HALLADOR ENERGY CO - Quarter Report: 2013 June (Form 10-Q)

jun2013q.htm

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: June 30, 2013 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 (State of incorporation)			84-1014610 (IRS Employer Identification No.)

1660 Lincoln Street, Suite 2700, Denver, Colorado (Address of principal executive offices)		80264-2701 (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. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "larger accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.

o Large accelerated filer	o Accelerated filer
o Non-accelerated filer (do not check if a small reporting company)	þ Smaller reporting company

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ

As of August 2, 2013 we had 28,605,000 shares outstanding.

PART I - Financial Information
ITEM 1. FINANCIAL STATEMENTS
Consolidated Balance Sheet
(in thousands, except per share data)
	June 30, 2013			December 31, 2012
ASSETS
Current assets:
Cash and cash equivalents	$	14,836		$	21,888
Accounts receivable		9,069			8,127
Coal inventory		5,195			2,342
Parts and supply inventory		2,722			2,264
Other		612			242
Total current assets		32,434			34,863
Coal properties, at cost:
Land and mineral rights		23,280			22,705
Buildings and equipment		139,195			131,566
Mine development		78,104			71,046
		240,579			225,317
Less - accumulated DD&A		(67,678	)		(58,479	)
		172,901			166,838
Investment in Savoy		13,506			12,230
Investment in Sunrise Energy		4,316			3,969
Other assets (Note 6)		16,487			11,307
	$	239,644		$	229,207
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	10,089		$	9,386
Income taxes					1,660
Total current liabilities		10,089			11,046
Long-term liabilities:
Bank debt		11,400			11,400
Deferred income taxes		38,591			35,884
Asset retirement obligations		2,669			2,573
Other		1,580			6,295
Total long-term liabilities		54,240			56,152
Total liabilities		64,329			67,198
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; 28,605 and 28,529 shares outstanding, respectively		286			285
Additional paid-in capital		87,304			86,576
Retained earnings		87,592			75,118
Accumulated other comprehensive income		133			30
Total stockholders’ equity		175,315			162,009
	$	239,644		$	229,207

See accompanying notes.

Consolidated Statement of Comprehensive Income
(in thousands, except per share data)

	Six months ended				Three months ended
	June 30,				June 30,
	2013		2012		2013		2012
Revenue:
Coal sales	$	68,144	$	62,107	$	34,149	$	32,487
Equity income - Savoy		2,447		2,498		1,363		680
Equity income (loss) - Sunrise Energy		347		32		225		(24	)
Liability extinguishment (Note 9)		4,300				4,300
Other (Note 6)		3,160		4,494		699		2,032
		78,398		69,131		40,736		35,175
Costs and expenses:
Operating costs and expenses		45,552		37,249		22,262		18,816
DD&A		9,210		7,750		4,650		3,944
Coal exploration costs		986		1,122		447		703
SG&A		3,650		3,660		1,674		1,805
Interest		823		528		447		257
		60,221		50,309		29,480		25,525

Income before income taxes		18,177		18,822		11,256		9,650

Less income taxes:
Current		1,906		3,876		1,105		1,992
Deferred		2,638		2,335		1,986		1,200
		4,544		6,211		3,091		3,192

Net income (1) (2)	$	13,633	$	12,611	$	8,165	$	6,458

Net income per share:
Basic	$	0.48	$	0.45	$	0.29	$	0.23
Diluted	$	0.47	$	0.44	$	0.28	$	0.23

Weighted average shares outstanding:
Basic		28,566		28,312		28,604		28,314
Diluted		28,849		28,719		28,763		28,675
___________________________________
(1) There is no material difference between net income and comprehensive income. (2) See MD&A – page 19, for pro-forma amounts excluding the $4.3 million in other income.

See accompanying notes.

