UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
FORM 10-Q
x | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended:JuneSeptember 30, 2014
or
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
Commission file number: 001-3473
“COAL KEEPS YOUR LIGHTS ON” | “COAL KEEPS YOUR LIGHTS ON” |
HALLADOR ENERGY COMPANY
(www.halladorenergy.com)
Colorado | 84-1014610 | |
(State of incorporation) | (IRS Employer Identification No.) | |
1660 Lincoln Street, Suite 2700, Denver, Colorado | 80264-2701 | |
(Address of principal executive offices) | (Zip Code) |
Issuer's telephone number: 303.839.5504
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. Yesþ Noo¨
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 during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yesþ Noo¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "larger accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.
¨ Large accelerated filer | þ Accelerated filer |
¨ Non-accelerated filer (do not check if a small reporting company) | ¨ Smaller reporting company |
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yeso¨ Noþ
As of August 1,November 10, 2014 we had 28,771,00028,778,000 shares outstanding.outstanding.
PART I - Financial Information
ITEM 1. FINANCIAL STATEMENTS
Consolidated Balance Sheet
(in thousands, except per share data)thousands)
June 30, | December 31, | September 30, | December 31, | |||||||||||||
2014 | 2013 | 2014 | 2013 | |||||||||||||
ASSETS | ||||||||||||||||
Current assets: | ||||||||||||||||
Cash and cash equivalents | $ | 21,025 | $ | 16,228 | $ | 22,018 | $ | 16,228 | ||||||||
Marketable securities | 1,753 | 1,720 | ||||||||||||||
Accounts receivable | 10,653 | 10,577 | 35,698 | 10,577 | ||||||||||||
Amounts due from Vectren | 8,200 | |||||||||||||||
Prepaid income taxes | 340 | 4,661 | 2,541 | 4,661 | ||||||||||||
Coal inventory | 6,448 | 4,778 | 17,883 | 4,778 | ||||||||||||
Parts and supply inventory | 2,609 | 2,826 | 14,902 | 2,826 | ||||||||||||
Other | 82 | 291 | 4,173 | 291 | ||||||||||||
Total current assets | 42,910 | 39,361 | 107,135 | 39,361 | ||||||||||||
Coal properties, at cost: | ||||||||||||||||
Land and mineral rights | 27,704 | 26,476 | 130,492 | 26,476 | ||||||||||||
Buildings and equipment | 155,405 | 148,077 | 335,059 | 148,077 | ||||||||||||
Mine development | 85,813 | 85,333 | 86,395 | 85,333 | ||||||||||||
268,922 | 259,886 | 551,946 | 259,886 | |||||||||||||
Less - accumulated DD&A | (87,605 | ) | (77,545 | ) | (94,523 | ) | (77,545 | ) | ||||||||
181,317 | 182,341 | 457,423 | 182,341 | |||||||||||||
Investment in Savoy | 18,582 | 16,733 | 19,258 | 16,733 | ||||||||||||
Investment in Sunrise Energy | 4,660 | 4,573 | 4,764 | 4,573 | ||||||||||||
Other assets (Note 5) | 17,000 | 17,405 | 22,377 | 17,405 | ||||||||||||
$ | 264,469 | $ | 260,413 | $ | 610,957 | $ | 260,413 | |||||||||
LIABILITIES AND STOCKHOLDERS' EQUITY | ||||||||||||||||
Current liabilities: | ||||||||||||||||
Current portion of long-term debt | $ | 19,688 | $ | |||||||||||||
Accounts payable and accrued liabilities | $ | 11,688 | $ | 10,357 | 29,512 | 10,357 | ||||||||||
Total current liabilities | 49,200 | 10,357 | ||||||||||||||
Long-term liabilities: | ||||||||||||||||
Bank debt | 16,000 | 16,000 | 325,938 | 16,000 | ||||||||||||
Deferred income taxes | 40,899 | 43,304 | 39,237 | 43,304 | ||||||||||||
Asset retirement obligations | 5,443 | 5,290 | 11,856 | 5,290 | ||||||||||||
Other | 1,448 | 2,128 | 1,838 | 2,128 | ||||||||||||
Total long-term liabilities | 63,790 | 66,722 | 378,869 | 66,722 | ||||||||||||
Total liabilities | 75,478 | 77,079 | 428,069 | 77,079 | ||||||||||||
Commitments and contingencies (Note 10) | ||||||||||||||||
Commitments and contingencies | ||||||||||||||||
Stockholders' equity: | ||||||||||||||||
Preferred Stock, $.10 par value, 10,000 shares authorized; none issued | ||||||||||||||||
Common stock, $.01 par value, 100,000 shares authorized; 28,771 and 28,751 shares outstanding, respectively | 287 | 287 | ||||||||||||||
Common stock, $.01 par value, 100,000 shares authorized; | ||||||||||||||||
28,778 and 28,751 shares outstanding, respectively | 287 | 287 | ||||||||||||||
Additional paid-in capital | 89,141 | 87,872 | 90,112 | 87,872 | ||||||||||||
Retained earnings | 98,996 | 94,796 | 92,029 | 94,796 | ||||||||||||
Accumulated other comprehensive income | 567 | 379 | 460 | 379 | ||||||||||||
Total stockholders’ equity | 188,991 | 183,334 | 182,888 | 183,334 | ||||||||||||
$ | 264,469 | $ | 260,413 | $ | 610,957 | $ | 260,413 |
See accompanying notes.
Consolidated Statement of Comprehensive Income (Loss)
(in thousands, except per share data)
Six months ended | Three months ended | Nine months ended | Three months ended | |||||||||||||||||||||||||||||
June 30, | June 30, | September 30, | September 30, | |||||||||||||||||||||||||||||
2014 | 2013 | 2014 | 2013 | 2014 | 2013 | 2014 | 2013 | |||||||||||||||||||||||||
Revenue: | ||||||||||||||||||||||||||||||||
Coal sales | $ | 69,146 | $ | 68,144 | $ | 36,130 | $ | 34,149 | $ | 133,910 | $ | 103,129 | $ | 64,764 | $ | 34,985 | ||||||||||||||||
Equity income - Savoy | 4,514 | 2,447 | 2,135 | 1,363 | 5,731 | 4,495 | 1,217 | 2,048 | ||||||||||||||||||||||||
Equity income (loss) - Sunrise Energy | 87 | 347 | (2 | ) | 225 | |||||||||||||||||||||||||||
Equity income - Sunrise Energy | 191 | 519 | 104 | 172 | ||||||||||||||||||||||||||||
Liability extinguishment (Note 9) | 4,300 | 4,300 | 4,300 | |||||||||||||||||||||||||||||
Other (Note 5) | 480 | 3,160 | 197 | 699 | 717 | 3,615 | 237 | 455 | ||||||||||||||||||||||||
74,227 | 78,398 | 38,460 | 40,736 | 140,549 | 116,058 | 66,322 | 37,660 | |||||||||||||||||||||||||
Costs and expenses: | ||||||||||||||||||||||||||||||||
Operating costs and expenses | 49,101 | 45,552 | 26,096 | 22,262 | 101,689 | 68,959 | 52,588 | 23,407 | ||||||||||||||||||||||||
DD&A | 10,152 | 9,210 | 5,193 | 4,650 | 17,131 | 13,982 | 6,979 | 4,772 | ||||||||||||||||||||||||
Coal exploration costs | 1,191 | 986 | 526 | 447 | 1,907 | 1,725 | 716 | 739 | ||||||||||||||||||||||||
SG&A | 4,709 | 3,650 | 2,738 | 1,674 | 7,220 | 5,586 | 2,511 | 1,936 | ||||||||||||||||||||||||
Interest | 862 | 823 | 397 | 447 | 2,687 | 1,131 | 1,825 | 308 | ||||||||||||||||||||||||
Write off deferred financing costs | 1,021 | 1,021 | ||||||||||||||||||||||||||||||
Vectren deal costs (Note 10) | 7,891 | 7,891 | ||||||||||||||||||||||||||||||
66,015 | 60,221 | 34,950 | 29,480 | 139,546 | 91,383 | 73,531 | 31,162 | |||||||||||||||||||||||||
Income before income taxes | 8,212 | 18,177 | 3,510 | 11,256 | ||||||||||||||||||||||||||||
Income (loss) before income taxes | 1,003 | 24,675 | (7,209 | ) | 6,498 | |||||||||||||||||||||||||||
Less income taxes: | ||||||||||||||||||||||||||||||||
Current | 4,401 | 1,906 | 3,169 | 1,105 | 4,244 | 1,297 | (157 | ) | (609 | ) | ||||||||||||||||||||||
Deferred | (2,783 | ) | 2,638 | (2,727 | ) | 1,986 | (4,067 | ) | 4,915 | (1,284 | ) | 2,277 | ||||||||||||||||||||
1,618 | 4,544 | 442 | 3,091 | 177 | 6,212 | (1,441 | ) | 1,668 | ||||||||||||||||||||||||
Net income(1) | $ | 6,594 | $ | 13,633 | $ | 3,068 | $ | 8,165 | ||||||||||||||||||||||||
Net income (loss)(1) | $ | 826 | $ | 18,463 | $ | (5,768 | ) | $ | 4,830 | |||||||||||||||||||||||
Net income per share: (Note 8) | ||||||||||||||||||||||||||||||||
Net income (loss) per share: (Note 8) | ||||||||||||||||||||||||||||||||
Basic | $ | 0.22 | $ | 0.48 | $ | 0.10 | $ | 0.29 | $ | 0.03 | $ | 0.65 | $ | (0.20 | ) | $ | 0.17 | |||||||||||||||
Diluted | $ | 0.22 | $ | 0.47 | $ | 0.10 | $ | 0.28 | $ | 0.03 | $ | 0.64 | $ | (0.20 | ) | $ | 0.17 | |||||||||||||||
Weighted average shares outstanding: | ||||||||||||||||||||||||||||||||
Basic | 28,763 | 28,566 | 28,770 | 28,604 | 28,766 | 28,580 | 28,772 | 28,607 | ||||||||||||||||||||||||
Diluted | 29,001 | 28,849 | 29,057 | 28,763 | 29,108 | 28,851 | 29,310 | 28,838 |
(1) There is no material difference between net income (loss) and comprehensive income.income (loss).
