Edgar Filing: HALLADOR ENERGY CO

form8k0913fin.htm

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

________________

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the

Securities Exchange Act of 1934

Date of report (Date of earliest event reported): November 1, 2013 (November 1, 2013)

HALLADOR ENERGY COMPANY

(Exact name of registrant as specified in its charter)

Colorado	001-3473	84-1014610
(State or Other Jurisdiction of Incorporation)	(Commission File Number)	(IRS Employer Identification No.)

1660 Lincoln Street, Suite 2700, Denver, CO		80264-2701
(Address of principal executive offices)		(Zip Code)

Registrant’s telephone number, including area code: 303-839-5504

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

r	Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
r	Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
r	Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
r	Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

ITEM 1. 2.02 Results of Operations and Financial Condition
Consolidated Balance Sheet
(in thousands, except per share data)
	September 30, 2013			December 31, 2012
ASSETS
Current assets:
Cash and cash equivalents	$	13,713		$	21,888
Accounts receivable		9,904			8,127
Prepaid income taxes		3,591
Coal inventory		4,086			2,342
Parts and supply inventory		2,645			2,264
Other		403			242
Total current assets		34,342			34,863
Coal properties, at cost:
Land and mineral rights		23,315			22,705
Buildings and equipment		144,304			131,566
Mine development		81,998			71,046
		249,617			225,317
Less - accumulated DD&A		(72,418	)		(58,479	)
		177,199			166,838
Investment in Savoy		15,401			12,230
Investment in Sunrise Energy		4,488			3,969
Other assets (Note 6)		15,191			11,307
	$	246,621		$	229,207
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities	$	10,111		$	9,386
Income taxes					1,660
Total current liabilities		10,111			11,046
Long-term liabilities:
Bank debt		11,400			11,400
Deferred income taxes		40,778			35,884
Asset retirement obligations		2,709			2,573
Other		1,926			6,295
Total long-term liabilities		56,813			56,152
Total liabilities		66,924			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; 28,618 and 28,529 shares outstanding, respectively		286			285
Additional paid-in capital		87,924			86,576
Retained earnings		91,264			75,118
Accumulated other comprehensive income		223			30
Total stockholders’ equity		179,697			162,009
	$	246,621		$	229,207

See accompanying notes.

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

	Nine months ended				Three months ended
	September 30,				September 30,
	2013		2012		2013			2012
Revenue:
Coal sales	$	103,129	$	98,259	$	34,985		$	36,152
Equity income - Savoy		4,495		2,999		2,048			501
Equity income - Sunrise Energy		519		49		172			17
Liability extinguishment (Note 9)		4,300
Other (Note 6)		3,615		4,938		455			444
		116,058		106,245		37,660			37,114
Costs and expenses:
Operating costs and expenses		68,959		57,994		23,407			20,745
DD&A		13,982		11,895		4,772			4,145
Coal exploration costs		1,725		1,900		739			778
SG&A		5,586		5,607		1,936			1,947
Interest		1,131		757		308			229
		91,383		78,153		31,162			27,844

Income before income taxes		24,675		28,092		6,498			9,270

Less income taxes:
Current		1,297		5,607		(609	)		1,731
Deferred		4,915		3,684		2,277			1,349
		6,212		9,291		1,668			3,080
Net income (1)	$	18,463	$	18,801	$	4,830		$	6,190
Net income excluding the $4.3 million liability extinguishment	$	15,281	$	18,801	$	4,830		$	6,190
Net income per share:
Basic	$	0.65	$	0.66	$	0.17		$	0.22
Diluted	$	0.64	$	0.65	$	0.17		$	0.22
Net income per share excluding the $4.3 million liability extinguishment:
Basic	$	0.53	$	0.66	$	0.17		$	0.22
Diluted	$	0.53	$	0.65	$	0.17		$	0.22
Weighted average shares outstanding:
Basic		28,580		28,316		28,607			28,324
Diluted		28,851		28,791		28,838			28,760
___________________________________
(1) There is no material difference between net income and comprehensive income.

See accompanying notes.