Consolidated Condensed Statement of Cash Flows
(in thousands)

	Six months ended June 30,

	2013			2012
Operating activities:
Cash provided by operating activities	$	12,961		$	13,700

Investing activities:
Capital expenditures for coal properties		(14,778	)		(4,229	)
Ohio River Terminal		(2,823	)
Purchase of marketable securities		(1,414	)		(1,253	)
Other		161			(423	)
Cash used in investing activities		(18,854	)		(5,905	)

Financing activities:
Payments to bank					(5,000	)
Dividends		(1,159	)		(4,080	)
Other					1
Cash used in financing activities		(1,159	)		(9,079	)

Decrease in cash and cash equivalents		(7,052	)		(1,284	)
Cash and cash equivalents, beginning of period		21,888			37,542
Cash and cash equivalents, end of period	$	14,836		$	36,258

See accompanying notes.

Consolidated Statement of Stockholders' Equity
(in thousands)


	Shares		Common Stock		Additional Paid-in Capital			Retained Earnings			AOCI*		Total

Balance, January 1, 2013		28,529	$	285	$	86,576		$	75,118		$	30	$	162,009

Stock-based compensation						1,107								1,107

Other		76		1		(379	)					103		(275	)

Dividends									(1,159	)				(1,159	)

Net income									13,633					13,633

Balance, June 30, 2013		28,605	$	286	$	87,304		$	87,592		$	133	$	175,315

_____________________________________

*Accumulated Other Comprehensive Income

See accompanying notes.

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 six months ended June 30, 2013 are not necessarily indicative of the results to be expected for future quarters or for the year ending December 31, 2013. To maintain consistency and comparability, certain 2012 amounts have been reclassified to conform to the 2013 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 2012 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). 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% 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 our coal mines.

(2) Bill and Hold

Early in 2012 two of our customers advised us that their coal stockpiles were increasing and asked us to consider storing their coal on our property. In April 2012 we entered into a storage agreement with one customer to store 250,000 tons for a minimum of one year and up to a maximum of two years. In June 2012 we entered into a similar storage agreement with the second customer. During the 2013 second quarter we increased the tons by 50,000 for both customers. We continue to sell the coal as contracted to these customers. The risks and rewards of ownership pass from us to them as coal is placed into segregated storage. We are paid a nominal storage fee in addition to our contracted price at the time the coal is placed in storage. During the six months ended June 30, 2013, 145,000 tons were placed in storage for the first customer and nil for the second customer. We have recognized $7.3 million in revenue from these “bill and hold” arrangements for the six months ended June 30, 2013. As of June 30, 2013, we have stored 300,000 tons for the first customer and 250,000 tons for the second. There were no changes in payment terms with our customers and, as of July 31, 2013, all receivables outstanding from these two customers at June 30, 2013 had been collected.

(3) Bank Debt

During October 2012, Sunrise Coal, our wholly-owned subsidiary, entered into a new credit agreement (the “Credit Agreement”) with PNC Bank, as administrative agent, 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. Outstanding debt at June 30, 2013 was $11.4 million.

The Credit Agreement provides for a $165 million senior secured revolving 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 the facility as needed for development of our new projects in Illinois and Indiana.

All borrowings under the Credit Agreement bear interest, at LIBOR plus 2% if the leverage ratio is less than 1.5X (which currently it is), LIBOR plus 2.5% if the leverage ratio is over 1.5 but less than 2X and at LIBOR plus 3% if the leverage ratio is over 2X. The maximum leverage ratio is 2.75X. The leverage ratio is equal to funded debt/EBITDA. The annual commitment fee is 50 BPS but falls to 37.5 BPS if we borrow more than 33% of the facility. The maximum that we can currently borrow is an additional $129 million. The Credit 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.

(4) Investment in Savoy

We own a 45% 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.

Below (in thousands) to the 100% is a condensed balance sheet at June 30, 2013, and a condensed statement of operations for the six months ended June 30, 2013 and 2012.