See accompanying notes.
Consolidated Condensed Statement of Cash Flows
(in thousands)
Six months ended | Nine months ended | |||||||||||||||
June 30, | September 30, | |||||||||||||||
2014 | 2013 | 2014 | 2013 | |||||||||||||
Operating activities: | ||||||||||||||||
Cash provided by operating activities | $ | 16,437 | $ | 12,961 | $ | 20,730 | $ | 20,310 | ||||||||
Investing activities: | ||||||||||||||||
Capital expenditures for coal properties | (9,126 | ) | (14,778 | ) | (14,326 | ) | (23,558 | ) | ||||||||
Ohio River Terminal | (2,823 | ) | (2,866 | ) | ||||||||||||
Purchase of marketable securities | (1,414 | ) | ||||||||||||||
Vectren Fuels acquisition | (319,762 | ) | ||||||||||||||
Other | 161 | 256 | ||||||||||||||
Cash used in investing activities | (9,126 | ) | (18,854 | ) | (334,088 | ) | (26,168 | ) | ||||||||
Financing activities: | ||||||||||||||||
Dividends | (2,394 | ) | (1,159 | ) | (3,593 | ) | (2,317 | ) | ||||||||
Other | (120 | ) | ||||||||||||||
Cash used in financing activities | (2,514 | ) | (1,159 | ) | ||||||||||||
Bank borrowings | 350,000 | |||||||||||||||
Payments on bank debt | (20,375 | ) | ||||||||||||||
Deferred financing costs | (6,884 | ) | ||||||||||||||
Cash provided by (used in) financing activities | 319,148 | (2,317 | ) | |||||||||||||
Increase (decrease) in cash and cash equivalents | 4,797 | (7,052 | ) | 5,790 | (8,175 | ) | ||||||||||
Cash and cash equivalents, beginning of period | 16,228 | 21,888 | 16,228 | 21,888 | ||||||||||||
Cash and cash equivalents, end of period | $ | 21,025 | $ | 14,836 | $ | 22,018 | $ | 13,713 |
See accompanying notes.
Consolidated Statement of Stockholders' Equity
(in thousands)
Common | Additional Paid- | Retained | Common | Additional Paid- | Retained | |||||||||||||||||||||||||||||||||||||||||||
Shares | Stock | in Capital | Earnings | AOCI* | Total | Shares | Stock | in Capital | Earnings | AOCI* | Total | |||||||||||||||||||||||||||||||||||||
Balance, January 1, 2014 | 28,751 | $ | 287 | $ | 87,872 | $ | 94,796 | $ | 379 | $ | 183,334 | 28,751 | $ | 287 | $ | 87,872 | $ | 94,796 | $ | 379 | $ | 183,334 | ||||||||||||||||||||||||||
Stock-based compensation | 1,322 | 1,322 | 7 | 2,289 | 2,289 | |||||||||||||||||||||||||||||||||||||||||||
Other | 20 | (53 | ) | 188 | 135 | 20 | (49 | ) | 81 | 32 | ||||||||||||||||||||||||||||||||||||||
Dividends | (2,394 | ) | (2,394 | ) | (3,593 | ) | (3,593 | ) | ||||||||||||||||||||||||||||||||||||||||
Net income | 6,594 | 6,594 | 826 | 826 | ||||||||||||||||||||||||||||||||||||||||||||
Balance, June 30, 2014 | 28,771 | $ | 287 | $ | 89,141 | $ | 98,996 | $ | 567 | $ | 188,991 | |||||||||||||||||||||||||||||||||||||
Balance, September 30, 2014 | 28,778 | $ | 287 | $ | 90,112 | $ | 92,029 | $ | 460 | $ | 182,888 |
*Accumulated Other Comprehensive Income
See accompanying notes.
5 |
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(1) General Business
The interim financial data is unaudited; however, in our opinion, it includes all adjustments, consisting only of normal recurring adjustments necessary for a fair statement of the results for the interim periods. The financial statements included herein have been prepared pursuant to the SEC’s rules and regulations; accordingly, certain information and footnote disclosures normally included in GAAP financial statements have been condensed or omitted.
The results of operations and cash flows for the sixnine months ended JuneSeptember 30, 2014 are not necessarily indicative of the results to be expected for future quarters or for the year ending December 31, 2014. To maintain consistency and comparability, certain 2013 amounts have been reclassified to conform to the 2014 presentation.
Our organization and business, the accounting policies we follow and other information, are contained in the notes to our consolidated financial statements filed as part of our 2013 Form 10-K. This quarterly report should be read in conjunction with such 10-K.
The consolidated financial statements include the accounts of Hallador Energy Company (the Company) and its wholly-owned subsidiary Sunrise Coal, LLC (Sunrise). and Sunrise’s wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated. We are engaged in the production of steam coal from mines located in western Indiana. We own a 45%40% equity interest in Savoy Energy, L.P., a private oil and gas company which has operations in Michigan and a 50% interest in Sunrise Energy, LLC, a private entity engaged in natgas operations in the same vicinity as the Carlisle mine.
(2) Bank Debt
During October 2012, Sunrise Coal, our wholly-owned subsidiary,To finance the Vectren Fuels acquisition (see Note 10) we entered into a new credit agreement (the “Credit Agreement”) with PNC Bank as administrative agent for a group of several other banks. The credit agreement allows for a $250 million revolver and a $175 million term loan. Considering the acquisition and the lenders named therein. The Credit Agreement replaces the previous credit agreement we had with PNC. Closing costs on this new facility were about $1.5 million which were deferred and are being amortized over five years. Outstandingpayment of bank fees, our debt at JuneSeptember 30, 2014 was $16is $345.6 million.
The Credit Agreement provides for a $165maximum that we can currently borrow is $398 million senior secured revolvingdue to the covenants. The credit facility. The facility matures in five years. The facility is collateralized by substantially all of Sunrise’s assets and we are the guarantor. We will draw on theBank fees and other costs incurred in connection with this new facility as needed for development ofwere about $6.8 million which were deferred and are being amortized over five years. Deferred financing costs, associated with our new projects in Illinoisprevious credit facility, approximated $1 million and Indiana.were expensed.