Consolidated Condensed Statement of Cash Flows
(in thousands)

	Nine months ended September 30,

	2013			2012
Operating activities:
Cash provided by operating activities	$	20,310		$	29,552

Investing activities:
Capital expenditures for coal properties		(23,558	)		(9,222	)
Ohio River Terminal		(2,866	)
Purchase of marketable securities					(1,291	)
Other		256			(423	)
Cash used in investing activities		(26,168	)		(10,936	)

Financing activities:
Payments to bank					(7,500	)
Dividends		(2,317	)		(18,721	)
Other					276
Cash used in financing activities		(2,317	)		(25,945	)

Decrease in cash and cash equivalents		(8,175	)		(7,329	)
Cash and cash equivalents, beginning of period		21,888			37,542
Cash and cash equivalents, end of period	$	13,713		$	30,213

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		13				1,724								1,724

Other		76		1		(376	)					193		(182	)

Dividends									(2,317	)				(2,317	)

Net income									18,463					18,463

Balance, September 30, 2013		28,618	$	286	$	87,924		$	91,264		$	223	$	179,697

_____________________________________

*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 nine months ended September 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 storage agreement by 50,000 tons 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 nine months ended September 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 nine months ended September 30, 2013. No tons were placed in storage during the 2013 third quarter. As of September 30, 2013, we have in storage 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 October 31, 2013, all receivables outstanding from these two customers at September 30, 2013 had been collected.

(3) Bank Debt

During October 2012, Sunrise, 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 September 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 $120 million due to our current covenants. 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 September 30, 2013, and a condensed statement of operations for the nine months ended September 30, 2013 and 2012.

Condensed Balance Sheet


	2013

Current assets	$	25,651
Oil and gas properties, net		24,156
	$	49,807

Total liabilities	$	14,354
Partners' capital		35,453
	$	49,807

Condensed Statement of Operations

	2013			2012

Revenue	$	29,444		$	24,585
Expenses		(19,471	)		(17,931	)
Net income	$	9,973		$	6,654

(5) Investment in Sunrise Energy

We own a 50% interest in Sunrise Energy, LLC which owns gas reserves in gathering equipment with plans to develop and operate such reserves. 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 September 30, 2013, and a condensed statement of operations for the nine months ended September 30, 2013 and 2012.

Condensed Balance Sheet


	2013

Current assets	$	2,849
Oil and gas properties, net		6,777
	$	9,626

Total liabilities	$	661
Members' capital		8,965
	$	9,626

Condensed Statement of Operations


	2013			2012

Revenue	$	2,551		$	1,671
Expenses		(1,513	)		(1,573	)
Net income	$	1,038		$	98

(6) Other Long-Term Assets and Other Income

	September 30, 2013			December 31, 2012

Long-term assets:
Advance coal royalties		$	3,936	$	3,324
Deferred financing costs, net			1,270		1,494
Marketable equity securities available for sale, at fair value (restricted)*			3,601		3,548
Ohio River Terminal (see Note 8)			2,881
Miscellaneous			3,503		2,941
		$	15,191	$	11,307

______________________

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

	Nine months ended September 30,
		2013		2012
Other income:
MSHA reimbursements*		$	2,053	$	4,236
Coal storage fees			964		127
Miscellaneous			598		575
		$	3,615	$	4,938

______________________

*See “MSHA Reimbursements” on page 13.

(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 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 late 2014.

(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 relating to a terminated coal contract was no longer required. The amount had no effect on cash flows.

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. Over 81% 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.

Our customers have made or announced plans to make significant investments in pollution control equipment at their plants. 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/mild winters and summers
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 quarter of 2013	825,000	$43.99
Year 2014	3,145,000	42.96
Year 2015	1,200,000	41.40
Year 2016	338,000	40.57

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
				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 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# 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 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. Ace currently has 20% of its capacity contracted for 2013 and 2014. We have invested $18 million in minerals, land, equipment and development as of September 30, 2013 and we anticipate investing an additional $1 million in equipment and development for the remainder of 2013.

During the third quarter we sold 17,000 high sulfur and 17,000 low sulfur tons from Ace. These sales which approximated $1.4 million were recorded as a reduction to the property accounts as the Ace mine was in the development stage. We expect the Ace mine to transition to the production stage in November.

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 or second 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 December 31, 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 nine months of 2013 our capex was about $23.5 million allocated as follows:

	in 000’s
Carlisle - maintenance capex	$	11,881
Carlisle - expansion/improvements		2,782
Carlisle - land and minerals		333
Ace - mine development		4,262
Ace - surface equipment		4,733
Ace - land and minerals		102
Other projects		208
Items accrued for but not paid		(743	)
Capex per the Cash Flow Statement	$	23,558

For the remainder of the year we expect maintenance capex for Carlisle to be $2.5 million. For the Ace surface mine we expect capex to be $1 million and we expect maintenance capex to be $100 thousand. Capex for the Ohio River Terminal is expected to be $100 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, paid on May 15, 2013. In addition to the August $.04 dividend, on October 15, our Board authorized a $.04 dividend payable November 15, 2013. In the past we only declared special dividends.

