate stated value of $12,047,000, in exchange for the cancellation of all of the issued and outstanding shares of Series A Convertible Preferred Stock held by Langtry and (b) Mr. Wallen was issued 2,115 shares of Series B Convertible Preferred Stock, with an aggregate stated value of $2,115,000, in exchange for the cancellation of a promissory note payable to Mr. Wallen in the principal amount of $2,000,000, plus $114,986 of accrued and unpaid interest. In these exchanges, the carrying amounts of the Series A Convertible Preferred Stock held by Langtry and the promissory note payable to Mr. Wallen exceeded the fair value of the Series B Convertible Preferred Stock the Company issued by $9,830,152 and $1,725,826, respectively. Due to the related party nature of the exchanges, the excess amounts have been recorded as contributions to equity.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Issuance of Warrants and Series C Redeemable Voting Preferred Stock
Pursuant to the terms of a Warrant and Preferred Stock Agreement, dated as of October 2, 2013, and in connection with the issuance and sale of the Notes under the Note Purchase Agreement (see Note F), the Company issued certain warrants. The Company issued warrants exercisable for (a) an aggregate of 65,834,549 shares of Common Stock, at an exercise price of $0.01 per share (the Class A Warrants), and (b) an aggregate of 32,917,274 shares of Common Stock, at an exercise price of $0.50 per share (the Class B Warrants, and together with the Class A Warrants, the Warrants). The fair value of the warrants was recorded as a loan discount and will be amortized over the three year term of the loan (see Note F).
The Company also issued an aggregate of 98,751.823 shares of Series C Redeemable Voting Preferred Stock to certain purchasers of the Notes and their affiliates (the Investors). The holders of the Series C Redeemable Voting Preferred Stock are entitled to vote, together with holders of Common Stock, as a single class with respect to all matters presented to holders of Common Stock of the Company. The holders of Series C Redeemable Voting Preferred Stock are entitled, in the aggregate, to a number of votes equal to the number of shares of Common Stock that would be issuable upon the exercise of all outstanding Warrants on a Full Physical Settlement basis (as defined in the Warrant and Preferred Stock Agreement). The holders of Series C Redeemable Voting Preferred Stock are not entitled to receive any dividends from the Company. Shares of the Series C Redeemable Voting Preferred Stock have a par value of $0.01 per share and may be redeemed at the option of the holders thereof at any time. The Series C Redeemable Voting Preferred has an aggregate stated value of approximately $988. The Series C Redeemable Voting Preferred Stock votes on all matters submitted for shareholder approval.
Stock and option grants
On January 14, 2011, the Company granted stock options, under the 2005 Stock Option Plan (the Plan), for the purchase of an aggregate of 288,667 shares of Company common stock to its Chief Financial Officer at that time, Larry G. Badgley. These options have an exercise price of $1.20 per share and expire five years from their issue date. One option, for the purchase of 15,667 shares, was fully vested upon grant. The other option, for the purchase of 273,000 shares vested on October 1, 2012. We estimated the fair value of the options on the date of grant using the Black-Scholes valuation model to be $100,997. There has been no charge to compensation expense for the three month period ending March 31, 2014, and none since October 2012, at which time the option was fully vested.
The expected term of the options represents the estimated period of time until exercise and is based on consideration to the contractual terms, vesting schedules and expectations of future employee behavior.
The risk-free interest rate is based on the U.S. Treasury bill rate in effect at the time of grant with an equivalent expected term or life. Information regarding activity for stock options under the Plan is as follows:
|
|
|
|
Weighted-average |
|
Weighted-average |
|
Aggregate |
| ||
|
|
|
|
exercise price per |
|
remaining contractual |
|
intrinsic |
| ||
|
|
Number of shares |
|
share |
|
term (years) |
|
value |
| ||
|
|
|
|
|
|
|
|
|
| ||
Outstanding, June 30, 2014 |
|
288,667 |
|
$ |
1.20 |
|
|
|
|
| |
Options granted |
|
|
|
|
|
|
|
|
| ||
Options exercised |
|
|
|
|
|
|
|
|
| ||
Options forfeited/expired |
|
|
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
|
|
| ||
Outstanding, March 31, 2014 |
|
288,667 |
|
1.20 |
|
1.50 |
|
$ |
|
| |
|
|
|
|
|
|
|
|
|
| ||
Exercisable, March 31, 2014 |
|
288,667 |
|
$ |
1.20 |
|
1.50 |
|
$ |
|
|
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Note E Oil and Gas Properties:
The capitalized costs included in the full cost pool are subject to a ceiling test, which limits such costs to the aggregate of the estimated present value, using a ten percent discount rate, of the future net revenues from proved reserves, based on current economic and operating conditions plus the lower of cost and estimated net realizable value of unproven properties.
The Company recorded no impairment loss on oil and gas properties for the three or nine months ended March 31, 2014 or 2013.
Note F Long-term debt:
Senior Secured Notes Financing
The Company entered into a Note Purchase Agreement dated October 2, 2013, pursuant to which the Company issued an aggregate of $66.0 million of notes due October 2, 2016 (the Notes) to certain Investors. As of March 31, 2014, the Notes bore interest at the rate of 15.5% per annum, in cash, payable quarterly; provided, however, that interest for the first six months following the closing was paid 7.0% per annum in cash and 8.5% per annum in additional Notes. The indebtedness under the Note Purchase Agreement is secured by substantially all of the assets of the Company, including a first priority lien over all of the assets of the Company, Cubic Asset and Cubic Asset Holding and a second priority lien over all of the assets of Cubic Louisiana and Cubic Louisiana Holding. Under the Note Purchase Agreement, the Company must maintain a $10,000,000 minimum cash balance through October 2, 2016.
The Company allocated the proceeds from the issuance of the Notes to the Warrants and the Notes, based on the warrants fair market values at the date of issuance. The value assigned to the Class A Warrants was $23,700,437 and the value assigned to the Class B Warrants was $9,710,596, both of which were recorded as liabilities. The assignment of a fair value to the Warrants resulted in a loan discount being recorded. The discount will be amortized over the original three-year term of the Notes as additional interest expense. Amortization for the three and nine months ended March 31, 2014 was $2,807,687 and $5,585,553 respectively.
Cubic incurred loan costs of $2,840,820 on the issuance of the Notes and Warrants. The amount allocable to the debt of $2,840,820 has been capitalized and will be amortized over the original term of the Notes. Amortization for the three and nine months ended March 31, 2014 was $233,492 and $464,390.
Wells Fargo debt
On March 5, 2007, Cubic entered into a credit agreement with Wells Fargo Energy Capital, Inc. (WFEC) providing for a revolving credit facility of $20,000,000 (the Revolving Note) and a convertible term loan of $5,000,000 (the Term Loan; and together with the Revolving Note, the Credit Facility). Subsequently, the Revolving Note was increased to $40 million. The indebtedness bore interest at a fluctuating rate equal to the sum of the Wells Fargo Bank prime rate plus two percent (2%) per annum, was originally scheduled to mature on March 1, 2010, subsequently extended to October 2, 2013, and was secured by substantially all of the assets of the Company.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Contemporaneously with entering into the Note Purchase Agreement, the Company repaid the $5 million Term Loan payable to WFEC, and Cubic Louisiana assumed the remaining unpaid debt to WFEC, which amount was $20,865,110 as of that date. That debt is reflected in a term loan bearing interest at the Wells Fargo Bank prime rate, plus 2%, per annum, due October 2, 2016. In the event that Cubic Louisiana does not have available cash to pay interest on the Credit Facility, accrued and unpaid interest will be paid in kind via an additional promissory note. As part of the new credit agreement, WFEC is providing a revolving credit facility in the amount of up to $10,000,000, bearing interest at the same rate, with all advances under that revolving credit facility to be made in the sole discretion of WFEC.