Condensed Balance Sheet


	2013

Current assets	$	20,651
Oil and gas properties, net		23,018
	$	43,669

Total liabilities	$	12,422
Partners' capital		31,247
	$	43,669

Condensed Statement of Operations

	2013			2012

Revenue	$	18,373		$	17,261
Expenses		(12,946	)		(11,719	)
Net income	$	5,427		$	5,542

(5) Investment in Sunrise Energy

In late December 2010, we invested $2.4 million for a 50% interest in Sunrise Energy, LLC which then purchased existing gas reserves and gathering equipment from an unrelated third party with plans to develop and operate such reserves. An additional $500 thousand was invested in January 2012. Sunrise Energy also plans to develop and explore 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 June 30, 2013, and a condensed statement of operations for the six months ended June 30, 2013 and 2012.

Condensed Balance Sheet


	2013

Current assets	$	2,506
Oil and gas properties, net		6,842
	$	9,348

Total liabilities	$	727
Members' capital		8,621
	$	9,348

Condensed Statement of Operations


	2013			2012

Revenue	$	1,691		$	1,086
Expenses		(997	)		(1,023	)
Net income	$	694		$	63

(6) Other Long-Term Assets and Other Income

	June 30, 2013		December 31, 2012

Long-term assets:
Advance coal royalties	$	3,737	$	3,324
Deferred financing costs, net		1,344		1,494
Marketable equity securities available for sale, at fair value (restricted)*		4,962		3,548
Ohio River Terminal (see Note 8)		2,823
Miscellaneous		3,621		2,941
	$	16,487	$	11,307

______________________

*Held by Sunrise Indemnity, Inc., our wholly-owned captive insurance company.

	Six months ended June 30,
	2013		2012
Other income:
MSHA reimbursements*	$	2,053	$	4,236
Coal storage fees		586
Miscellaneous		521		258
	$	3,160	$	4,494

_______________________

*See “MSHA Reimbursements” on page 16.

(7) Self Insurance

We continue to self-insure on about $110 million (historical cost) of our underground mining equipment. We feel comfortable with this decision as such equipment is allocated among four mining units spread over 12 miles.

(8) 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 our 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 late 2014.

(9) Other Income

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 has no effect on cash flows and is not taxable.

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 June 30, 2013 and the related condensed consolidated statements of comprehensive income, cash flows, and stockholders’ equity for the three and six month periods ended June 30, 2013 and June 30, 2012. 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, 2012, 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 March 6, 2013, 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, 2012, is fairly stated, in all material respects, in relation to the balance sheet from which it has been derived.

/s/ EKS&H LLLP

August 2, 2013

Denver, Colorado

ITEM 2. MD&A

THE FOLLOWING DISCUSSION UPDATES THE MD&A SECTION OF OUR 2012 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% 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 is the Carlisle underground coal mine located in western Indiana, about 30 miles south of Terre Haute. The Carlisle Mine was in the development stage from April of 2006 through January of 2007. Coal shipments began February 5, 2007. Over 84% 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.

These plants have made or announced plans to make significant investments in pollution control equipment. Due to these large investments 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.

Headwinds and Tailwinds Affecting Our Company

Headwinds

1.	Competition from low-priced natgas
2.	The Obama’s administration dislike of burning coal to generate cheap and reliable electricity
3.	Onerous environmental regulations and overzealous mislead environmentalists
4.	Competition from new mines opening in the Illinois Basin
5.	Slow economy

Tailwinds

1.	Major shift in utilities replacing Central Appalachia (CAAP) coal with Illinois Basin (ILB) coal
2.	More power plants are installing scrubbers enabling them to burn high-sulfur coal
3.	Our coal can compete with natgas down to $2.75/Mcf
4.	Coal is the fastest growing fuel worldwide

For 2013 we will continue to focus on maintaining our low cost structure and leasing and permitting new reserves.

We see an increasing demand for coal produced in the 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 CAAP 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 CAAP cost structure that is leading to increased switching from CAAP coal to ILB coal. Some fuel switching will also occur from PRB to ILB in newly scrubbed utilities located near ILB coal supply.