All borrowings under the Credit Agreementcredit agreement bear interest at LIBOR plus 2%2.25% if the leverage ratio is less than 1.5X (which currently it is),1X; LIBOR plus 2.5% if the leverage ratio is over 1.51X but less than 1.5X; LIBOR plus 2.75% if the ratio is over 1.5X but less than 2X; LIBOR plus 3% if the ratio is over 2X but less than 2.5X and at LIBOR plus 3%3.5% if the leverage ratio is over 2X.2.5X (which it currently is). We are required to pay at the highest rate (LIBOR plus 3.5%) through the first quarter of 2015. The maximum leverage ratio is 2.75X.currently 3.25X. The leverage ratio is equal to funded debt/EBITDA. The annual commitment fee is 50 BPS but fallsWe entered into swap agreements to 37.5 BPS if we borrow more than 33%fix the LIBOR component of the facility.interest rate to achieve an effective fixed rate of no greater than 5% on 100% ($175 million) of the term loan and on $100 million of the revolver. The maximum that we can currently borrow is $102 million due to our current covenants. revolver steps down 10% each quarter commencing March 31, 2016. As of September 30, 2014 these two interest rate swaps had a de minimus fair value.
The Credit Agreementcredit agreement also imposes certain other customary restrictions and covenants as well as certain milestones we must meet in order to draw down the full amount. Any non-tax cash distributions from Savoy are required to be applied toward the debt. The term loan requires annual amortization during the five years at 10%, 15%, 15%, 20%, and 20% with a balloon at maturity.
See Note 10 regarding ourThe credit agreement matures on August 29, 2019, but we have the right to purchase Vectren Fuels.prepay the loan at any time without penalty.
(3) Investment in Savoy
We currently own a 45%40% interest in Savoy Energy, L.P., a private company engaged in the oil and gas business primarily in the state of Michigan. Savoy uses the successful efforts method of accounting. We account for our interest using the equity method of accounting. Our ownership was 45% but was decreased on October 1, 2014 due to the exercise of options by Savoy’s management.
Below (in thousands) to the 100% is a condensed balance sheet at JuneSeptember 30, 2014, and a condensed statement of operations for the sixnine months ended JuneSeptember 30, 2014 and 2013.
Condensed Balance Sheet
2014 | 2014 | |||||||
Current assets | $ | 31,544 | $ | 27,247 | ||||
Oil and gas properties, net | 27,868 | 28,940 | ||||||
$ | 59,412 | $ | 56,187 | |||||
Total liabilities | $ | 16,234 | $ | 10,814 | ||||
Partners' capital | 43,178 | 45,373 | ||||||
$ | 59,412 | $ | 56,187 |
Condensed Statement of Operations
2014 | 2013 | 2014 | 2013 | |||||||||||||
Revenue | $ | 24,493 | $ | 18,373 | $ | 32,135 | $ | 29,444 | ||||||||
Expenses | (14,480 | ) | (12,946 | ) | (19,423 | ) | (19,471 | ) | ||||||||
Net income | $ | 10,013 | $ | 5,427 | $ | 12,712 | $ | 9,973 |
Late last year Savoy engaged Energy Spectrum Advisors Inc. (ESA) to market its Trenton-Black River oil properties located in southeast Michigan. ESA has offices in Dallas and Houston. Information was posted to the ESA websiteNo acceptable offers were received. Marketing efforts are on hold until oil prices recover. Savoy made a $12 million cash distribution in early March 2014. Savoy terminated discussions with a prospective buyer and we are now exploring other alternatives to monetizeOctober 2014; our Savoy investment.share was $4.9 million; such amount was applied toward our bank debt.
7 |
(4) Investment in Sunrise Energy
We own a 50% interest in Sunrise Energy, LLC, a private company engaged in the oil and gas business that develops and explores for coal-bed methane gas reserves on or near our underground coal reserves. They use the successful efforts method of accounting. We account for our interest using the equity method of accounting.
Below (in thousands) to the 100% is a condensed balance sheet at JuneSeptember 30, 2014, and a condensed statement of operations for the sixnine months ended JuneSeptember 30, 2014 and 2013.
Condensed Balance Sheet
2014 | 2014 | |||||||
Current assets | $ | 3,315 | $ | 3,496 | ||||
Oil and gas properties, net | 6,837 | 6,745 | ||||||
$ | 10,152 | $ | 10,241 | |||||
Total liabilities | $ | 854 | $ | 724 | ||||
Members' capital | 9,298 | 9,517 | ||||||
$ | 10,152 | $ | 10,241 |
Condensed Statement of Operations
2014 | 2013 | |||||||
Revenue | $ | 1,583 | $ | 1,691 | ||||
Expenses | (1,409 | ) | (997 | ) | ||||
Net income | $ | 174 | $ | 694 | ||||
2014 | 2013 | |||||||
Revenue | $ | 2,328 | $ | 2,551 | ||||
Expenses | (1,945 | ) | (1,513 | ) | ||||
Net income | $ | 383 | $ | 1,038 |
8 |
(5) Other Long-Term Assets and Other Income
June 30, 2014 | December 31, 2013 | September 30, 2014 | December 31, 2013 | |||||||||||||
Long-term assets: | ||||||||||||||||
Advance coal royalties | $ | 5,188 | $ | 4,693 | $ | 5,462 | $ | 4,693 | ||||||||
Deferred financing costs, net | 1,166 | 1,195 | 6,855 | 1,195 | ||||||||||||
Marketable equity securities available for sale, at fair value (restricted)* | 2,503 | 3,889 | 2,374 | 3,889 | ||||||||||||
Ohio River Terminal (see Note 7) | 2,744 | 2,836 | 2,698 | 2,836 | ||||||||||||
Other | 5,399 | 4,792 | 4,988 | 4,792 | ||||||||||||
$ | 17,000 | $ | 17,405 | $ | 22,377 | $ | 17,405 |
*Held by Sunrise Indemnity, Inc., our wholly-owned captive insurance company.
Six months ended | Nine months ended | |||||||||||||||
June 30, | September 30, | |||||||||||||||
2014 | 2013 | 2014 | 2013 | |||||||||||||
Other income: | ||||||||||||||||
MSHA reimbursements* | $ | 2,053 | $ | 2,053 | ||||||||||||
Coal storage fees | $ | 83 | 586 | $ | 83 | 964 | ||||||||||
Miscellaneous | 397 | 521 | 634 | 598 | ||||||||||||
$ | 480 | $ | 3,160 | $ | 717 | $ | 3,615 |
_______________________
*See “MSHA Reimbursements” on page 20.
(6) Self Insurance
In late August 2010 we decided to terminate the property insurance on our underground mining equipment. Such equipment is allocated among five13 mining units spread out over 1423 miles. The historical cost of such equipment is about $111$245 million.
(7) Ohio River Terminal
On May 31, 2013 we purchased for $2.8 million a multi-commodity truck/barge terminal. Over 17 acres of secured area is available. The terminal is at mile point 743.8 on the Indiana bank of the Ohio River near the William Natcher Bridge between Rockport and Grandview, Indiana. Currently the dock will handle third party commodities. In the long term, we plan to ship coal through the dock. The terminal is in close proximity to the NS railroad, the CSX railroad, and American Electric Power's Rockport generating power plant. We do not expect revenue from this asset until 2015.
(8) EarningsNet Income (Loss) per Share
We compute earningsnet income (loss) per share using the two-class method, which is an earnings allocation formula that determines earningsnet income (loss) per share for common stock and participating securities which for us are our outstanding RSUs (restricted stock units).
The following table sets forth the computation of earningsnet income (loss) per share for the threenine and sixthree months ended JuneSeptember 30, 2014.The adjustments for 2013 were not significant (in(in thousands, except per share amounts):
Six months | Three months | Nine months | Three months | |||||||||||||
Numerator: | ||||||||||||||||
Net income | $ | 6,594 | $ | 3,068 | ||||||||||||
Net income (loss) | $ | 826 | $ | (5,768 | ) | |||||||||||
Less: earnings allocated to RSUs | (263 | ) | (125 | ) | (23 | ) | ||||||||||
Net income available to common shareholders | $ | 6,331 | $ | 2,943 | ||||||||||||
Net income (loss) available to common shareholders | $ | 803 | $ | (5,768 | ) | |||||||||||
Denominator: | ||||||||||||||||
Average number of common shares outstanding | 28,763 | 28,770 | 28,766 | 28,772 | ||||||||||||
Potential dilutive shares | 238 | 287 | 342 | 538 | ||||||||||||
Average number of diluted shares outstanding | 29,001 | 29,057 | 29,108 | 29,310 | ||||||||||||
Earnings per share: | ||||||||||||||||
Net income (loss) per share: | ||||||||||||||||
Basic | $ | 0.22 | $ | 0.10 | $ | 0.03 | $ | (0.20 | ) | |||||||
Diluted | $ | 0.22 | $ | 0.10 | $ | 0.03 | $ | (0.20 | ) |
(9)Liability Extinguishment
During the 2013 second quarter we concluded that an approximate $4.3 million liability we recorded during 2006 upon the purchase of Sunrise Coal relating to a terminated coal contract was no longer required. The amount had no effect on cash flows.