During the nine month period ended March 31, 2014, the Company borrowed $4,015,826 under the revolving credit facility for two new natural gas wells drilled and completed by EXCO, leaving a maximum of $5,984,174 available for future borrowing. Interest expense for the quarters ended March 31, 2014 and 2013 was $288,009 and $356,079, respectively, and for the nine-months ended March 31, 2014 and 2013 it was $907,104 and $1,143,555, respectively.
December 2009 subordinated debt issue and refinancing
On December 18, 2009, the Company issued a subordinated promissory note (the Wallen Note) payable to Mr. Wallen, the Companys Chairman of the Board and Chief Executive Officer, in the principal amount of $2,000,000 which was subordinated to all WFEC indebtedness. The Wallen Note bore interest at the prime rate plus one percent (1%), and originally provided for interest payable monthly. The proceeds of the Wallen Note were used to repay other indebtedness to the Company. The Wallen Note was converted into shares of Series B preferred stock on October 2, 2013.
In addition, an entity controlled by Mr. Wallen advanced the Company $2,000,000, as of June 30, 2013 to provide short-term working capital and an additional $2,500,000 during the quarter ended September 30, 2013 to fund additional deposits and fees paid for extensions needed to consummate the transactions that were consummated on October 2, 2013. The Company accrued costs associated with these advances totaling $896,667, which is included in interest expense for the nine month period ended March 31, 2014. These advances along with the additional costs accrued were re-paid on October 2, 2013.
Conversion of Wallen Note and Series A Convertible Preferred Stock into Series B Convertible Preferred Stock
The Company entered into and consummated the transactions contemplated by a Conversion and Preferred Stock Purchase Agreement dated as of October 2, 2013 with Mr. Wallen and Langtry (the Conversion Agreement). Pursuant to the terms of the Conversion Agreement, (a) Langtry was issued 12,047 shares of Series B preferred stock, with an aggregate stated value of $12,047,000, in exchange for the cancellation of all of the issued and outstanding shares of Series A preferred stock held by Langtry and (b) Mr. Wallen was issued 2,115 shares of Series B preferred stock, with an aggregate stated value of $2,115,000, in exchange for the cancellation of the Wallen Note and accrued interest.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Note G Fair Value Measurements
We value our derivatives and other financial instruments according to FASB ASC Topic 820, Fair Value Measurements and Disclosures, which defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date.
To estimate fair value, the Company utilizes market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. The guidance establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted market prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The three levels of the fair value hierarchy are as follows:
· Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities.
· Level 2 inputs are quoted prices for similar assets and liabilities in active markets or inputs that are observable for the asset or liability, either directly or indirectly through market corroboration, for substantially the full term of the financial instrument.
· Level 3 inputs are measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources. These inputs may be used with internally developed methodologies or third party broker quotes that result in managements best estimate of fair value. The Companys valuation models consider various inputs including (a) quoted forward prices for commodities, (b) time value, (c) volatility factors and (d) current market and contractual prices for the underlying instruments. Significant increases or decreases in any of these inputs in isolation would result in a significantly higher or lower fair value measurement. Level 3 instruments are commodity costless collars, index swaps, basis and fixed price swaps and put and call options to hedge natural gas, oil and NGLs price risk. At each balance sheet date, the Company performs an analysis of all applicable instruments and includes in Level 3 all of those whose fair value is based on significant unobservable inputs. The fair values derived from counterparties and third-party brokers are verified by the Company using publicly available values for relevant NYMEX futures contracts and exchange traded contracts for each derivative settlement location. Although such counterparty and third-party broker quotes are used to assess the fair value of its commodity derivative instruments, the Company does not have access to the specific assumptions used in its counterparties valuation models. Consequently, additional disclosures regarding significant Level 3 unobservable inputs were not provided and the Company does not currently have sufficient corroborating market evidence to support classifying these contracts as Level 2 instruments.
As required, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The Companys assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values below incorporates various factors, including the impact of the counterpartys non-performance risk
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
with respect to the Companys financial assets and the Companys non-performance risk with respect to the Companys financial liabilities. The Company has not elected to offset the fair value amounts recognized for derivative instruments executed with the same counterparty, but reports them gross on its consolidated balance sheets.
Transfers between levels are recognized at the end of the reporting period. There were no transfers between levels during the 2013 and 2014 periods.
The following tables set forth by level within the fair value hierarchy the Companys financial assets and liabilities that were accounted for at fair value on a recurring basis as of March 31, 2014:
|
|
Fair value as of March 31, 2014 |
| ||||||||||
|
|
Level 1 |
|
Level 2 |
|
Level 3 |
|
Total |
| ||||
|
|
|
|
|
|
|
|
|
| ||||
Derivative financial instruments -Assets |
|
|
|
|
|
|
|
|
| ||||
Derivative financial instruments - Liabilities |
|
|
|
|
|
|
|
|
| ||||
Oil and natural gas derivative financial instruments |
|
|
|
|
|
44,275,363 |
|
44,275,363 |
| ||||
Total |
|
$ |
|
|
$ |
|
|
$ |
44,275,363 |
|
$ |
44,275,363 |
|
The fair value guidance, as amended, establishes that every derivative instrument is to be recorded on the balance sheet as either an asset or liability measured at fair value. (See Note H).
Derivative contracts added October 2, 2013 |
|
$ |
35,091,536 |
|
Loss on derivative contracts |
|
12,221,932 |
| |
Settlements on derivative contracts |
|
(3,038,105 |
) | |
Derivative contracts as of March 31, 2014 |
|
$ |
44,275,363 |
|
Note H Derivative Instruments and Hedging Activity
From time to time, we utilize commodity derivatives to attempt to reduce exposure to fluctuations in the price of crude oil and natural gas. A description of the Companys derivative financial instruments is provided below:
Fixed price swaps |
|
The Company receives a fixed price for the contract and pays a floating market price to the counterparty. |
|
|
|
Fixed price call options |
|
The Company sells fixed price call options in exchange for a premium. At the time of settlement, if the market price exceeds the fixed price of the call option, the Company pays the counterparty such excess on sold fixed price call options. If the market price settles below the fixed price of the call option, no payment is due from either party. |
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
On October 2, 2013, the Company, through its subsidiary Cubic Asset, entered into a Call Option Structured Derivative arrangement with a third party that resulted in the receipt of an upfront payment at closing of approximately $35,000,000, through the sale of calls, which upfront payment approximated fair value of the calls sold at inception. As a result, the Call Option Structured Derivative arrangement was initially recognized and measured at the amount of its upfront payment. Under the terms of the Call Option Structured Derivative arrangement, Cubic Asset sold calls to the third party covering (i) approximately 556,000 barrels of oil at a strike price set between $80 per barrel and $90 per barrel, and (ii) approximately 51.3 million MMBtus of gas at a strike price set between $3.45 per MMBtu and $3.90 per MMBtu. The scheduled volumes subject to the calls sold relate to production months from November 2013 through December 2018. The Company is subject to the price risks associated with product price changes that differ from the specified call prices.
If the market price during the applicable production month is above the applicable strike price, Cubic Asset would be required to pay the third party the difference between the market price and strike price for the amount of production subject to the call. This arrangement does not hedge the Companys risk associated with product price decreases.
