KIRBY CORP - Quarter Report: 2013 June (Form 10-Q)

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

¨	Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission File Number 1-7615

KIRBY CORPORATION

(Exact name of registrant as specified in its charter)

Nevada		74-1884980
(State or other jurisdiction of incorporation or organization)		(IRS Employer Identification No.)

55 Waugh Drive, Suite 1000,		77007
Houston, TX		(Zip Code)
(Address of principal executive offices)

(713) 435-1000

(Registrant’s telephone number, including area code)

No Change

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No ¨

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 Regulations S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “large accelerated filer” and “accelerated filer” in Rule 12b-2 of the Exchange Act.

Large accelerated filer	x	Accelerated filer	¨

Non-accelerated filer	¨	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 ¨ No x

The number of shares outstanding of the registrant’s Common Stock, $.10 par value per share, on August 2, 2013 was 56,768,000.

PART I – FINANCIAL INFORMATION

Item 1.

Financial Statements

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED BALANCE SHEETS

(Unaudited)

ASSETS

	June 30, 2013			December 31, 2012
	($ in thousands)
Current assets:
Cash and cash equivalents	$	5,263		$	11,059
Accounts receivable:
Trade – less allowance for doubtful accounts		331,131			313,182
Other		46,489			43,074
Inventories – net		139,547			177,397
Prepaid expenses and other current assets		38,277			39,248
Deferred income taxes		6,464			12,296

Total current assets		567,171			596,256

Property and equipment		3,332,462			3,219,113
Less accumulated depreciation		(948,499	)		(903,948	)

Property and equipment – net		2,383,963			2,315,165

Goodwill		599,001			596,030
Other assets		174,174			145,677

Total assets	$	3,724,309		$	3,653,128

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED BALANCE SHEETS

(Unaudited)

LIABILITIES AND STOCKHOLDERS’ EQUITY

	June 30, 2013			December 31, 2012
	($ in thousands)
Current liabilities:
Current portion of long-term debt	$	78,000		$	65,000
Income taxes payable		4,107			2,369
Accounts payable		165,502			156,763
Accrued liabilities		121,973			114,031
Deferred revenues		31,506			16,857

Total current liabilities		401,088			355,020

Long-term debt – less current portion		943,240			1,070,110
Deferred income taxes		467,885			426,096
Other long-term liabilities		75,936			94,848

Total long-term liabilities		1,487,061			1,591,054

Contingencies and commitments		—			—

Equity:
Kirby stockholders’ equity:
Common stock, $.10 par value per share. Authorized 120,000,000 shares, issued 59,776,000 shares		5,978			5,978
Additional paid-in capital		401,826			397,785
Accumulated other comprehensive income – net		(58,237	)		(61,127	)
Retained earnings		1,558,750			1,439,079
Treasury stock – at cost, 3,020,000 at June 30, 2013 and 3,191,000 at December 31, 2012		(83,596	)		(86,747	)
Total Kirby stockholders’ equity		1,824,721			1,694,968
Noncontrolling interests		11,439			12,086
Total equity		1,836,160			1,707,054

Total liabilities and equity	$	3,724,309		$	3,653,128

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED STATEMENTS OF EARNINGS

(Unaudited)

	Three months ended June 30,						Six months ended June 30,
	2013			2012			2013			2012
	($ in thousands, except per share amounts)
Revenues:
Marine transportation	$	423,868		$	342,195		$	842,386		$	678,152
Diesel engine services		140,040			169,653			280,307			400,631
Total revenues		563,908			511,848			1,122,693			1,078,783

Costs and expenses:
Costs of sales and operating expenses		369,587			345,916			738,861			730,275
Selling, general and administrative		40,938			43,199			85,094			96,299
Taxes, other than on income		4,397			3,907			8,875			7,821
Depreciation and amortization		40,271			35,197			81,267			71,671
Gain on disposition of assets		(537	)		(69	)		(505	)		(41	)
Total costs and expenses		454,656			428,150			913,592			906,025