Results of Operations

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

	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		42.80
Operating costs		21,745		23,290		22,262		23,407		90,704
Average cost/ton		28.92		27.73		28.76		28.65		28.50
Margin		11,366		10,705		11,887		11,578		45,536
Margin/ton		15.11		12.74		15.36		14.17		14.31
Capex		16,987		8,604		6,174		8,780		40,545

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

Tons sold		921		701		743		810		3,175
Coal sales	$	37,723	$	29,620	$	32,487	$	36,152	$	135,982
Average price/ton		40.96		42.25		43.72		44.63		42.83
Operating costs		21,129		18,433		18,816		20,745		79,123
Average cost/ton		22.94		26.30		25.32		25.61		24.92
Margin		16,594		11,187		13,671		15,407		56,859
Margin/ton		18.02		15.96		18.40		19.02		17.91
Capex		15,970		2,372		1,857		4,993		25,192

__________________________

*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 Bulldog and Carlisle. Capex in the fourth quarter of 2011 includes $9 million for the purchase of land for Bulldog.

First Nine Months 2013 vs. 2012

For the first nine months of 2013, we sold 2,431,000 tons at an average price of $42.42/ton. For the first nine months of 2012, we sold 2,255,000 tons at an average price of $43.57/ton. The lower average price is due to the mix of our various contracts. We expect our coal sales for the last quarter of 2013 to be circa 825 thousand tons with an average price of $43.99/ton as set forth in the table on page 11.

Operating costs and expenses averaged $28.37/ton in 2013 compared to $25.72 in 2012. The increase was due primarily to poor mining conditions in the months of January, February, April and May. Additionally, costs increased due to below normal wash plant recovery (60-63%) in the months of May and August. We anticipate wash plant recovery’s remaining in the upper 60s in the 4th quarter 2013, before returning to our historical recovery of 72%. Thus, we expect costs to average $27-$28/ton for the remainder of 2013.

Our Indiana employees totaled 374 at September 30, 2013 compared to 327 at September 30, 2012. Part of the employee increase (19) was due to the opening of the new Ace-in-the-Hole Mine in January of this year.

Three Months Ended September 30, 2013 vs. 2012

For the third quarter of 2013, we sold 817,000 tons at an average price of $42.82/ton. For the third quarter of 2012, we sold 810,000 tons at an average price of $44.63/ton.

Operating costs and expenses averaged $28.65/ton in 2013 compared to $25.61 in 2012. The higher costs are discussed above.

We expect our margins for the remainder of the year to be in the $16-$17/ton range.

Other Analyses of Results of Operations

Savoy’s activity is discussed below.

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 25% 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

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 1,100 barrels of oil. Oil and liquids make up 98% of their oil and gas revenue.

The first nine months 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 $95/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 nine months of 2013 to 2012 (financial statement data in thousands):

	2013		2012
Revenue:
Oil	$	24,081	$	19,730
NGLs (natural gas liquids)		658		679
Natgas		549		267
Contract drilling		3,168		3,552
Other		988		357
Total revenue		29,444		24,585
Costs and expenses:
LOE (lease operating expenses)		4,060		3,451
Contract drilling costs		2,296		2,578
DD&A (depreciation, depletion & amortization)		4,634		2,843
G&G (geological and geophysical) costs		2,278		2,689
Dry hole costs		1,408		2,527
Impairment of unproved properties		3,472		2,950
Other exploration costs		275		195
G&A (general & administrative)		1,048		698
Total expenses		19,471		17,931
Net income	$	9,973	$	6,654

The information below is not in thousands:

Oil production – barrels		253,070		218,350
NGLs production – barrels		17,357		13,995
Natgas production – Mcf		156,328		97,240
Average oil prices/barrel for the nine months	$	95.18	$	90.36
Average NGL prices/barrel for the nine months	$	37.90	$	48.52
Average natgas prices/Mcf for the nine months	$	3.52	$	2.75

New Accounting Pronouncements

None of the recent FASB pronouncements will have any material effect on us.

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 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.

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.

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: November 1, 2013		/s/W. Anderson Bishop
		W. Anderson Bishop, CFO and CAO