On October 2, 2013, the Company, through its subsidiary Cubic Asset, entered into a Fixed Price Swap arrangement. Under the terms of the fixed price swap arrangement, Cubic Asset sold calls to a third party covering approximately 18,000 barrels of oil at a price of $92 per barrel. The scheduled volumes subject to the calls sold relate to production months from November 2013 through October 2016. Cubic Asset receives the fixed price and pays the third party the floating market price during the applicable production month for the amount of production subject to the call. Cubic Asset is subject to the price risks associated with product price increases above the specified fixed prices. This third party has a junior lien position on both of the assets of Cubic Asset and Cubic Louisiana.
All derivative contracts are carried at their fair value on the balance sheet and all unrealized gains and losses as well as realized gains and losses related to contract settlements are presented in the statement of operations as a gain or (loss) on derivatives. For the three and nine months ended March 31, 2014, the Company reported losses of $2,127,972 and $12,221,932 respectively, in the condensed consolidated statement of operations related to its commodity derivative instruments.
As of March 31, 2014, the following natural gas derivative transactions were outstanding with the associated notional volumes and weighted average underlying hedge prices:
Settlement Period |
|
Derivative Instrument |
|
Average |
|
Total of |
|
Strike |
| |
|
|
|
|
In MMBtu |
|
|
| |||
2014 |
|
Call Option |
|
26,666 |
|
7,299,927 |
|
$ |
3.90 |
|
2015 |
|
Call Option |
|
29,305 |
|
10,696,392 |
|
$ |
3.70 |
|
2016 |
|
Call Option |
|
30,292 |
|
11,056,752 |
|
$ |
3.65 |
|
2017 |
|
Call Option |
|
30,643 |
|
11,184,600 |
|
$ |
3.55 |
|
2018 |
|
Call Option |
|
22,609 |
|
8,252,340 |
|
$ |
3.45 |
|
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
As of March 31, 2014, the following crude derivative transactions were outstanding with the associated notional volumes and weighted average underlying hedge prices:
Settlement Period |
|
Derivative Instrument |
|
Average |
|
Total of |
|
Strike |
| |
|
|
|
|
In Bbls |
|
|
| |||
2014 |
|
Fixed Price Swap |
|
23 |
|
6,201 |
|
$ |
92.00 |
|
2015 |
|
Fixed Price Swap |
|
15 |
|
5,532 |
|
$ |
92.00 |
|
2016 |
|
Fixed Price Swap |
|
8 |
|
2,900 |
|
$ |
92.00 |
|
|
|
|
|
|
|
|
|
|
| |
2014 |
|
Call Option |
|
289 |
|
79,218 |
|
$ |
90.00 |
|
2015 |
|
Call Option |
|
312 |
|
113,952 |
|
$ |
80.00 |
|
2016 |
|
Call Option |
|
361 |
|
131,796 |
|
$ |
80.00 |
|
2017 |
|
Call Option |
|
328 |
|
119,868 |
|
$ |
80.00 |
|
2018 |
|
Call Option |
|
218 |
|
79,452 |
|
$ |
80.00 |
|
Oil derivatives. Our oil derivatives are swap and call option contracts for notional Bbls of oil at interval NYMEX oil index prices. The asset and liability values attributable to our oil derivatives as of the end of the reporting period are based on (i) the contracted notional volumes, (ii) independent active NYMEX future quotes for oil index prices, (iii) the applicable estimated credit-adjusted risk free rate curve, and (iv) the implied rate of volatility inherent in the call option contracts. The implied rates of volatility were determined based on average NYMEX oil index prices.
Natural gas derivatives. Our natural gas derivatives are option contracts for notional MMcf of natural gas at NYMEX penultimate index prices. The asset and liability values attributable to our natural gas derivatives as of the end of the reporting period are based on (i) the contracted notional volumes and (ii) the applicable credit-adjusted risk-free rate curve and (iii) the implied rate of volatility inherent in the call option contracts. The implied rates of volatility were determined based on average NYMEX penultimate index prices.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Additional Disclosures about Derivative Instruments and Hedging Activities
The tables below provide information on the location and amounts of derivative fair values in the condensed consolidated balance sheet and derivative gains and losses in the condensed consolidated statement of operations for derivative instruments that are not designated as hedging instruments:
|
|
Fair Values of Derivative Instruments |
| ||||||
|
|
Derivative Assets(Liabilities) |
| ||||||
|
|
|
|
Fair Value |
| ||||
|
|
Balance Sheet Location |
|
March 31, 2014 |
|
March 31, 2013 |
| ||
|
|
|
|
|
|
|
| ||
Derivatives not designated as hedging instruments |
|
|
|
|
|
|
| ||
Commodity derivative contracts |
|
Assets |
|
$ |
|
|
$ |
|
|
Commodity derivative contracts |
|
Current Liabilities |
|
(5,949,967 |
) |
|
| ||
Commodity derivative contracts |
|
Long-term Liabilities |
|
(38,325,396 |
) |
|
| ||
Total derivatives not designated as hedging instruments |
|
|
|
$ |
(44,275,363 |
) |
$ |
|
|
|
|
Amount of Gain (Loss) Recognized in Income on Derivatives |
| ||||||
|
|
Location of Gain (Loss) |
|
Amount of Gain (Loss) Recognized in |
| ||||
|
|
Derivatives |
|
March 31, 2014 |
|
March 31, 2013 |
| ||
|
|
|
|
|
|
|
| ||
Derivatives not designated as hedging instruments |
|
|
|
|
|
|
| ||
Commodity derivative contracts |
|
Loss on derivatives |
|
$ |
(12,221,932 |
) |
$ |
|
|
Total derivatives not designated as hedging instruments |
|
|
|
$ |
(12,221,932 |
) |
$ |
|
|
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
|
|
Volume |
|
Fair Value per |
|
Fair value at |
| ||
Natural gas: |
|
|
|
|
|
|
| ||
|
|
|
|
|
|
|
| ||
Call Options: |
|
|
|
|
|
|
| ||
2014 |
|
7,299,927 |
|
$ |
0.44 |
|
$ |
3,237,751 |
|
2015 |
|
10,696,392 |
|
$ |
0.66 |
|
$ |
7,040,561 |
|
2016 |
|
11,056,752 |
|
$ |
0.77 |
|
$ |
8,551,013 |
|
2017 |
|
11,184,600 |
|
$ |
0.89 |
|
$ |
9,931,795 |
|
2018 |
|
8,252,340 |
|
$ |
1.09 |
|
$ |
8,967,453 |
|
Total natural gas |
|
|
|
|
|
$ |
37,728,573 |
| |
|
|
|
|
|
|
|
| ||
Oil: |
|
|
|
|
|
|
| ||
Swaps: |
|
|
|
|
|
|
| ||
2014 |
|
6,201 |
|
$ |
5.09 |
|
$ |
31,538 |
|
2015 |
|
5,532 |
|
$ |
(1.84 |
) |
$ |
(10,178 |
) |
2016 |
|
2,900 |
|
$ |
(6.23 |
) |
$ |
(18,066 |
) |
|
|
|
|
|
|
$ |
3,294 |
| |
Call Options: |
|
|
|
|
|
|
| ||
2014 |
|
79,218 |
|
$ |
7.06 |
|
$ |
558,937 |
|
2015 |
|
113,952 |
|
$ |
12.66 |
|
$ |
1,443,050 |
|
2016 |
|
131,796 |
|
$ |
13.29 |
|
$ |
1,751,313 |
|
2017 |
|
119,868 |
|
$ |
13.81 |
|
$ |
1,655,848 |
|
2018 |
|
79,452 |
|
$ |
14.28 |
|
$ |
1,134,348 |
|
Total oil |
|
|
|
|
|
$ |
6,543,496 |
| |
Total oil and natural gas derivatives |
|
|
|
|
|
$ |
44,275,363 |
|
Note I Warrants Liabilty
The Companys outstanding warrants issued in connection with the issuance of the Notes issued on October 2, 2013 are classified as liabilities and are adjusted to reflect fair value at the end of each reporting period, with the changes in fair value recognized as a change in fair value of warrants liability in the Companys condensed consolidated statements of operations. Specifically, the warrants issued in connection with Notes issued on October 2, 2013, grant the warrant holders certain anti-dilution protection which provide exercise price adjustments in the event that any common stock or common stock equivalents are issued at an effective price per share that is less than the then-current exercise price per share. As noted, the financial information for the three months ended March 31, 2014 has been restated to reflect the change in fair value of warrants liability. The fair value of the warrants liability was not recorded for the year ended June 30, 2013 or previous years. Upon exercise or expiration of a warrant, the fair value of the warrant at the time will be reclassified to equity from a liability.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
The Company recorded the liability related to the fair value of these warrants issued in connection with the issuance and sale of the Notes on October 2, 2013 in an amount equal to the value assigned to the Class A Warrants of $23,700,437 and the value assigned to the Class B Warrants of $9,710,596, or an aggregate of $33,411,033 recorded as a liability upon issuance. The subsequent decrease in the warrants fair value during the three and nine months ended March 31, 2014 has been reflected as a decrease in the warrants liability and a charge to net income of $5,177,320 and $13,357,742, respectively. Upon exercise or expiration of the warrants, the fair value of the warrants at that time will be reclassified to equity from a liability.