Operating income		109,252			83,698			209,101			172,758
Other income		101			30			176			179
Interest expense		(7,219	)		(5,901	)		(15,207	)		(11,741	)

Earnings before taxes on income		102,134			77,827			194,070			161,196
Provision for taxes on income		(38,342	)		(29,392	)		(72,726	)		(60,882	)

Net earnings		63,792			48,435			121,344			100,314
Less: Net earnings attributable to noncontrolling interests		(699	)		(884	)		(1,673	)		(1,819	)

Net earnings attributable to Kirby	$	63,093		$	47,551		$	119,671		$	98,495

Net earnings per share attributable to Kirby common stockholders:
Basic	$	1.11		$	.85		$	2.11		$	1.76
Diluted	$	1.11		$	.85		$	2.10		$	1.76

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three months ended June 30,						Six months ended June 30,
	2013			2012			2013			2012
	($ in thousands)

Net earnings	$	63,792		$	48,435		$	121,344		$	100,314
Other comprehensive income (loss), net of taxes:
Pension and postretirement benefits		494			(1,268	)		1,671			(279	)
Foreign currency translation adjustments		44			152			249			447
Change in fair value of derivative instruments		(4	)		1,420			970			2,500
Total comprehensive income, net of taxes		534			304			2,890			2,668

Total comprehensive income, net of taxes		64,326			48,739			124,234			102,982
Net earnings attributable to noncontrolling interests		(699	)		(884	)		(1,673	)		(1,819	)

Comprehensive income attributable to Kirby	$	63,627		$	47,855		$	122,561		$	101,163

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Six months ended June 30,
	2013			2012
	($ in thousands)
Cash flows from operating activities:
Net earnings	$	121,344		$	100,314
Adjustments to reconcile net earnings to net cash provided by operations:
Depreciation and amortization		81,267			71,671
Provision for deferred income taxes		47,883			33,774
Amortization of unearned share-based compensation		5,061			4,489
Other		3,475			2,127
Increase (decrease) in cash flows resulting from changes in operating assets and liabilities, net		10,245			(75,773	)
Net cash provided by operating activities		269,275			136,602

Cash flows from investing activities:
Capital expenditures		(168,175	)		(153,846	)
Acquisition of businesses and marine equipment		(3,643	)		−
Proceeds from disposition of assets		13,111			6,651
Net cash used in investing activities		(158,707	)		(147,195	)

Cash flows from financing activities:
Borrowings (payments) on bank credit facilities, net		(112,870	)		10,530
Borrowings on long-term debt		225,000			−
Payments on long-term debt		(226,000	)		(13,003	)
Proceeds from exercise of stock options		2,573			1,250
Payment of contingent liability		(5,000	)		−
Excess tax benefit from equity compensation plans		2,253			2,375
Other		(2,320	)		(1,003	)
Net cash provided by (used in) financing activities		(116,364	)		149
Decrease in cash and cash equivalents		(5,796	)		(10,444	)

Cash and cash equivalents, beginning of year		11,059			16,249
Cash and cash equivalents, end of period	$	5,263		$	5,805

Supplemental disclosures of cash flow information:
Cash paid during the period:
Interest	$	8,012		$	10,619
Income taxes	$	17,969		$	19,174

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

In the opinion of management, the accompanying unaudited condensed financial statements of Kirby Corporation and consolidated subsidiaries (the “Company”) contain all adjustments (consisting of only normal recurring accruals) necessary to present fairly the financial position as of June 30, 2013 and December 31, 2012, and the results of operations for the three months and six months ended June 30, 2013 and 2012.

(1)	BASIS FOR PREPARATION OF THE CONDENSED FINANCIAL STATEMENTS

The condensed financial statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Although the Company believes that the disclosures are adequate to make the information presented not misleading, certain information and footnote disclosures, including significant accounting policies normally included in annual financial statements, have been condensed or omitted pursuant to such rules and regulations. It is suggested that these condensed financial statements be read in conjunction with the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.