The table below illustrates the backlog of our current coal contracts:

Period	Contracted Tons	Average Price

Last half of 2013	1,800,000	$43.28
Year 2014	2,900,000	43.15
Year 2015	1,200,000	41.40

For the month of July 2013 we sold 307,000 tons at an average price of $42.13/ton. We expect that our mining costs for July will be similar to June’s costs which were $24.93/ton.

Current Projects

All of our underground coal reserves are high sulfur (4.5 - 6#) with a BTU content in the 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
	Annual Capacity	2012			2011
		Proven	Probable	Total	Proven	Probable	Total

Carlisle (assigned)	3.4	34.2	9.3	43.5	36.0	10	46.0
Ace-in-the-Hole (assigned)	0.5	3.1		3.1
Bulldog (unassigned)		19.5	16.1	35.6	16.3	16	32.3
Russellville (unassigned)		15.5	13.9	29.4
Total	3.9	72.3	39.3	111.6	52.3	26	78.3

Assigned				46.6			46.0
Unassigned				65.0			32.3
Totals at December 31,				111.6			78.3

Active Reserve (assigned) - Carlisle Mine (underground)

Our coal reserves at December 31, 2012 assigned to the Carlisle Mine were 43.5 million tons compared to beginning of year reserves of 46 million tons. Primarily through the execution of new leases, our reserve additions of 1.2 million tons replaced 40% of our 2012 production of 3 million tons. We reduced our reserves by 700,000 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.

•

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)

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 will mine two primary seams of low sulfur coal which make up 2.9 million of the 3.1 million tons controlled. Both of the primary seams are low sulfur (2# SO2). Mine development began in late December 2012 and we expect to ship coal in late August 2013. We plan to 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# SO2). Blending Carlisle coal to a lower sulfur specification will enable us to market Carlisle coal to more customers. We currently have a contract at Carlisle which will require 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. Ace currently has 20% of its capacity contracted for 2013 and 2014. We have invested $17 million in minerals, land, equipment, and development as of June 30, 2013 and we anticipate investing an additional $2.5 million in equipment and development for the remainder of 2013.

New Reserve (unassigned) - Bulldog Mine (underground)

We have leased roughly 19,300 acres in Vermillion County, Illinois near the village of Allerton. Based on our reserve estimates we currently control 35.6 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 2013. 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. We currently expect to receive an approved mining permit in the first quarter of 2014.

Full-scale mine development will not commence until we have a sales commitment.

New Reserve (unassigned) - Russellville (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 29.4 million tons of coal reserves. The permitting process will start this fall and we anticipate filing the formal permit with the appropriate regulators during the second quarter of 2014. 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.

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

MSHA Reimbursements

Some of our 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 2010 in September 2011 for $4.2 million. One of the customers agreed with our analysis and paid $2.3 million in February 2012 and the other agreed with our analysis in May 2012. Accordingly, $2.3 million was recorded in the first quarter and the other $1.9 million was recorded in the second quarter of 2012.

We submitted our incurred costs for 2011 in October 2012 for $4.2 million. One of the customers agreed with our analysis, paid $2 million in February 2013 and was recorded in the first quarter. We are in discussions with the other customer. We expect to submit our 2012 costs by September 30, 2013.

Liquidity and Capital Resources

We do not anticipate any liquidity issues in the foreseeable future. We plan to fund future projects through a combination of draws from our revolver and cash from operations.

We have no material off-balance sheet arrangements.

Capital Expenditures (capex)

For the first half of 2013 our capex was about $15 million allocated as follows:

	in 000’s
Carlisle - maintenance capex	$	6,243
Carlisle - expansion/improvements		548
Carlisle - land and minerals		385
Ace - mine development		3,491
Ace - surface equipment		4,391
Ace - land and minerals		102
Other projects		100
Items accrued for but not paid		(482	)
Capex per the Cash Flow Statement	$	14,778

For the remainder of the year we expect maintenance capex for Carlisle to be $6 million and capex for air shafts and improvements to be $4.5 million. For the Ace surface mine we expect capex to be $2.5 million for equipment and mine development and we expect maintenance capex to be $50 thousand. Capex for the Ohio River Terminal is expected to be $400 thousand.