The Company re-priced and extended warrants to purchase 8,500,000 shares of common stock in connection with the amendment of its Credit Agreement with WFEC in December 2012. The previously issued warrants were modified to provide for an exercise price of $0.20 per share with the exercise term extended to December 31, 2017. The warrants include certain anti-dilution provisions, which provide exercise price adjustments in the event that any common stock equivalents are issued at an effective price per share that is less than the exercise price of the warrants. The warrants were not recorded as a fair value liability for the year ended June 30, 2013 or previous years. The Company, however, recorded the fair value of these warrants as of July 1, 2013 ($1,805,898) as an out-of-period charge to net income and corresponding liability on July 1, 2013. The subsequent decrease in the warrants fair value during the nine months ended March 31, 2014, which includes the effect of the anti-dilution re-pricing from $0.20 per share to $0.17 per share in connection with the issuance of the Notes on October 2, 2013, has been reflected as a reduction in the warrant liability and a credit to net income, resulting in a net credit to net income of $96,048 in the three months ended December 31, 2013 and a $369,801 and a $465,849 net decrease in fair value of the WFEC warrants liability for the three and nine months ended March 31, 2014, respectively.
The following table is a summary of the warrants liability activity measured at fair value using Level 3 inputs:
|
|
Warrants liability |
| |
WFEC warrants, balance at July 1, 2013 |
|
$ |
1,805,898 |
|
Granted |
|
|
| |
Class A and B warrants, balance at October 2, 2013 |
|
33,411,033 |
| |
Cancelled, forfeited or expired |
|
|
| |
Change in fair value |
|
|
| |
Class A and B warrants |
|
(13,357,742 |
) | |
WFEC warrants |
|
(465,849 |
) | |
Balance at March 31, 2014 |
|
$ |
21,393,340 |
|
The estimated fair value of the warrants issued in connection with the Notes was determined using the Monte Carlo Simulation option pricing model, assuming there will be no dividend, using the applicable exercisable periods, a risk-free rate of return of approximately 0.89% and an expected stock volatility of approximately 80%. The estimated fair value for warrants associated with the WFEC Credit Agreement was determined using the Black-Scholes option pricing model, assuming there will be no dividend, using the applicable exercisable periods, a risk-free rate of return of approximately 0.89% and an expected volatility of 80%.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Note J Asset Retirement Obligations
We record asset retirement obligations (ARO) associated with the retirement of our long-lived assets in the period in which they are incurred and become determinable. Under this method, we record a liability for the expected future cash outflows discounted at our credit-adjusted risk-free interest rate for the dismantlement and abandonment costs, excluding salvage values, of each oil and gas property. We also record an asset retirement cost to the oil and gas properties equal to the ARO liability. The fair value of the asset retirement cost and the ARO liability is measured using primarily Level 3 inputs. The significant unobservable inputs to this fair value measurement include estimates of plugging, abandonment and remediation costs, inflation rate and well life. The inputs are calculated based on historical data as well as current estimated costs. Accretion of the liability is recognized each period using the interest method of allocation, and the capitalized cost is depleted over the useful life of the related asset.
The following table reflects the assumed ARO liability from the acquisition of assets on October 2, 2013 for the nine months ended March 31, 2014:
Asset retirement obligations, at June 30, 2013 |
|
$ |
|
|
Activity during the period: |
|
|
| |
Liabilities incurred during the period |
|
1,576,323 |
| |
Accretion of discount |
|
226,635 |
| |
Asset retirement obligations, at March 31, 2014 |
|
1,802,958 |
|
Note K Lease Operating Expenses
Within the Companys Lease operating costs as part of transportation and marketing expenses, Volume Shortfall Payments were created as part of a transaction monetizing mid-stream assets. Gastar had entered into a transportation agreement with their East Texas mid-stream natural gas gathering system purchaser, requiring a certain minimum quarterly volume of natural gas production, which agreement was assumed by Cubic Asset as part of the acquisitions discussed in Note B. This agreement requires Cubic Asset to make payments for the natural gas volume shortfalls for any quarter through the autumn of 2014. Volume shortfalls require Cubic Asset to make quarterly payments, in excess of normal transportation and marketing costs. These quarterly payments have been approximately $600,000 and will end during the 2nd quarter of fiscal 2015.
Note L Related Party Transactions
Tauren owns working interests in oil and gas properties in which the Company owns working interests. As of March 31, 2014, the Company owed Tauren $4,009 and as of June 30, 2013, the Company owed Tauren $44,922 for revenue, miscellaneous capital expenditures and general and administrative expenses paid by Tauren on the Companys behalf.
In addition, certain oil and gas properties in which the Company owns a working interest were operated by an affiliated company, Fossil Operating, Inc. (Fossil), which is owned 100% by Mr. Wallen. As of March 31, 2014 and June 30, 2013, the Company owed Fossil $697,849 and $27,949 respectively for revenue, miscellaneous capital expenditures and general and administrative expenses, and the Company was owed by Fossil $104,605and $28,897 respectively, for oil and gas sales.
CUBIC ENERGY, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
AS OF MARCH 31, 2014
(Unaudited)
Note M Liquidity
Following consummation of the transactions on October 2, 2013, approximately $9,000,000 is available for capital expenditures and working capital for operations. Management believes cash on hand, cash that may be made available from WFEC, along with cash flows from operations, will be sufficient to fund operations for the next 12 months.
Note N Legal Proceedings
We are party to lawsuits arising in the normal course of business. We intend to defend these actions vigorously and believe, based on currently available information, that adverse results or judgments from such actions, if any, will not be material to our financial position or results of operations. The legal climate in Northwest Louisiana is hostile and litigious towards oil and gas companies; and the legal environment in East Texas is becoming increasingly competitive and hostile. Mineral owners are seeking opportunities to make additional money from their mineral rights, including pursuit of claims of lease expiration by asserting that production does not exist in paying quantities. In the normal course of our business, title defects and lease issues of varying degrees will arise, and, if practicable, reasonable efforts will be made to cure any such defects and issues.