10 |
(10) Vectren Fuels Pending Acquisition
On July 1,August 29, 2014, Sunrise Coal, LLC entered into an agreement to purchasewe consummated the acquisition of all the common stock of Vectren Fuels, Inc. (a wholly-owned coal mining subsidiary(VFI) for $320 million, which was accounted for as a business acquisition requiring measurement of Vectren Corporation (NYSE:VVC)).acquired assets and assumed liabilities at their estimated fair value in applying purchase accounting. The estimated fair values are based on market participant assumptions. The acquisition was financed through a new debt facility, and the preliminary purchase price allocation and use of proceeds from the new debt facility were as follows (assets not received or liabilities not assumed were retained by the parent company of VFI):
Assets received: | ||||
Accounts receivable | $ | 25,109 | ||
Coal inventory | 21,484 | |||
Parts and supply inventory | 13,176 | |||
Advance royalties | 685 | |||
Prepaid expenses | 909 | |||
Land and mineral rights | 103,577 | |||
Buildings and equipment | 174,180 | |||
Total assets received | 339,120 | |||
Liabilities assumed: | ||||
Accounts payable and accrued liabilities | 12,808 | |||
Asset retirement obligations | 6,550 | |||
Total liabilities assumed | 19,358 | |||
Total consideration paid for VFI | $ | 319,762 | ||
Use of proceeds from new debt facility: | ||||
Cash | $ | 1,805 | ||
Consideration paid for VFI | 319,762 | |||
Deferred financing costs | 6,163 | |||
Payoff existing debt facility | 16,149 | |||
Acquisition costs paid at closing | 6,121 | |||
Total | $ | 350,000 |
Vectren Fuels, headquartered in Evansville, Indiana, owns three underground coal mines in southwestern Indiana, including
The allocation of the Oaktown 1 and Oaktown 2 mines in Oaktown, Indiana,purchase price is preliminary pending the completion of various analyses and the Prosperity Mine locatedfinalization of estimates. During the measurement period (which is not to exceed one year from the acquisition date), additional assets or liabilities may be recognized if new information is obtained about facts and circumstances that existed as of the acquisition date that, if known, would have resulted in Petersburg, Indiana.the recognition of those assets or liabilities as of that date. The preliminary allocation may be adjusted after obtaining additional information regarding, among other things, asset valuations, liabilities assumed and revisions of previous estimates. These adjustments may be significant and will be accounted for retrospectively. The closing expenses include certain contract termination costs related to the termination of a contract post combination, which was to our benefit.
The two underground minesacquisition generated $26.6 million of revenue and $2.5 million of pretax income since the August 29, 2014 acquisition date, and these amounts are included in Oaktown, Indiana are seven miles south of our Carlisle underground mine. operations for the nine months ended September 30, 2014.
The purchase price is $296 million plus additional working capital adjustments, not to exceed a total of $325 million. Sunrise is working with its group of banks headed by PNC Bank to securefollowing unaudited pro forma information has been prepared for illustrative purposes only and assumes the necessary financing. Weacquisition occurred on January 1, 2013. The unaudited pro forma results have been advised by PNC that commitmentsprepared based on estimates and assumptions, which we believe are reasonable, however, they are not necessarily indicative of the consolidated results of operations had the acquisition occurred on January 1, 2013, or of future results of operations. Vectren deal costs of $7.9 million have been excluded from the various banks in the syndication exceed the amount necessary to fund the acquisition. Closing is expected to occur around September 1, 2014.pro forma amounts.
Nine Months Ended September 30, | ||||||||
2014 | 2013 | |||||||
(In thousands, except per share data) | ||||||||
Total Revenues | ||||||||
As reported | $ | 140,549 | $ | 116,058 | ||||
Pro forma | $ | 361,464 | $ | 335,625 | ||||
Net income applicable to common shareholders | ||||||||
As reported | $ | 826 | $ | 18,463 | ||||
Pro forma | $ | 33,843 | $ | 34,877 | ||||
Basic net income per share applicable to common shareholders | ||||||||
As reported | $ | 0.03 | $ | 0.65 | ||||
Pro forma | $ | 1.18 | $ | 1.22 |
REPORT OF INDEPENDENT REGISTERD PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders
Hallador Energy Company
Denver, Colorado
We have reviewed the accompanying condensed consolidated balance sheet of Hallador Energy Company and subsidiaries (the “Company”) as of JuneSeptember 30, 2014 and the related condensed consolidated statements of comprehensive income (loss), cash flows, and stockholders’ equity for the three and sixnine month periods ended JuneSeptember 30, 2014 and JuneSeptember 30, 2013. These financial statements are the responsibility of the Company’s management.
We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.
Based on our reviews, we are not aware of any material modifications that should be made to the accompanying condensed consolidated interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.
We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of the Company as of December 31, 2013, and the related consolidated statements of comprehensive income, cash flows, and stockholders’ equity for the year then ended (not presented herein); and in our report dated February 28, 2014, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, 2013, is fairly stated, in all material respects, in relation to the balance sheet from which it has been derived.
/s/ EKS&H LLLP |
August 1,November 10, 2014
Denver, Colorado
ITEM 2. MD&A
The following discussion updates the MD&A section of our 2013
Form 10-K and should be read in conjunction therewith.
Our consolidated financial statements should be read in conjunction with this discussion.
Overview
The largest portion of our business is devoted to coal mining in the state of Indiana through Sunrise Coal, LLC (a wholly-owned subsidiary) serving the electric power generation industry. We also own a 45%40% equity interest in Savoy Energy, L.P., a private oil and gas exploration company with operations in Michigan, and a 50% interest in Sunrise Energy, LLC, a private gas exploration company with operations in Indiana. We account for our investments in Savoy and Sunrise Energy using the equity method.
Our largest contributor to revenue and earnings ishas been the Carlisle underground coal mine located in western Indiana, about 30 miles south of Terre Haute. We now expect both Oaktown 1 and Oaktown 2 to significantly contribute to revenue and earnings. For 2014 over 90%86% of our coal sales are to customers with large scrubbed coal-fired power plants in the state of Indiana. Our mines and coal reserves are strategically located in close proximity to our primary customers, which reduces transportation costs and thus provides us with a competitive advantage with respect to those customers; our closest customer’s plant is 13 miles away and the farthest Indiana customer is 100 miles away. We have access to our primary customers directly through either the CSX Corporation (NYSE:CSX) or through the Indiana Rail Road, majority owned by the CSX.
We see an increasing demand for coal produced in the Illinois Basin (ILB) in the future. Demand for coal produced in the ILB is expected to grow at a rate faster than overall U.S. coal demand due to ILB coal having higher heating content than Powder River Basin (PRB) and lower cost structure than Central Appalachia (CAPP) coal. Many utilities are scrubbing to meet emission requirements beyond just sulfur compliance, even utilities that burn exclusively PRB. Once scrubbed, those utilities are usually capable of burning ILB coal. It is this trend of new scrubber installations coupled with rising CAPP cost structure that is leading to increased switching from CAPP coal to ILB coal. Some fuel switching will also occur from PRB to ILB in newly scrubbed utilities located near ILB coal supply.
The majority of our coal is sold to investment grade customers who have scrubbed, “base load” power plants. Base load power plants are among the lowest cost producers of electricity and the first to be dispatched in the power grid. Due to the large investments made to these plants none of these plants are scheduled for retirement; thus we expect to be supplying these plants for many years. It is not economical for the smaller, older, less efficient power plants to install scrubbers and other pollution control devices; accordingly, those type plants most likely will be retired in the coming years.
Vectren Fuels pending acquisitionAcquisition
On July 1,August 29, 2014, Sunrise Coal, LLC entered into an agreement to purchasewe consummated the acquisition of Vectren Fuels, Inc. (a wholly-owned coal mining subsidiary of Vectren Corporation (NYSE:VVC)).(VFI) for $320 million. See Note 10 to the financial statements.
Vectren Fuels, headquartered in Evansville, Indiana, ownsowned three underground coal mines in southwestern Indiana, including the Oaktown 1 and Oaktown 2 mines in Oaktown, Indiana, and the Prosperity Mine located in Petersburg, Indiana. We idled the Prosperity Mine on August 29, 2014. The two underground mines in Oaktown, Indiana are seven miles south of our Carlisle underground mine.