Inauguration of Regular Dividends

On April 5, 2013 our Board of Directors approved the adoption of a regular quarterly dividend policy and authorized a dividend of $.04 per common share outstanding, payable on May 15, 2013, to shareholders of record on April 30, 2013. On July 15 our Board again authorized a $.04 dividend payable August 15, 2013 to shareholders of record on July 31, 2013. In the past we only declared special dividends.

Results of Operations

Quarterly coal sales, cost and margin data (in 000’s):

	3rd 2012		4th 2012		1st 2013		2nd 2013		T4Qs*

Coal sales	$	36,152	$	33,111	$	33,995	$	34,149	$	137,407
Tons sold		810		752		840		774		3,176
Average price/ton	$	44.63	$	44.03	$	40.47	$	44.12	$	43.26

Operating costs	$	20,745	$	21,745	$	20,745	$	22,262	$	88,042
Average cost/ton	$	25.61	$	28.91	$		$	28.76	$	27.72
Margin	$	15,407	$	11,366	$	15,407	$	11,887	$	49,365
Margin/ton	$	19.02	$	15.11	$	19.02	$	15.36	$	15.54
Capex	$	4,993	$	16,987	$	4,993	$	6,174	$	36,758

	3rd 2011		4th 2011		1st 2012		2nd 2012		T4Qs*

Coal sales	$	34,174	$	37,723	$	29,620	$	32,487	$	134,004
Tons sold		805		921		701		743		3,170
Average price/ton	$	42.45	$	40.96	$	42.25	$	43.72	$	42.27

Operating costs	$	19,355	$	21,129	$	18,433	$	18,816	$	77,733
Average cost/ton	$	24.04	$	22.94	$	26.30	$	25.32	$	24.52
Margin	$	14,819	$	16,594	$	11,187	$	13,671	$	56,271
Margin/ton	$	18.41	$	18.02	$	15.96	$	18.40	$	17.75
Capex	$	4,467	$	15,970	$	2,372	$	1,857	$	24,666

__________________________

*T4Qs= trailing four quarters.

Capex in the fourth quarter of 2012 includes $9 million for the purchase of the Ace surface mine and another $4 million for land at Bull Dog and Carlisle. Capex in the fourth quarter of 2011 includes $9 million for the purchase of land for Bull Dog.

First Half 2013 vs. 2012

For the first half of 2013, we sold 1,614,000 tons at an average price of $42.22/ton. For the first half of 2012, we sold 1,444,000 tons at an average price of $43/ton. The lower average price for the first half 2013 is due to the mix of our various contracts. We expect our coal sales for the last half of 2013 to be circa 1.8 million tons with an average price of $43.28/ton as set forth in the table on page 13.

Operating costs and expenses averaged $28.22/ton in 2013 compared to $25.79 in 2012. The increase was due primarily to poor mining conditions in the months of March and May. These conditions have since improved. Our Indiana employees totaled 355 at June 30, 2013 compared to 324 at June 30, 2012. Part of the employee increase was due to the opening of the new Ace-in-the-Hole Mine in January of this year.

Operating costs and expenses averaged $27.40/ton in April, $34.41 in May, and $24.93 in June. We experienced bad mining conditions during May as noted in the extremely high costs/ton for May. June and July mining conditions were much better. We expect such costs to average $25-26/ton for the remainder of 2013.

Savoy’s activity is discussed below.

Three Months Ended June 30, 2013 vs. 2012

For the second quarter of 2013, we sold 774,000 tons at an average price of $44.12/ton. For the first second quarter of 2012, we sold 743,000 tons at an average price of $43.72/ton.

Operating costs and expenses averaged $28.76/ton in 2013 compared to $25.32 in 2012. The higher costs are discussed above.

We expect our margins for the remainder of the year to be in the $17-$18 range.