A lawsuit was filed on or about June 15, 2010, styled, Glorias Ranch, LLC v. Tauren Exploration, Inc., Cubic Energy, Inc., Wells Fargo Energy Capital, Inc. & EXCO USA Asset, LLC, filed in the 1st Judicial District Court, Caddo Parish, Louisiana, Cause No. 541-768, A. This lawsuit alleges that all or part of the Glorias Ranch mineral lease has lapsed, and seeks a finding that the mineral lease has lapsed, damages, attorney fees, and other equitable relief. This lawsuit would have a material effect, with the lost acreage component having an estimated value of up to $9,100,000, if ultimately adjudicated entirely in favor of the mineral owner. The Company intends to vigorously defend its position and believes it will prevail regarding some, if not all, of the acreage at issue in this lawsuit.
Item 2. Managements Discussion and Analysis of Financial Condition and Results of Operations.
The following discussion of operations for the three and nine months ended March 31, 2014 and 2013 should be read in conjunction with our condensed financial statements and the notes thereto included in this Quarterly Report on Form 10-Q/A and with the financial statements, notes and managements discussion and analysis included in our Annual Report on Form 10-K/A for the year ended June 30, 2013.
Statements in this discussion may be forward-looking. These forward-looking statements involve risks and uncertainties, including those discussed below, which could cause actual results to differ from those expressed.
Overview
Cubic Energy, Inc. is an independent upstream energy company engaged in the development and production of, and exploration for, crude oil and natural gas. Our acreage is held in two wholly owned indirect subsidiaries, Cubic Louisiana, LLC, a direct subsidiary of Cubic Louisiana Holding, LLC, which holds our legacy Louisiana acreage, and Cubic Asset, LLC, a direct subsidiary of Cubic Asset Holding, LLC, which holds our newly acquired Texas acreage, our legacy Texas acreage and bolt-on working interests in our Louisiana acreage. Our oil and gas assets and activities are concentrated exclusively in Louisiana and Texas.
As a result of the acquisition of properties from Gastar Exploration Texas, LP (Gastar), we acquired proved reserves, oil & natural gas production and undeveloped leasehold interests in Leon and Robertson Counties, Texas. The acquired properties include approximately 17,400 net acres of leasehold interests. The acquisition price paid by us at closing was $39,188,830, following various adjustments set forth in the Gastar Agreement, and net of the various deposits paid prior to the closing date. For purposes of allocating revenues and expenses and capital costs between Gastar and us, such amounts we netted effective January 1, 2013 and have been recorded as an adjustment to the purchase price.
On September 27, 2013, the Company entered into a purchase agreement with Navasota Resources Ltd., LLP (Navasota). On October 2, 2013, pursuant to the Navasota Agreement, the Company acquired proved reserves, oil & natural gas production and undeveloped leasehold interests in Leon and Robertson Counties, Texas. The leasehold interests acquired from Navasota generally consist of additional fractional interests in the properties acquired pursuant to the Gastar Agreement, comprising approximately 6,400 net acres. The acquisition price paid by the Company was $19,400,000, prior to certain post-closing adjustments.
On October 2, 2013, the Company entered into a purchase agreement with Tauren Exploration, Inc. (Tauren). Pursuant to this agreement, the Company acquired well bores, proved reserves, oil & natural gas production and undeveloped leasehold interests in the Cotton Valley formation in DeSoto and Caddo Parishes, Louisiana. The acquired properties include approximately 5,600 net acres of leasehold interests. The acquisition price paid by the Company was $4,000,000 in cash and 2,000 shares of the Companys Series B preferred stock with an aggregate stated value of $2,000,000 and a fair market value of $368,000. The acquisition was valued at $26,946,000.
Legacy Louisiana Acreage
The Companys corporate strategy with respect to its asset acquisition and development efforts is to position the Company in low risk opportunities while building mainstream high yield reserves. The acquisition of its legacy acreage in DeSoto and Caddo Parishes, managed by Cubic Louisiana, put the Company in reservoir rich environment in the Hosston, Cotton Valley and Bossier/Haynesville Shale formations, with additional shallow formations to exploit as well. The Company has had success on its acreage with wells drilled achieving production from the Hosston formation, the Cotton Valley formation and the Bossier/Haynesville Shale formation.
We share our Bossier/Haynesville formation acreage with Goodrich Petroleum Corporation (Goodrich), Chesapeake Energy Corporation (Chesapeake), Petrohawk Energy Corporation (Petrohawk), EP Energy E&P Company, L.P. (El Paso), BG US Production Company, LLC (BG), EXCO Operating Company, LP (EXCO) and Indigo Minerals, LLC (Indigo Minerals), several of which are actively working on parts of our shared acreage. As a result of this activity, we saw improved production volumes in two of the last three fiscal years. However due to lower natural gas prices and depleting production volumes, there was a decrease in production volumes during fiscal 2013.
Legacy Texas Acreage
Our legacy Texas properties are situated in Eastland and Callahan Counties. These Texas properties consist primarily of wells acquired in several transactions between 1991 and 2002 and through overriding royalty interests reserved in farm-out agreements in 1998 and 1999. These wells produce limited amounts of natural gas and oil condensate.
Newly Acquired Texas Acreage and Louisiana Working Interests
Our recent acquisition of acreage in Leon and Robertson Counties, Texas, puts us in the additional reservoir rich environments in the Eagle Ford, Woodbine, Austin Chalk, Buda, Glen Rose and Georgetown formations, with additional shallow formations to exploit as well. We have seen success on our acquired acreage and Louisiana legacy acreage with two wells drilled by EXCO achieving production from the Haynesville shale formation and a total of three wells drilled and completed by Indigo Minerals during the nine months ended March 31, 2014. Concurrently with the acquisition of the acreage in Leon and Robertson Counties, Texas, we acquired bolt-on working interests in our legacy Louisiana acreage. These interests consist of additional working interests in the same Louisiana properties.
The legacy Texas acreage is operated by Fossil Operating, Inc. (Fossil) an entity controlled by Calvin A. Wallen, our Chairman of the Board and Chief Executive Officer.
Results of Operations
For the Three Months ended March 31, 2014 and 2013
|
|
Three months ended |
| ||||
|
|
March 31, |
| ||||
|
|
2014 |
|
2013 |
| ||
Production Volumes: |
|
|
|
|
| ||
Oil (Bbl) |
|
1,698 |
|
237 |
| ||
Natural gas liquids (Bbl) |
|
518 |
|
1,005 |
| ||
Natural gas (Mcf) |
|
1,264,380 |
|
271,553 |
| ||
Total (Mcfe) |
|
1,277,672 |
|
279,003 |
| ||
|
|
|
|
|
| ||
Weighted Average Sales Prices: |
|
|
|
|
| ||
Oil (per Bbl) |
|
$ |
98.25 |
|
$ |
96.09 |
|
Natural gas liquids (per Bbl) |
|
$ |
48.72 |
|
$ |
40.74 |
|
Natural gas (per Mcf) |
|
$ |
3.98 |
|
$ |
3.33 |
|
|
|
|
|
|
| ||
Selected Expenses per Mcfe: |
|
|
|
|
| ||
Production costs |
|
$ |
0.61 |
|
$ |
0.41 |
|
Workover expenses (non-recurring) |
|
$ |
0.47 |
|
$ |
0.19 |
|
Severance taxes |
|
$ |
(0.04 |
) |
$ |
0.07 |
|
Other revenue deductions |
|
$ |
1.38 |
|
$ |
0.55 |
|
Total lease operating expenses |
|
$ |
2.42 |
|
$ |
1.17 |
|
General and administrative expenses |
|
$ |
1.13 |
|
$ |
2.02 |
|
Depreciation, depletion and amortization |
|
$ |
2.10 |
|
$ |
2.69 |
|
Revenues
Oil And Gas Sales increased to $5,219,837 for the quarter ended March 31, 2014 from $968,980 for the quarter ended March 31, 2013 primarily due to increased oil and gas volumes resulting from the acquisition of the acreage in Leon and Robertson Counties, Texas in October 2013. We received an average natural gas price of $3.98 per Mcf in the 2014 quarter versus $3.33 in the 2013 quarter.