(2)	ACCOUNTING STANDARDS ADOPTION

In February 2013, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2013-02, “Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income” (“ASU 2013-02”). ASU 2013-02 established the effective date for the requirement to present components of reclassifications out of accumulated other comprehensive income (“OCI”) on the face of the financial statements. The adoption of ASU 2013-02 in the first quarter of 2013 did not have an impact on the Company’s consolidated financial statements except the Company has applied these provisions to its presentation of consolidated financial statements.

(3)	ACQUISITIONS

On December 28, 2012, the Company purchased the assets of Flag Service & Maintenance, Inc. (“Flag”) for $6,864,000 in cash. Flag was an East Coast high-speed diesel engine service provider, operating factory-authorized full service marine dealerships for Caterpillar, Cummins, MTU and John Deere diesel engines.

On December 14, 2012, the Company completed the acquisition of Penn Maritime Inc. and Maritime Investments LLC (“Penn”), an operator of tank barges and tugboats participating in the coastal transportation of primarily refinery feedstocks, asphalt and crude oil in the United States. The total value of the transaction was $300,538,000, consisting of $146,750,000 of cash, $29,080,000 through the issuance of 500,000 shares of Company common stock valued at $58.16 per share, and $124,708,000 of cash for the retirement of Penn’s debt. Penn’s fleet, comprised of 18 double hull tank barges with a capacity of 1.9 million barrels and 16 tugboats, operates along the East Coast and Gulf Coast of the United States.

On November 1, 2012, the Company purchased from Allied Transportation Company (“Allied”) 10 coastal tank barges with a total capacity of 680,000 barrels, three offshore dry-bulk barges with a total capacity of 48,000 deadweight tons and seven coastal tugboats for $108,547,000 in cash plus a provision for up to $10,000,000 that will be paid contingent on developments with the sugar provisions in the United States Farm Bill. The fair value of the contingent liability recorded at the acquisition date was $9,756,000. A payment of $5,000,000 was made in the 2013 first quarter on the contingent liability. Allied provided coastal transportation of petrochemicals as well as dry sugar products in the Northeast, Atlantic and Gulf Coast regions of the United States.

(4)	INVENTORIES

The following table presents the details of inventories as of June 30, 2013 and December 31, 2012 (in thousands):

	June 30, 2013		December 31, 2012
Finished goods	$	116,822	$	162,859
Work in process		22,725		14,538
	$	139,547	$	177,397

(5)	FAIR VALUE MEASUREMENTS

The accounting guidance for using fair value to measure certain assets and liabilities establishes a three tier value hierarchy, which prioritizes the inputs to valuation techniques used in measuring fair value. These tiers include: Level 1, defined as observable inputs such as quoted prices in active markets for identical assets or liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little, if any, market data exists, therefore requiring an entity to develop its own assumptions about the assumptions that market participants would use in pricing the asset or liability.

The following table summarizes the assets and liabilities measured at fair value on a recurring basis as of June 30, 2013 and December 31, 2012 (in thousands):

June 30, 2013:	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total Fair Value Measurements
Assets:
Derivatives	$	—	$	—	$	—	$	—

Liabilities:
Derivatives	$	—	$	30	$	—	$	30
Contingent liabilities		—		—		12,780		12,780
	$	—	$	30	$	12,780	$	12,810

December 31, 2012:	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total Fair Value Measurements
Assets:
Derivatives	$	—	$	—	$	—	$	—

Liabilities:
Derivatives	$	—	$	1,525	$	—	$	1,525
Contingent liabilities		—		—		28,067		28,067
	$	—	$	1,525	$	28,067	$	29,592

The fair value of the Company’s derivative instruments is more fully described below in Note 6, Derivative Instruments.