The purchase priceOaktown 2 is $296 million plus additional working capital adjustments, notcontiguous to exceed a totalour Carlisle mine and War Eagle reserve. Thus we intend to mine part of $325 million. Sunrise is working with its groupOaktown 2’s reserve from our Carlisle portal and all of banks headed by PNC Bank to secure the necessary financing. We have been advised by PNC that commitmentsour War Eagle reserve from the various banksOaktown 2 portal (as noted later in the syndication exceed the amount necessary to fund the acquisition. Closing is expected to occur around September 1, 2014.
Reserve Table).
Oaktown 1, Oaktown 2, Carlisle and War Eagle will becomeare now one large underground mining complex representing 161142 million tons of controlled reserves, with three portals, two wash plants and two rail facilities. Duringfacilities, located on the last twelve months, the Oaktown mines sold 5.1 million tons of coal, the Prosperity mine sold 1.8 million tons and Sunrise sold 3.2 million tons from the Carlisle mine. Current 2015 coal sales commitmentsCSX. We anticipate total capacity for the four mines stand at a total of 9 million tons.
The information below pertaining to the three mines we agreed to purchase from Vectren was taken directly from disclosuresbe roughly 9.7 million tons annually. Additionally, the capacity of our Ace in Vectren’s 2013 Form 10-K. Additional disclosure regarding these minesthe Hole mine is contained in Vectren’s Form 10-Q for the quarters ended March 31 and June 30, 2014..5 million tons annually. Thus, our total mining capacity is 10.2 million tons annually.
All coal is high-to-mid sulfur bituminous coal from the Illinois Basin. Vectren engaged contract mining companies to operate the coal mines. Contract miners will not be utilized post losing. The three mines generated approximately $293 million in revenue in 2013, compared to $236 million in 2012.
Oaktown Mine Expansion
In April 2006, Vectren announced plans to open two new underground mines. The first of two underground mines located near Vincennes, Indiana, began full operations in 2010. The second mine began operations during 2013. Reserves at the two mines are estimated at about 94 million tons of recoverable number-five coal at 11,200 BTU and less than 6-pound sulfur dioxide.
The Oaktown mine infrastructure is located on 1,100 acres near Oaktown in Knox County, Indiana. Oaktown’s location is within 50 miles of multiple coal-fired power plants. It is estimated approximately 25,000 acres of coal will be mined during the life of both mines. Through December 31, 2013, approximately 2,353 acres of coal have been mined with approximately 22,647 acres remaining. Access to the Oaktown 1 mine was accomplished via a 90 foot deep box cut and a 2,200 foot slope on a 14 percent grade, reaching coal in excess of 375 feet below the surface. Access to the Oaktown 2 mine is via an 80 foot deep box cut and a 2,600 foot slope on a 14 percent grade, reaching coal in excess of 400 feet below the surface.
Both Oaktown mines are room and pillar underground mines meaning that main airways and transportation entries are developed and maintained while remote-controlled continuous miners extract coal from so-called rooms by removing coal from the seam, leaving pillars to support the roof. Shuttle cars or similar transportation are used to transport coal to a conveyor belt for transport to the surface. The two Oaktown mines are separated by a sandstone channel. The coal seam thickness ranges from 4 feet to over 9 feet. The mine’s wash plant was originally sized to process 800 tons per hour and has been expanded to 1,600 tons per hour to accommodate the second mine. The two mines are connected to a railway equipped to handle 110 to 120 car unit trains. Coal is also transported via truck to customers, which include Vectren’s power supply operations and other third party utilities. The total plant and development costs to date for the Oaktown mining complex are $291 million, inclusive of advance royalty payments. The remaining unamortized plant balance as of December 31, 2013 approximates $212 million, inclusive of $41 million of land and buildings, $169 million of mine development and equipment, and $2 million in advance royalty payments.
Prosperity Mine
Prosperity is an underground mine located on 1,100 surface acres outside of Petersburg in Pike County, Indiana. Prosperity is also a room and pillar mine where coal removal is accomplished with continuous mining machines. The mine entrance slopes gradually for 500 ft on a 9 degree grade and is more than 250 feet below ground level. The coal seam varies in thickness from 4-1/2 to 6 feet. The mine has a wash plant sized to process 1,000 tons per hour. The mine is connected to a railway and can handle 110 to 120 car unit trains. Coal is also transported via truck to customers, which include Vectren's power supply operations and other third party utilities. The mine opened in 2001, and the total plant and development costs to date are $219 million. The remaining unamortized plant balance as of December 31, 2013 approximates $80 million, inclusive of $6 million of land and buildings and $74 million of mine development and equipment.
Our Coal Contracts
We have close relationships with oursell coal to the following customers: Duke Energy Corporation (NYSE:DUK), Hoosier Energy, an electric cooperative, and Indianapolis Power & Light Company (IPL), a wholly-owned subsidiary of The AES Corporation (NYSE:AES), Northern Indiana Public Service Co. (NIPSCO), a wholly-owned subsidiary of NiSource Inc. (NYSE:NI) and Vectren Corporation (NYSE:VVC). We also deliver coal to an Orlando utility through an arrangement we have with an affiliate of JP Morgan.three Florida utilities. We believe these Florida sales are an indication of the trend of ILB coal replacing CAPP coal that has traditionally supplied the southeast markets.
The table below illustrates the status of our current coal contracts:
Period | Contracted Tons | Average Price/Ton | ||||||
Six months ending December 31, 2014* | 1,911,000 | $ | 41.58 | |||||
2015 | 2,020,000 | 42.87 | ||||||
2016 | 689,000 | 40.93 | ** |
*Due to rail shipping delays, it is possible that 100,000 tons to 200,000 tons will be pushed into 2015 business.
**During 2013, to accommodate one of our major customers, we entered into three separate agreements that allowed them to defer 338,000 tons originally to be delivered in 2013 to sometime in 2016. Under the agreements they agreed to pay us an average of $5.36/ton over the life of the deferral periods and we recognize the revenue accordingly; otherwise our average price/ton in 2016 would be $43.57.
Period | Contracted Tons | Average Price/Ton | ||||||
Three months ending December 31, 2014* | 2,425,000 | $ | 43.24 | |||||
2015 | 9,470,000 | 44.32 | ||||||
2016 | 3,369,000 | 44.03 | ||||||
2017 | 1,450,000 | 44.39 |
We expect to continue selling a significant portion of our coal under supply agreements with terms of one year or longer. Typically, customers enter into coal supply agreements to secure reliable sources of coal at predictable prices while we seek stable sources of revenue to support the investments required to open, expand and maintain, or improve productivity at the mines needed to supply these contracts. The terms of coal supply agreements result from competitive bidding and extensive negotiations with customers.
Current Projects
All of our underground coal reserves are high sulfur (4.5 - 6#) with a BTU content in the 11,50011,300 -11,500 range. As discussed below, the Ace surface mine is low sulfur (1.5#) with a BTU content of 11,400. We have no met coal reserves, only steam (thermal) coal reserves. Below is a discussion of our current projects preceded by a table of our coal reserves.
Reserve Table - Controlled Tons (in millions):
Year-End Reserves | ||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||
Annual Capacity | Proven | Probable | Total | Proven | Probable | Total | ||||||||||||||||||||||
Carlisle (assigned) | 3.4 | 33.5 | 8.6 | 42.1 | 34.2 | 9.3 | 43.5 | |||||||||||||||||||||
Ace in the Hole (assigned) | 0.5 | 3.1 | 3.1 | 3.1 | 3.1 | |||||||||||||||||||||||
Bulldog (unassigned) | 19.6 | 16.2 | 35.8 | 19.5 | 16.1 | 35.6 | ||||||||||||||||||||||
War Eagle (unassigned) | 27.7 | 15.4 | 43.1 | 15.5 | 13.9 | 29.4 | ||||||||||||||||||||||
Total | 3.9 | 83.9 | 40.2 | 124.1 | 72.3 | 39.3 | 111.6 | |||||||||||||||||||||
Assigned | 45.2 | 46.6 | ||||||||||||||||||||||||||
Unassigned | 78.9 | 65.0 | ||||||||||||||||||||||||||
124.1 | 111.6 |
December 31, 2013 reserves plus Oaktown 1 and Oaktown 2
Annual Capacity | Total | |||||||
Carlisle (assigned) | 3.3 | 42 | ||||||
Ace in the Hole (assigned) | 0.5 | 3 | ||||||
Oaktown 1* (assigned) | 3.2 | 36 | ||||||
Oaktown 2* and War Eagle** (assigned) | 3.2 | 64 | ||||||
Bulldog (unassigned) | 36 | |||||||
Total | 10.2 | 181 | ||||||
Assigned | 145 | |||||||
Unassigned | 36 | |||||||
181 |
Active Reserve (assigned) - *Oaktown 1 and 2 were acquired on August 29, 2014.