Costs and Expenses
Oil and Gas Production and Operating Costs increased to $3,105,635 (45% of oil and gas sales) for 2014 from $325,906 (34% of oil and gas sales) for 2013, primarily due to the expenses incurred from the increased number of wells brought online as a result of the acquisition of the acreage in Leon and Robertson Counties, Texas in October 2013. Other revenue deduction expenses increased $1,610,773. These are costs passed-through to the Company by the purchaser of the Companys gas. Such costs are deducted from the Companys gross revenue by the purchaser and include, but are not limited to: costs to market the Companys gas, compression fees, and the cost of fuel used by the purchaser to convey the Companys gas; lease operating expense increased $644,235, workovers expenses increased $600,447, production taxes decreased $75,122 primarily due to abatements.
Accretion of Asset Retirement Obligation (ARO) was $113,318 for the three months ended March 31, 2014.
General and Administrative Expenses increased to $1,444,340 for 2014 from $562,692 in 2013, primarily due to an increase of $471,518 in salaries (due to employee raises and new hires), a $168,722 increase in legal fees/expenses, a $80,649 increase in contracted professional services, a $66,314 increase in marketing
expenses and a $40,272 increase in reserve report fees, related to the Companys acquisitions and debt restructuring efforts, during the three months ended March 31, 2014 as compared to the 2013 quarter.
Derivatives Loss was $5,601,123 for the three months ended March 31, 2014. There was no derivative gain or loss for the three months ended March 31, 2013, as we had not engaged in any derivative transactions prior to the end of that quarter. The net derivative loss in the 2014 quarter was due to contract prices of $92 per barrel of oil and $3.90 per Mcf for natural gas generally being lower than the settlement prices.
Change in Fair Value of Warrants Liability of $5,547,121 was recognized for the three months ended March 31, 2014. The fair value of warrants liability associated with the Companys Class A and B warrants, which were issued in connection with the issuance of the Notes on October 2, 2013, decreased as of March 31, 2014, by $5,177,320. There was also a decrease in fair value of warrants held by WFEC of $369,801 for the three months ended March 31, 2014.
Depreciation, Depletion and Amortization increased to $2,685,149 in 2014 from $751,075 in 2013. The increase was primarily due to the $90,037,491 increase in the full cost pool due to the acquisitions prior to the three months ended March 31, 2014 as compared to the 2013 quarter.
Interest Expense increased to $5,695,528 in 2014 from $1,258,240 in 2013 primarily due to interest incurred on the Notes issued on October 2, 2013, as well as interest on borrowings from WFEC. The Companys weighted average total debt (before discounts) was $92,299,345 for the 2014 quarter from $27,865,110 for the 2013 quarter.
For the Nine Months ended March 31, 2014 and 2013
|
|
Nine months ended |
| ||||
|
|
March 31, |
| ||||
|
|
2014 |
|
2013 |
| ||
Production Volumes: |
|
|
|
|
| ||
Oil (Bbl) |
|
5,970 |
|
612 |
| ||
Natural gas liquids (Bbl) |
|
1,884 |
|
1,460 |
| ||
Natural gas (Mcf) |
|
2,800,069 |
|
931,822 |
| ||
Total (Mcfe) |
|
2,847,189.90 |
|
944,254 |
| ||
|
|
|
|
|
| ||
Weighted Average Sales Prices: |
|
|
|
|
| ||
Oil (per Bbl) |
|
$ |
93.87 |
|
$ |
89.35 |
|
Natural gas liquids (per Bbl) |
|
$ |
45.36 |
|
$ |
45.78 |
|
Natural gas (per Mcf) |
|
$ |
3.64 |
|
$ |
3.10 |
|
|
|
|
|
|
| ||
Selected Expenses per Mcfe: |
|
|
|
|
| ||
Production costs |
|
$ |
0.71 |
|
$ |
0.49 |
|
Workover expenses (non-recurring) |
|
$ |
0.25 |
|
$ |
0.20 |
|
Severance taxes |
|
$ |
0.00 |
|
$ |
0.18 |
|
Other revenue deductions |
|
$ |
1.24 |
|
$ |
0.81 |
|
Total lease operating expenses |
|
$ |
2.19 |
|
$ |
1.67 |
|
General and administrative expenses |
|
$ |
1.39 |
|
$ |
1.67 |
|
Depreciation, depletion and amortization |
|
$ |
2.01 |
|
$ |
2.69 |
|
Revenues
Oil and Gas Sales increased to $10,841,391 for the nine months ended March 31, 2014 from $3,012,016 for the nine months ended March 31, 2013, primarily due to increased oil and gas volumes resulting from the acquisitions during the 2014 period versus the 2013 period. We received an average natural gas price of $3.64 per Mcf in the 2014 period versus $3.10 per Mcf in the 2013 period.
Costs and Expenses
Oil and Gas Production and Operating Costs increased to $6,409,143 (50% of oil and gas sales) for 2014 from $1,579,221 (52% of oil and gas sales) for 2013, primarily due to the expenses recognized from the increased number of wells brought online post-acquisition during the nine months ended March 31, 2014. Other revenue deduction expenses increased $2,776,063. These are costs passed-through to the Company by the purchaser of the Companys gas. Such costs are deducted from the Companys gross revenue by the purchaser and include, but are not limited to: costs to market the Companys gas, compression fees, and the cost of fuel used by the purchaser to convey the Companys gas. Lease operating expense increased $1,552,544 and workovers expenses increased $670,889, but were partially offset by a $169,575 decrease in production taxes.
Accretion of Asset Retirement Obligation (ARO) was $226,635 for the nine months ended March 31, 2014.
General and Administrative Expenses increased to $4,735,950 for 2014 from $1,581,451 for 2013 primarily due to an increase of $877,680 in legal fees/expenses, a $559,305 increase in salaries (due to employee raises and new hires), a $1,113,458 increase in consulting and management fees and a $214,290 increase in contracted professional services, directly related to the Companys acquisitions and debt restructuring efforts, during the nine months ended March 31, 2014 as compared to the 2013 period.
Depreciation, Depletion and Amortization increased to $5,726,591 in 2014 from $2,537,883 in 2013. The increase was primarily due to the $90,037,491 increase in the full cost pool due to the acquisitions during the nine months ended March 31, 2014 as compared to March 31, 2013.
Derivatives Loss was $12,221,932 for the nine months ended March 31, 2014. There was no derivative gain or loss for the nine months ended March 31, 2013, as we had not engaged in any derivative transactions prior to the end of that quarter. The net derivative loss in the 2014 quarter was due to contract prices of $92 per barrel of oil and $3.90 per Mcf for natural gas generally being lower than the settlement prices.