Other Analyses of Results of Operations

The increase in equity income from Sunrise Energy was due to higher natgas prices.

The increase in DD&A was due to additions to coal properties.

Income Taxes

For the remainder of 2013 we expect our effective tax rate to be 25%. We estimate that 50% of such rate will be for taxes currently due. The decrease in the 2013 effective rate compared to the 2012 rate was due to percentage depletion for income tax purposes in excess of basis. We anticipate our effective tax rate going forward to remain in the mid-20s.

Net Income

The table below reflects net income and net income per share excluding the $4.3 million:

	Six months ended				Three months ended
	June 30,				June 30,
	2013		2012		2013		2012

Net income excluding the $4.3 million liability extinguishment	$	10,927	$	12,611	$	5,459	$	6,458

Net income per share excluding the $4.3 million liability extinguishment
Basic	$	0.38	$	0.45	$	0.19	$	0.23
Diluted	$	0.38	$	0.44	$	0.19	$	0.23

45% Ownership in Savoy

Savoy operates almost exclusively in Michigan. They have an interest in the Trenton-Black River Play in southern Michigan. They hold 200,000 gross acres (about 100,000 net) in Hillsdale and Lenawee counties. Drilling locations in this play are identified based on the evaluation of extensive 3-D seismic shoots. Savoy operates their own wells and their working interest averages between 40% and 50% and their net revenue interest averages between 34% and 42%. Savoy’s net daily oil production currently averages about 900 barrels of oil. Oil and liquids make up 98% of their oil and gas revenue.

The first half of 2013 may or may not be indicative for all of 2013 due to (i) the uncertainty of the outcome of Savoy’s drilling activity; (ii) the extent of their seismic activity (G&G costs) and (iii) the sustainability of these high oil prices. Current oil prices are in excess of $100/barrel. Savoy does not have any oil price hedges in place.

The table below illustrates the growth in Savoy (to the 100%) comparing the first half of 2013 to 2012 (financial statement data in thousands):

	2013		2012
Revenue:
Oil	$	14,758	$	14,010
NGLs (natural gas liquids)		409		488
Natgas		345		173
Contract drilling		1,345		2,296
Other		1,516		294
Total revenue		18,373		17,261
Costs and expenses:
LOE (lease operating expenses)		2,482		2,213
Contract drilling costs		1,684		1,588
DD&A (depreciation, depletion & amortization)		2,395		1,957
G&G (geological and geophysical) costs		2,386		1,512
Dry hole costs		711		1,959
Impairment of unproved properties		2,391		1,824
Other exploration costs		173		125
G&A (general & administrative)		724		541
Total expenses		12,946		11,719
Net income	$	5,427	$	5,542

The information below is not in thousands:

Oil production – barrels		162,570		147,810
NGLs production – barrels		10,895		9,570
Natgas production – Mcf		94,000		63,610
Average oil prices/barrel for the half	$	90.78	$	94.78
Average NGL prices/barrel for the half	$	37.54	$	51.04
Average natgas prices/Mcf for the half	$	3.67	$	2.72

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 4T. CONTROLS AND PROCEDURES

Disclosure Controls

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 June 30, 2013 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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 5. OTHER INFORMATION

2014 Annual Meeting

Our annual shareholders’ meeting is scheduled for Thursday morning, April 24, 2014 in New York City at a yet to be determined location near mid-town Manhattan.

Yorktown Distribution

As previously disclosed, Yorktown Energy Partners and its affiliated partnerships (Yorktown) have made seven distributions to their numerous partners totaling 5.25 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 10.3 million shares of our stock representing about 36% of total shares outstanding.

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 improve our liquidity and float.

If and when we are advised of another Yorktown distribution, we will timely report such on a Form 8-K.

ITEM 6. EXHIBITS

15	Letter Regarding Unaudited Interim Financial Information
31	SOX 302 Certifications
32	SOX 906 Certification
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: August 5, 2013		/s/W. Anderson Bishop
		W. Anderson Bishop, CFO and CAO