** War Eagle reserves will be mined from the Oaktown 2 portal and have been added to the Oaktown 2 reserve base.
Carlisle Mine (underground) - Assigned
Our coal reserves at December 31, 2013 assigned to the Carlisle Mine were 42.142 million tons compared to beginning of year reserves of 43.5 million tons. Primarily through the execution of new leases, our reserve additions of 2.5 million tons replaced 80% of our 2013 production of 3.1 million tons. We reduced our reserves by 810,000 tons due to revised mining plans. The mine is located near the town of Carlisle, Indiana in Sullivan County and became operational in January 2007. The coal is accessed with a slope to a depth of 340'. The coal is mined in the Indiana Coal V seam which is highly volatile bituminous coal and is the most economically significant coal in Indiana. The Indiana V seam has been extensively mined by underground and surface methods in the general area. The coal thickness in the project area is 4' to 7'.
The mine has several advantages as listed below:
SO2 - Historically, Carlisle has guaranteed a 6# SO2 product; however, with the addition of the Ace in the Hole Mine we can blend lower sulfur coal with Carlisle coal and guarantee a mid-sulfur product which should command a higher price and increase our customer base. Few mines in the ILB have the ability to offer their customers various ranges of SO2. Carlisle has supplied coal to 11 different power plants. |
· | Chlorine - Our reserves have lower chlorine (<0.10%) than average ILB reserves of 0.22%. Much of the ILB’s new production is located in Illinois and possesses chlorine content in excess of .30%. The relatively low chlorine content of our reserves is attractive to buyers given their desire to limit the corrosive effects of chlorine in their power plants. |
16 |
· | Transportation - Carlisle has a double 100 rail car loop facility and a four-hour certified batch load-out facility connected to the CSX railroad. The Indiana Rail Road (INRD) also has limited running rights on the CSX to our mine. Dual rail access gives us a freight advantage to more customers. Long term, the CSX anticipates our coal being shipped to southeast markets via their railroad. We sell our coal FOB the mine and substantially all of our coal is transported by rail. However, on occasion we have shipped to three power plants via truck. |
New Mine (assigned) – Ace in the Hole Mine (Ace) (surface) - Assigned
In November 2012 we purchased for $6 million permitted fee coal reserves, coal leases and surface properties near Clay City, Indiana in Clay County. The Ace mine is 42 road miles northeast of the Carlisle Mine. We control 3.1 million tons of proven coal reserves of which we own 1.2 million tons in fee. We mine two primary seams of low sulfur coal which make up 2.8 million of the 3.1 million tons controlled. Both of the primary seams are low sulfur (2#(<2# SO2).Mine development began in late December 2012, and we began shipping coal in late August 2013. We truck low sulfur coal from Ace to Carlisle to blend with Carlisle’s high sulfur coal. Many utilities in the southeastern U.S. have scrubbers with lower sulfur limits (4# SO2) which cannot accept the higher sulfur contents of the ILB (6#(4.5# - 6# SO2). Blending Carlisle coal to a lower sulfur specification enables us to market Carlisle coal to more customers. We currently have a contract at Carlisle which requires us to blend coal from Ace to meet sulfur specifications. We also expect to ship low sulfur coal from Ace direct to unscrubbed customers that require low sulfur (2# SO2). We expect the maximum capacity of Ace to be 500,000 tons annually.
New Reserve (unassigned) - BulldogOaktown 1 Mine (underground) – Assigned
We have 36 million tons controlled and rated proved and probable of the Indiana #V seam. All reserves are located in Knox County, IN.
Oaktown 2 Mine / War Eagle reserve (underground) – Assigned
We have combined 21 million tons of our Oaktown 2 Mine with 43 million tons from of our War Eagle reserve to create a combined 64 million tons of reserve based in both Knox County, Indiana and Lawrence County, Illinois. Both the Oaktown 2 reserve and War Eagle reserve will be mined through the Oaktown 2 portal. In future reporting we will only refer to the combined reserve as Oaktown 2.
Bulldog Mine (underground) – Unassigned
We have leased roughly 19,300 acres in Vermillion County, Illinois near the village of Allerton. Based on our reserve estimates we currently control 35.8 million tons of coal reserves. A considerable amount of our leased acres has yet to receive any exploratory drilling, thus we anticipate our controlled reserves to grow as we continue drilling in 2014.drilling. The permitting process was started in the summer of 2011, and we filed the formal permit with the state of Illinois and the appropriate Federal regulators during June 2012. In July 2014, we were notified by the Illinois Department of Natural Resources (ILDNR) that our permit had been deemed complete which starts the timeline for the ILDNR public review process. It is our estimation that our permit will be approved or denied no later than mid-March 2015.
Full-scale mine development will not commence until we have a sales commitment. We estimate the costs to develop this mine to be $150 million at full capacity of three million tons annually.
New Reserve (unassigned) – War Eagle Mine (underground)
We have leased roughly 11,000 acres in Lawrence County, Illinois near the village of Russellville. Based on our reserve estimates we currently control 43.1 million tons of coal reserves. This reserve is located about 20 miles southwest of the Carlisle Mine. Our initial testing indicates that this reserve’s minability and coal quality is very similar to the Carlisle reserve.
We anticipate filing for a mining permit in late 2014. Full-scale mine development will not commence until we have a sales commitment. We estimate the costs to develop this mine to be $150 million at full capacity of 3.3 million tons annually.
Upon closing of the Vectren acquisition, we will be able to access the War Eagle reserves from the Oaktown 2 portal without spending the aforementioned $150 million in development costs. Consequently we will be able to classify these reserves as “assigned.”
Unassigned reserves represent coal reserves that would require new mineshafts, mining equipment, and plant facilities before operations could begin on the property. The primary reason for this distinction is to inform investors which coal reserves will require substantial capital expenditures before production can begin.
Ohio River Terminal
On May 31, 2013 we purchased for $2.8 million a multi-commodity truck/barge terminal. Over 17 acres of secured area is available. The terminal is at mile point 743.8 on the Indiana bank of the Ohio River near the William Natcher Bridge between Rockport and Grandview, Indiana. Currently the dock will handle third party commodities. In the long term, we plan to ship coal through the dock. The terminal is in close proximity to the NS railroad, the CSX railroad, and American Electric Power's Rockport generating power plant. We do not expect significant revenue from this asset until 2015.
Liquidity and Capital Resources
Our capex budget for the remainder of 2014 is about $8 million. At Carlisle we expect to spend $7.5$9.1 million, of which $7.1 million is for maintenance capex. At Ace we estimate maintenance capex to be about $500,000. Cash from operations should fund these expenditures.
As discussed in Note 10 we will fund the Vectren acquisition with the new PNC facility.
We have no material off-balance sheet arrangements.
Capital Expenditures (capex)
For the 2014 first halfnine months of 2014 our capex was about $9$14.3 million allocated as follows (in 000’s):
Carlisle - maintenance capex | $ | 6,624 | $ | 10,653 | ||||
Oaktown - maintenance capex | 727 | |||||||
Oaktown expansion | 171 | |||||||
Ace - surface equipment | 1,586 | 1,707 | ||||||
Bulldog-land and easements | 751 | |||||||
Bulldog - land and easements | 752 | |||||||
Other projects | 165 | 316 | ||||||
Capex per the Cash Flow Statement | $ | 9,126 | $ | 14,326 |
Results of Operations
The column for the 3rd quarter 2014 in the table includes the mines acquired from Vectren on August 29, 2014.