Change in Fair Value of Warrants Liability of $12,017,693 was recognized for the nine months ended March 31, 2014. The fair value of warrants liability, associated with the Companys Class A and B warrants, which were issued in connection with the issuance of the Notes on October 2, 2013, decreased as of March 31, 2014, by $13,357,742. There was an overall decrease in fair value of warrants held by WFEC to $465,849 for the nine months ended March 31, 2014.
Interest Expense increased to $12,583,873 in 2014 from $2,110,403 in 2013 primarily due to interest incurred on the Notes issued on October 2, 2013, as well as interest on borrowings from WFEC. The Companys weighted average total debt (before discounts) was $69,375,858 for the nine months ended March 31, 2014 from $31,098,994 for the same 2013 period.
Capital Resources and Liquidity
Overview
The Companys primary resource is its oil and gas reserves. Our strategy with respect to our domestic exploration program seeks to maintain a balanced portfolio of drilling opportunities that range from lower risk, field extension wells to the smaller scale pursuit of Company appropriate higher risk, high reserve potential prospects.
Our recent acquisition of East Texas Basin assets is at the core of our current strategy, providing lower risk development opportunities and high yield opportunities within the same property. The Company is exploring acquiring additional properties with this similar development profile.
Additionally, our focus is on exploration opportunities that can benefit from advanced technologies, including 3-D seismic, designed to reduce risks and increase success rates. We develop prospects in-house with an affiliate and through strategic alliances with exploration companies that have expertise in specific target areas. In addition, we evaluate externally generated prospects and look to participate in certain of these opportunities to enhance our portfolio.
We are currently focusing our domestic exploration activities to develop, re-enter, and re-complete existing well bores with respect to our recently acquired East Texas Basin assets; as well as developing our recently augmented leasehold interests in Louisiana. Our East Texas Basin prospects have been developed from the top of the Cretaceous formations all the way to the bottom of the Deep Bossier Shale. The various Cretaceous zones all have strong oil and liquids component that will help the Company achieve its transition away from dry natural gas. The high production of dry natural gas from the various Bossier sands has the opportunity to provide us a significant increase in short term cash flow without substantial out-of-pocket expenditures, even at current commodity prices, through the re-recompletion and work over of existing wells. Prospects in our Louisiana leaseholds are focused on the Cotton Valley and the Haynesville Shale, but also include the Hosston; Gloyd; Pettet; Glen Rose and Paluxy.
Product prices, over which we have no control, have a significant impact on revenues from production and the value of such reserves and thereby on our borrowing capacity. Within the confines of product pricing, we
need to be able to find and develop or acquire oil and gas reserves in a cost effective manner in order to generate sufficient financial resources through internal means to finance our capital expenditure program.
Working Capital and Capital Expenditures
Working capital as of March 31, 2014 was over $2 million, up from a working capital deficit of over $35 million at June 30, 2013, as a result of proceeds from the issuance of the Notes, the Call Option Structured Derivative arrangement and the refinancing of the WFEC debt. The debt to WFEC is now classified as long-term debt.
The Company entered into a Note Purchase Agreement dated October 2, 2013, pursuant to which the Company issued an aggregate of $66,000,000 (see Note F to the condensed consolidated financial statements) of senior secured notes due October 2, 2016, to certain purchasers. Pursuant to the terms of the Credit Agreement with WFEC, the Company repaid the $5 million term loan, and Cubic Louisiana assumed the remaining unpaid debt to WFEC, which amount was $20,865,110 as of that date. That debt is reflected in a term loan bearing interest at the Wells Fargo Bank prime rate, plus 2%, per annum and is due October 2, 2016. In the event that Cubic Louisiana does not have available cash to pay interest on the debt under the Credit Agreement, accrued and unpaid interest will be paid in kind via an additional promissory note. As part of the Credit Agreement, WFEC is providing a revolving credit facility in the amount of up to $10,000,000, bearing interest at the same rate, with all advances under that revolving credit facility to be made in the sole discretion of WFEC. Also on October 2, 2013, the Company entered into a Call Option Structured Derivative arrangement (see Note H to the condensed consolidated financial statements) that provided the Company an upfront derivative payment of approximately $35,000,000, and together with the proceeds from the issuance of the senior secured notes, a total of $101,000,000. Approximately $20,000,000 of these funds remained available for capital expenditures and working capital for operations, as of March 31, 2014.
On October 2, 2013, Mr. Wallen was issued 2,115 shares of Series B preferred stock, with an aggregate stated value of $2,115,000, in exchange for the cancellation of a promissory note payable to Mr. Wallen in the principal amount of $2,000,000, plus $114,986 of accrued and unpaid interest. The promissory note was classified as a current debt.
The majority of our oil and gas reserves are undeveloped. As such, recovery of the Companys future undeveloped proved reserves will require significant capital expenditures. Management estimates that aggregate capital expenditures ranging from a minimum of approximately $45,000,000 and a maximum of approximately $60,000,000 will be made to further develop our reserves during fiscal 2014 and fiscal 2015 for exploratory drilling on our undeveloped acreage. The Company may increase its planned activities for fiscal 2014 and fiscal 2015, if the Company acquires additional oil or natural gas properties. The new Louisiana acreage is approximately 99% operated by Fossil and approximately 1% operated by Indigo Minerals on Cotton Valley wells.
No assurance can be given that all or any of these anticipated or possible capital expenditures will be completed as currently anticipated. Any material acquisition of additional leaseholds would require that we obtain additional capital resources.
The Company plans to fund its development and exploratory activities through cash on hand, cash provided from operations, and a possible disposition of assets, if needed, or other transactions.
As future cash flows, the availability of borrowings, and the ability to consummate any of the aforementioned potential transactions are subject to a number of variables, such as prevailing prices of oil and gas, actual production from existing and newly-completed wells, the Companys success in developing and producing new reserves, the uncertainty of financial markets and joint venture and merger and acquisition activity, and the uncertainty with respect to the amount of funds which may ultimately be
required to finance the Companys development and exploration program, there can be no assurance that the Companys capital resources will be sufficient to sustain the Companys development and exploratory activities. With funds generated through existing wells and cash on hand, we expect to be able to continue to pay our expenses as they come due.
If we are unable to obtain sufficient capital resources on a timely basis, the Company may need to curtail its planned development and exploratory activities. If a well is proposed by a third-party operator and the Company does not have the capital resources to participate in that well, the Company might not receive any revenue generated by that well, while still being required to fulfill the relevant royalty payment obligations to the mineral owner and other royalty holders. Additionally, because future cash flows and the availability of borrowings are subject to a number of variables, there can be no assurance that the Companys capital resources will be sufficient to sustain the Companys development and exploration activities.
Cash Flow
Our net (decrease) increase in cash and cash equivalents is summarized as follows:
|
|
Nine months ended |
| ||||
|
|
March 31, |
| ||||
|
|
2014 |
|
2013 |
| ||
Net cash provided (used) by operating activities |
|
$ |
(3,894,958 |
) |
$ |
256,313 |
|
Net cash provided (used) by investing activities |
|
(73,498,934 |
) |
9,647,535 |
| ||
Net cash provided (used) by financing activities |
|
86,490,797 |
|
(9,394,890 |
) | ||
Net increase in cash and cash equivalents |
|
$ |
9,096,905 |
|
$ |
508,958 |
|
Operating Activities During the nine months ended March 31, 2014, the Company used cash flows from operating activities of $3,894,958 as compared to $256,313 of cash provided in operating activities in the prior year period. Cash flow from operations is dependent on our ability to increase production through our development and exploratory activities and the price received for oil and natural gas.