In connection with the acquisition of Allied on November 1, 2012, Allied’s former owners are eligible to receive up to an additional $10,000,000 payable in 2013 through 2015, contingent on developments with the sugar provisions in the United States Farm Bill. The fair value of the contingent liability recorded at the acquisition date was $9,756,000. The fair value of the contingent liability is based on a valuation of the estimated fair value of the liability after probability weighting and discounting various potential payments. A payment of $5,000,000 was made in the 2013 first quarter on the contingent liability. The increase in the fair value of the contingent liability for the three months and six months ended June 30, 2013 was $14,000 and $113,000, respectively, was charged to selling, general and administrative expense. As of June 30, 2013, the Company had recorded a contingent liability of $4,880,000.

In connection with the acquisition of United Holdings LLC (“United”) on April 15, 2011, United’s former owners are eligible to receive a three-year earnout provision for up to an additional $50,000,000 payable in 2014, dependent on achieving certain financial targets. The fair value of the contingent earnout liability recorded at the acquisition date was $16,300,000. The fair value of the earnout is based on a valuation of the estimated fair value of the liability after probability weighting and discounting various potential payments. The decrease in the fair value of the earnout liability for the three months and six months ended June 30, 2013 was $6,100,000 and $10,400,000, respectively, was credited to selling, general and administrative expense. As of June 30, 2013, the Company had recorded an earnout liability of $7,900,000.

The estimated fair value of total debt outstanding at June 30, 2013 and December 31, 2012 was $995,608,000 and $1,130,967,000, respectively, which differs from the carrying amounts of $1,021,240,000 and $1,135,110,000, respectively, included in the consolidated financial statements. The fair value was determined using an income approach that relies on inputs such as yield curves. Cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities have carrying values that approximate fair value due to the short-term maturity of these financial instruments.

Certain assets are measured at fair value on a nonrecurring basis and therefore are not included in the table above. These assets are adjusted to fair value when there is evidence of impairment. During the six months ended June 30, 2013, there was no indication that the Company’s long-lived assets were impaired, and accordingly, measurement at fair value was not required.

(6)	DERIVATIVE INSTRUMENTS

The Company recognizes all derivative instruments at fair value in the balance sheet as either assets or liabilities. The accounting for changes in the fair value of a derivative instrument depends on the intended use of the derivative and the resulting designation, which is established at the inception date of a derivative. For derivative instruments designated as cash flow hedges, changes in fair value, to the extent the hedge is effective, are recognized in OCI until the hedged item is recognized in earnings. Hedge effectiveness is measured at least quarterly based on the cumulative difference between the fair value of the derivative contract and the hedged item over time. Any change in fair value resulting from ineffectiveness is recognized immediately in earnings.

Interest Rate Risk Management

From time to time, the Company has utilized derivative financial instruments with respect to a portion of its interest rate risks to achieve a more predictable cash flow by reducing its exposure to interest rate fluctuations. These transactions generally are interest rate swap agreements and are entered into with large multinational banks. On February 28, 2013, all of the Company’s outstanding interest rate swaps expired. These interest rate swaps, with a total notional amount of $200,000,000, were designated as cash flow hedges.

Foreign Currency Risk Management

From time to time, the Company has utilized derivative financial instruments with respect to its forecasted foreign currency transactions to attempt to reduce the risk of its exposure to foreign currency rate fluctuations in its transactions denominated in foreign currency. These transactions, which relate to foreign currency obligations for the purchase of equipment from foreign suppliers or foreign currency receipts from foreign customers, generally are forward contracts or purchased call options and are entered into with large multinational banks.

As of June 30, 2013, the Company had a forward contract with a notional amount of $469,000 to hedge its exposure to foreign currency rate fluctuations in expected foreign currency transactions. This contract expires in the first quarter of 2014. This forward contract is designated as a cash flow hedge, therefore, the change in fair value, to the extent the forward contract is effective, is recognized in OCI until the forward contract expires and is recognized in cost of sales and operating expenses.