Quarterly coal sales and cost data (in 000’s):
3rd2013 | 4th2013 | 1st 2014 | 2nd 2014 | T4Qs | ||||||||||||||||
Tons sold | 817 | 757 | 776 | 847 | 3,197 | |||||||||||||||
Coal sales | $ | 34,985 | $ | 34,307 | $ | 33,016 | $ | 36,130 | $ | 138,438 | ||||||||||
Average price/ton | 42.82 | 45.32 | 42.55 | 42.66 | 43.30 | |||||||||||||||
Wash plant recovery in % | 68.00 | 63.20 | 65.60 | 67.50 | ||||||||||||||||
Operating costs | $ | 23,407 | $ | 23,934 | $ | 23,005 | $ | 26,096 | $ | 96,442 | ||||||||||
Average cost/ton | 28.65 | 31.62 | 29.65 | 30.81 | 30.16 | |||||||||||||||
Margin | 11,578 | 10,373 | 10,011 | 10,034 | 41,996 | |||||||||||||||
Margin/ton | 14.17 | 13.70 | 12.90 | 11.85 | 13.14 | |||||||||||||||
Capex | 8,780 | 7,834 | 2,936 | 6,190 | 25,740 |
3rd2012 | 4th2012 | 1st 2013 | 2nd 2013 | T4Qs | ||||||||||||||||
Tons sold | 810 | 752 | 840 | 774 | 3,176 | |||||||||||||||
Coal sales | $ | 36,152 | $ | 33,111 | $ | 33,995 | $ | 34,149 | $ | 137,407 | ||||||||||
Average price/ton | 44.63 | 44.03 | 40.47 | 44.12 | 43.26 | |||||||||||||||
Wash plant recovery in % | 71.10 | 71.70 | 74.00 | 70.90 | ||||||||||||||||
Operating costs | $ | 20,745 | $ | 21,745 | $ | 23,290 | $ | 22,262 | $ | 88,042 | ||||||||||
Average cost/ton | 25.61 | 28.91 | 27.73 | 28.76 | 27.72 | |||||||||||||||
Margin | 15,407 | 11,366 | 10,705 | 11,887 | 49,365 | |||||||||||||||
Margin/ton | 19.02 | 15.12 | 12.74 | 15.36 | 15.54 | |||||||||||||||
Capex | 4,993 | 16,987 | 8,604 | 6,174 | 36,758 |
Year | Tons | Average Sales Price/ton | Average Cost/ton | Margin/ton | Margin (in millions) | |||||||||||||||
2012 (actual) | 3,006 | $ | 43.70 | $ | 26.53 | $ | 17.17 | $ | 51.6 | |||||||||||
2013 (actual) | 3,188 | 43.11 | 29.14 | 13.97 | 44.5 | |||||||||||||||
Six months ended June 30, 2014 (actual) | 1,623 | 42.60 | 30.25 | 12.35 | 20 | |||||||||||||||
Six months ending December 31, 2014* | 1,911 | 41.58 | 29-30 | 12.58 - 11.58 | 24-22 |
4th 2013 | 1st 2014 | 2nd 2014 | 3rd 2014 | T4Qs | ||||||||||||||||
Tons sold | 757 | 776 | 847 | 1,500 | 3,880 | |||||||||||||||
Coal sales | $ | 34,307 | $ | 33,016 | $ | 36,130 | $ | 64,764 | $ | 168,217 | ||||||||||
Average price/ton | 45.32 | 42.55 | 42.66 | 43.18 | 43.35 | |||||||||||||||
Wash plant recovery in % | 63.2 | 65.6 | 67.5 | 62.8 | ||||||||||||||||
Operating costs | $ | 23,934 | $ | 23,005 | $ | 26,096 | $ | 52,588 | $ | 125,623 | ||||||||||
Average cost/ton | 31.62 | 29.65 | 30.81 | 35.06 | 32.38 | |||||||||||||||
Margin | 10,373 | 10,011 | 10,034 | 12,176 | 42,594 | |||||||||||||||
Margin/ton | 13.7 | 12.9 | 11.85 | 8.12 | 10.97 | |||||||||||||||
Capex | 7,834 | 2,936 | 6,190 | 5,209 | 22,169 |
4th 2012 | 1st 2013 | 2nd 2013 | 3rd 2013 | T4Qs | ||||||||||||||||
Tons sold | 752 | 840 | 774 | 817 | 3,183 | |||||||||||||||
Coal sales | $ | 33,111 | $ | 33,995 | $ | 34,149 | $ | 34,985 | $ | 136,240 | ||||||||||
Average price/ton | 44.03 | 40.47 | 44.12 | 42.82 | 42.8 | |||||||||||||||
Wash plant recovery in % | 71.7 | 74 | 70.9 | 68 | ||||||||||||||||
Operating costs | $ | 21,745 | $ | 23,290 | $ | 22,262 | $ | 23,407 | $ | 90,704 | ||||||||||
Average cost/ton | 28.91 | 27.73 | 28.76 | 28.65 | 28.49 | |||||||||||||||
Margin | 11,366 | 10,705 | 11,887 | 11,578 | 45,536 | |||||||||||||||
Margin/ton | 15.12 | 12.74 | 15.36 | 14.17 | 14.31 | |||||||||||||||
Capex | 16,987 | 8,604 | 6,174 | 8,780 | 40,545 |
*Sales areRail service has been poor throughout the industry in 2014. Unfortunately, we have not been immune from this issue. Of our eight contracted for 2014. Average cost per ton is an estimate.customers, three have struggled to provide us with adequate freight. We have made several changes to improve transportation in 2015 and believe results will be improved.
The cold weatherIn 2014, much of management’s time, effort and attention have been focused on purchasing Vectren Fuels, a transaction that has essentially tripled the size of our company. Two thirds of our employees are new and we experienced duringwill continue to spend the remaining part of 2014 first quarter was both a blessingintegrating them into Sunrise. Additionally, we will continue to move equipment and curse. The coal burn was high butemployees from the freezing weather caused train delaysProsperity Mine to the Oaktown Mines for the remainder of the year. We are extremely grateful for the time, effort and missed shipments. The missed shipments causeddedication of our stockpiles to increase which translates to more handling time to keep the coal from burning and the coal deteriorates the longer it sits resulting in lower wash plant recovery. Weemployees that have limited space for our stockpiles so we had to cut production which lowers our productivity resulting in higher costs. The train delays and missed shipments continued during the month of April and May.made this transaction possible.
We hoperealize the combination of poor transportation and the challenge of acquiring Vectren Fuels has not helped contain our costs structure throughout 2014, but we believe in 2015 we will return to make up the missed shipments throughout the year but it is possible that 100,000 tons to 200,000 tons will not be shipped and be pushed into 2015 business. We continue to believe that our mining costs for the last halfa cost structure of 2014 will be $29-30/$30/ton or lower.
First HalfNine Months 2014 vs.v. 2013
For the first halfnine months of 2014, we sold 1,623,0003,123,000 tons at an average price of $42.60/$42.88/ton. For the first halfnine months of 2013, we sold 1,614,0002,431,000 tons at an average price of $42.22/$42.42/ton. The slightly higher average price for the first half 2014increase is dueattributable to the mix of our various contracts.Vectren acquisition.
Operating costs and expenses averaged $30.25/$32.56/ton in 2014 compared to $28.22$28.37 in 2013. The cold weather andreasons for the missed shipmentsincrease are discussed above caused the increase. In addition in April 2014 we made a one-time payment to our mining employees that increased our per ton cost by about $1.50.above. Our Indiana employees totaled 3831,072 at JuneSeptember 30, 2014 compared to 355374 at JuneSeptember 30, 2013.
SG&A expense increased significantly for several reasons: (i) legal fees incurred with respect to the Vectren acquisition were about $325,000; (ii) we contributed $100,0000$210,000 to political candidates and PACs who support the coal mining industry; (iii)industry and our pleased with the election results, (ii) stock based compensation increased by about $200,000;$600,000; and (iv)(iii) health care benefits increased by about $230,000.$400,000. We are self-insured for the first $110,000 per person with an annual cap of $5.5 million. We paid for some non-routine treatments during the first sixnine months of 2014.
Savoy’s activity is discussed below.
Three months ended JuneMonths Ended September 30, 2014 vs.v. 2013
For the secondthird quarter of 2014, we sold 847,0001,500,000 tons at an average price of $42.66/$43.18/ton. For the secondthird quarter of 2013, we sold 774,000817,000 tons at an average price of $44.12/$42.82/ton.
Operating costs and expenses averaged $30.81/$35.06/ton in 2014 compared to $28.76$28.65 in 2013. The reasons for the increase are discussed above.
See above for an explanation of the increase in SG&A.