Investing Activities The cash used in investing activities consists of capital expenditures related to the drilling and completion of new wells and the acquisition and development of additional oil and gas properties. In the nine months ended March 31, 2014, we had capital spending related to the acquisitions and development of oil and gas properties of $8,049,680 and has acquisition costs of $64,278,148 and total cash used of $73,498,934 by investing activities. In the nine months ended March 31, 2013, we had capital spending related to the acquisition and development of oil and gas properties of $431,843 and provided net cash of $9,647,535 from investing activities, of which approximately $10,000,000 was the payment of the remaining unused prepaid drilling credit, received as part of the EXCO/BG settlement.
Financing Activities Net cash flows were $86,490,797 provided and $9,394,890 used by financing activities during the nine month periods ended March 31, 2014 and 2013, respectively. During the 2014 period, we used $86,490,797 of cash provided by financing activities (see Note F to the condensed consolidated financial statements). These funds were received as part of the Notes provided by the Investors and upfront payments from derivative contracts. During the fiscal 2013 period, we used $260,000 to pay loan costs on the Wells Fargo extension and paid $9,134,890 on our debt to Wells Fargo.
Contractual Obligations
We have no material changes in our long-term commitments associated with our capital expenditure plans or operating agreements other than those described above. Our level of capital expenditures will vary in future periods depending on: the success we experience in our acquisition, development and exploration activities; oil and natural gas price conditions; and other related economic factors. Currently, no sources of liquidity or
financing are provided by off-balance sheet arrangements or transactions with unconsolidated, limited-purpose entities. We have no contractual commitments pertaining to exploration, development and production activities.
Critical Accounting Policies and Estimates
Our discussion and analysis of our financial condition and results of operation are based upon the condensed financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. Preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses. There have been no changes to our critical accounting policies from those described in our Annual Report on Form 10-K/A for the year ended June 30, 2013.
Item 3. Quantitative and Qualitative Disclosures About Market Risk.
Not Applicable
Item 4. Controls and Procedures
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we conducted an evaluation of our disclosure controls and procedures, as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, as of the end of the period covered by this report. Based on this evaluation, our principal executive officer and our principal financial officer concluded that our disclosure controls and procedures were not effective to provide reasonable assurance that information required to be disclosed by us in reports we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SECs rules and forms, and is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosures.
In September and October 2014, we identified material weaknesses in our internal controls over financial reporting in connection with our (i) financial reporting and disclosure process (ii) accounting for asset retirement obligations and (iii) accounting for certain complex accounting transactions. The first material weakness, our financial reporting and disclosure process, resulted in additional disclosures and amendments to our quarterly reports for the quarterly periods ended September 30, 2013, December 31, 2013 and March 31, 2014 necessary to present the financial statements in accordance with accounting principles generally accepted in the United States. The second material weakness, our accounting for asset retirement obligations (ARO), resulted in our inappropriate estimation of the ARO related to the properties acquired in our acquisitions in Fiscal 2014. Our third material weakness, our accounting for certain complex accounting transactions, resulted in an incorrect accounting treatment related to the warrants that were issued together with the Notes. The warrants contained full-ratchet anti-dilution adjustment provisions that were not properly accounted for. Additionally, certain warrants that were re-priced in 2013 and 2014 also contained certain anti-dilution provisions that were not accounted for correctly since their issuance date. Finally, we did not apply the proper accounting for the exchanges of certain related party debt and equity instruments in transactions that were deemed equity contributions. As a result of these material weaknesses, the Company has amended its September 30, 2013 and December 31, 2013 Form 10-Qs.
We note that there are inherent limitations on the effectiveness of internal controls, as they cannot prevent collusion, management override or failure of human judgment. If we fail to maintain an effective system
of internal controls or if management or our independent registered public accounting firm were to discover material weaknesses in our internal controls, we may be unable to produce reliable financial reports or prevent fraud, and it could harm our financial condition and results of operations, result in a loss of investor confidence and negatively impact our share price.
Changes in Internal Control over Financial Reporting
We maintain a system of internal control over financial reporting. There were material weaknesses in our internal control over financial reporting during the second quarter of fiscal 2014 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. The Company needs to hire qualified experts to review complex transactions like those consummated in October 2013, to ensure all items are receiving proper accounting treatment.
Inherent Limitations on Internal Control
A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, have been detected. These inherent limitations include the realities that judgments in decision making can be faulty, and that breakdowns can occur because of simple errors. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls is also based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected.
We are party to lawsuits arising in the normal course of business. We intend to defend these actions vigorously and believe, based on currently available information, that adverse results or judgments from such actions, if any, will not be material to our financial position or results of operations. The legal climate in Northwest Louisiana is hostile and litigious towards oil and gas companies; and the legal environment in East Texas is becoming increasingly competitive and hostile. Mineral owners are seeking opportunities to make additional money from their mineral rights, including pursuit of claims of lease expiration by asserting that production does not exist in paying quantities. In the normal course of our business, title defects and lease issues of varying degrees will arise, and, if practicable, reasonable efforts will be made to cure any such defects and issues.
A lawsuit was filed on or about June 15, 2010, styled, Glorias Ranch, LLC v. Tauren Exploration, Inc., Cubic Energy, Inc., Wells Fargo Energy Capital, Inc. & EXCO USA Asset, LLC, filed in the 1st Judicial District Court, Caddo Parish, Louisiana, Cause No. 541-768, A. This lawsuit alleges that all or part of the Glorias Ranch mineral lease has lapsed, and seeks a finding that the mineral lease has lapsed, damages, attorney fees, and other equitable relief. This lawsuit would have a material effect, with the lost acreage component having an estimated value of up to $9,100,000, if ultimately adjudicated entirely in favor of the mineral owner. The Company intends to vigorously defend its position and believes it will prevail regarding some, if not all, of the acreage at issue in this lawsuit.
None
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
None.
Item 3. Defaults Upon Senior Securities
None.
Item 4. Mine Safety Disclosures
None.
None.
No. |
|
Description | ||
|
|
| ||
31.1 |
|
*Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer | ||
|
|
| ||
31.2 |
|
*Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer | ||
|
|
| ||
32.1 |
|
*Certification of Chief Executive Officer pursuant to 18 U.S.C. § 1350 | ||
|
|
| ||
32.2 |
|
*Certification of Chief Financial Officer pursuant to 18 U.S.C. § 1350 | ||
|
|
| ||
101.INS* |
|
XBRL Instance Document | ||
|
|
| ||
101.SCH* |
|
XBRL Taxonomy Extension Schema Document | ||
|
|
| ||
101.CAL* |
|
XBRL Taxonomy Calculation Linkbase Document | ||
|
|
| ||
101.DEF* |
|
XBRL Taxonomy Definition Linkbase Document | ||
|
|
| ||
101.LAB* |
|
XBRL Taxonomy Label Linkbase Document | ||
|
|
| ||
101.PRE* |
|
XBRL Taxonomy Presentation Linkbase Document | ||
* Filed herewith.
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
|
CUBIC ENERGY, INC. | |
|
(Registrant) | |
|
| |
|
|
|
Date: April 15, 2015 |
By: |
/s/ Calvin A. Wallen, III |
|
|
Calvin A. Wallen, III, President and Chief Executive Officer |
|
|
|
Date: April 15, 2015 |
By: |
/s/ Larry G. Badgley |
|
|
Larry G. Badgley, Chief Financial Officer |