Earnings per Share
3rd 2013 | 4th 2013 | 1st 2014 | 2nd 2014 | |||||||||||||
Basic | $ | .17 | $ | .16 | $ | .12 | $ | .10 | ||||||||
Diluted | .17 | .16 | .12 | .10 |
3rd 2012 | 4th 2012 | 1st 2013 | 2nd 2013 | 4th 2013 | 1st 2014 | 2nd 2014 | 3rd 2014 | |||||||||||||||||||||||||
Basic | $ | .22 | $ | .18 | $ | .19 | $ | .29 | $ | 0.16 | $ | 0.12 | $ | 0.10 | $ | (0.20 | ) | |||||||||||||||
Diluted | .22 | .17 | .19 | .28 | 0.16 | 0.12 | 0.10 | (0.20 | ) | |||||||||||||||||||||||
4th2012 | 1st 2013 | 2nd 2013 | 3rd 2013 | |||||||||||||||||||||||||||||
Basic | $ | 0.18 | $ | 0.19 | $ | 0.29 | $ | 0.17 | ||||||||||||||||||||||||
Diluted | 0.17 | 0.19 | 0.28 | 0.17 |
MSHA Reimbursements
Some of our legacy coal contracts allow us to pass on certain costs incurred resulting from changes in costs to comply with mandates issued by MSHA or other government agencies. We do not recognize any revenue until customers have notified us that they accept the charges.
We submitted our incurred costs for 2011 in October 2012 for $3.7 million. $2.1 million in reimbursements were recorded in the first quarter 2013 and $1.6 million were recorded in the fourth quarter. Based on past experience we expect to collect the 2012 costs in 2014 and the 2013 costs in 2015. Due to the time involved relating to the pending Vectren acquisition, we do not expect to submit our incurred costs for 2012 until the fourth quarter of 2014.
Income Taxes
During 2013 our effective tax rate (ETR) was 25%. For the nine months ended September 30, 2014, we are projecting an effective tax rate ofused a 20%. Based on our projections, we are forecasting a total federal and state tax obligation in excess of existing prepayments resulting in additional outlays of cash ETR; for income taxes. In addition,the calendar year 2014 we expect the tax consequences between income tax and financial reporting purposesour ETR to result in a reduction to the deferred tax liability with a corresponding deferred tax benefit. be 20-25%.
45%40% Ownership in Savoy
Our ownership was 45% but was decreased on October 1, 2014 due to the exercise of options by Savoy’s management.
Late last year Savoy engaged Energy Spectrum Advisors Inc. (ESA) to market its Trenton-Black River oil properties located in southeast Michigan. ESA has offices in Dallas and Houston. Information was posted to the ESA websiteNo acceptable offers were received. Marketing efforts are on hold until oil prices recover.
Savoy made a $12 million cash distribution in early March 2014. Savoy terminated discussions with a prospective buyer and we are now exploring other alternatives to monetizeOctober 2014; our Savoy investment.
share was $4.9 million; such amount was applied toward our bank debt.
The table below illustrates the growth in Savoy (to the 100% - in other words not shown proportionate to our 45% interest) comparing the first halfnine months of 2014 to 2013 (financial statement data in thousands):
2014 | 2013 | 2014 | 2013 | |||||||||||||
Revenue: | ||||||||||||||||
Oil | $ | 18,795 | $ | 14,758 | $ | 26,138 | $ | 24,081 | ||||||||
NGLs (natural gas liquids) | 524 | 409 | 760 | 658 | ||||||||||||
Natgas | 742 | 345 | 955 | 549 | ||||||||||||
Contract drilling | 1,938 | 1,345 | 2,806 | 3,168 | ||||||||||||
Other | 2,494 | 1,516 | 1,476 | 988 | ||||||||||||
Total revenue | 24,493 | 18,373 | 32,135 | 29,444 | ||||||||||||
Costs and expenses: | ||||||||||||||||
LOE (lease operating expenses) | 3,339 | 2,482 | 4,870 | 4,060 | ||||||||||||
Contract drilling costs | 1,913 | 1,684 | 2,420 | 2,296 | ||||||||||||
DD&A (depreciation, depletion & amortization) | 3,072 | 2,395 | 4,433 | 4,634 | ||||||||||||
G&G (geological and geophysical costs) | 2,170 | 2,386 | 981 | 2,278 | ||||||||||||
Dry hole costs | 1,686 | 711 | 2,411 | 1,408 | ||||||||||||
Impairment of unproved properties | 1,271 | 2,391 | 2,135 | 3,472 | ||||||||||||
Other exploration costs | 188 | 173 | 297 | 275 | ||||||||||||
G&A (general & administrative) | 841 | 724 | 1,240 | 1,048 | ||||||||||||
Compensation expense – options | 636 | |||||||||||||||
Total expenses | 14,480 | 12,946 | 19,423 | 19,471 | ||||||||||||
Net income | $ | 10,013 | $ | 5,427 | $ | 12,712 | $ | 9,973 | ||||||||
The information below is not in thousands: | ||||||||||||||||
Oil production – barrels | 198,000 | 163,000 | 277,000 | 253,000 | ||||||||||||
Average oil prices/barrel | $ | 94.74 | $ | 90.78 | $ | 94.36 | $ | 95.18 |
Critical Accounting Estimates
We believe that the estimates of our coal reserves and our deferred tax assets and liability accounts are our only critical accounting estimates. The reserve estimates are used in the DD&A calculation, in our impairment test if and when circumstances indicate the need for measurement, and in our internal cash flow projections. If these estimates turn out to be materially under or over-stated; our DD&A expense and impairment test may be affected. Furthermore, if our coal reserves are materially overstated, our liquidity and stock price could be adversely affected. The allocation of the Vectren purchase price is also an estimate.
We have analyzed our filing positions in all of the federal and state jurisdictions where we are required to file income tax returns, as well as all open tax years in these jurisdictions. We identified our federal tax return and our Indiana state tax return as “major” tax jurisdictions. During 2012 the IRS completed an examination of our 2009 and 2010 federal tax returns and there were no significant adjustments. During 2012 the State of Indiana completed their examination of our 2008-2010 returns and no adjustments were proposed. We believe that our income tax filing positions and deductions will be sustained on audit and do not anticipate any adjustments that will result in a material change to our consolidated financial position.
Yorktown Distributions
As previously disclosed, Yorktown Energy Partners and its affiliated partnerships (Yorktown) have made eight distributions to their numerous partners totaling 6 million (750,000 per distribution) shares since May 2011. In the past these distributions were made soon after we filed our Form 10-Qs and Form 10-Ks. Currently they own 9.7 million shares of our stock representing about 34% of total shares outstanding. Their last distribution was made in August 2013.
We have been informed by Yorktown that they have not made any determination as to the disposition of their remaining Hallador stock. While we do not know Yorktown’s ultimate strategy to realize the value of their Hallador investment for their partners, we expect that over time such distributions will increase our liquidity and float.
If and when we are advised of another Yorktown distribution, we will timely report such on a Form 8-K.
New Accounting Pronouncements
None of the recent FASB pronouncements will have any material effect on us.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
Smaller reporting companies are not required to provide the information required by this item.
ITEM 4. CONTROLS AND PROCEDURES
We maintain a system of disclosure controls and procedures that are designed for the purposes of ensuring that information required to be disclosed in our SEC reports is recorded, processed, summarized, and reported within the time periods specified in the SEC's rules and forms, and that such information is accumulated and communicated to our CEO and CFO as appropriate to allow timely decisions regarding required disclosure.
As of the end of the period covered by this report, we carried out an evaluation, under the supervision and with the participation of our CEO and CFO, of the effectiveness of the design and operation of our disclosure controls and procedures. Based upon that evaluation, our CEO and CFO concluded that our disclosure controls and procedures are effective for the purposes discussed above.
There has been no change in our internal control over financial reporting during the quarter ended JuneSeptember 30, 2014 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
At June 30, 2014 our public float exceed the $75 million threshold used to determine our filing status.
Consequently we are no longer a Smaller Reporting Company (SRC) and will be required to have EKS&H, our auditors, provide an audit report on our internal controls to be included in our Form 10-K for the year ending December 31, 2014. Such Form 10-K will continue to provide scaled SRC-level disclosures; the larger reporting company disclosures will commence in our Form 10-Q for the quarter ended March 31, 2015.
PART II - Other Information
ITEM 4. MINE SAFETY DISCLOSURE
See Exhibit 95 to this Form 10-Q for a listing of our mine safety violations.
ITEM 6. EXHIBITS
10.26 | Stock Purchase Agreement (Vectren Fuels) – IBR to Form 8-K dated July 8, 2014 |
10.27 | Second Amended and Restated Credit Agreement – August 29, 2014 |
15 | Letter Regarding Unaudited Interim Financial Information |
31 | SOX 302 Certifications |
32 | SOX 906 Certification |
95 | Mine Safety Report |
101 | Interactive Files |
SIGNATURE
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.
HALLADOR ENERGY COMPANY | |
Date: | /s/W. Anderson Bishop |
W. Anderson Bishop, CFO and CAO |