Fair Value of Derivative Instruments

The following table sets forth the fair value of the Company’s derivative instruments recorded as liabilities located on the consolidated balance sheet at June 30, 2013 and December 31, 2012 (in thousands):

Liability Derivatives	Balance Sheet Location	June 30, 2013		December 31, 2012
Derivatives designated as hedging instruments under ASC 815:

Foreign currency contracts	Other accrued liabilities	$	30	$	−
Foreign currency contracts	Other long-term liabilities		−		39
Interest rate contracts	Other accrued liabilities		−		1,486

Total derivatives designated as hedging instruments under ASC 815		$	30	$	1,525
Total liability derivatives		$	30	$	1,525

Fair value amounts were derived as of June 30, 2013 and December 31, 2012 utilizing fair value models of the Company and its counterparties on the Company’s portfolio of derivative instruments. These fair value models use the income approach that relies on inputs such as yield curves, currency exchange rates and forward prices. The fair value of the Company’s derivative instruments is described above in Note 5, Fair Value Measurements.

Cash Flow Hedges

For derivative instruments that are designated and qualify as cash flow hedges, the effective portion of the gain or loss on the derivative is reported as a component of OCI and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings. Gains and losses on the derivative representing either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness are recognized in current earnings. Any ineffectiveness related to the Company’s hedges was not material for any of the periods presented.

The following table sets forth the location and amount of gains and losses on the Company’s derivative instruments in the consolidated statements of earnings for the three months and six months ended June 30, 2013 and 2012 (in thousands):

	Location of Gain (Loss)		Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)					Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
	Reclassified from		Three months ended					Three months ended
Derivatives in ASC 815 Cash	Accumulated OCI into Income		June 30,					June 30,
Flow Hedging Relationships:	(Effective Portion)		2013			2012		2013		2012
Interest rate contracts	Interest expense	$	─		$	2,030	$	─	$	(2,056	)

Foreign exchange contracts	Cost and sales of operating expenses		(8	)		172	─			─	)

Total		$	(8	)	$	2,202	$	─	$	(2,056	)

	Location of Gain (Loss)		Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)				Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
	Reclassified from		Six months ended				Six months ended
Derivatives in ASC 815 Cash	Accumulated OCI into Income		June 30,				June 30,
Flow Hedging Relationships:	(Effective Portion)		2013		2012		2013			2012
Interest rate contracts	Interest expense	$	1,486	$	3,623	$	(1,389	)	$	(4,100	)

Foreign exchange contracts	Cost and sales of operating expenses		7		249	─				(2	)

Total		$	1,493	$	3,872	$	(1,389	)	$	(4,102	)

The Company expects $30,000 of net losses on foreign currency contracts included in accumulated OCI will be transferred into earnings over the next year based on current spot rates.

(7)	STOCK AWARD PLANS

The Company has share-based compensation plans which are described below. The compensation cost that has been charged against earnings for the Company’s stock award plans and the income tax benefit recognized in the statement of earnings for stock awards for the three months and six months ended June 30, 2013 and 2012 were as follows (in thousands):

	Three months ended June 30,						Six months ended June 30,
	2013			2012			2013			2012
Compensation cost		$	2,927		$	2,583		$	5,061		$	4,489
Income tax benefit		$	1,106		$	987		$	1,913		$	1,715

The Company has an employee stock award plan for selected officers and other key employees which provide for the issuance of stock options, restricted stock and performance awards. The exercise price for each option equals the fair market value per share of the Company’s common stock on the date of grant. The terms of the options granted prior to January 25, 2010 are five years and vest ratably over three years. Options granted on or after January 25, 2010 have terms of seven years and vest ratably over three years. No performance awards payable in stock have been awarded under the Plan. At June 30, 2013, 2,678,355 shares were available for future grants under the employee plan and no outstanding stock options under the employee plan were issued with stock appreciation rights.

The following is a summary of the stock option activity under the employee plan described above for the six months ended June 30, 2013:

	Outstanding Non- Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2012		351,173		$	45.54
Granted		109,560		$	70.65
Exercised		(43,449	)	$	28.75
Outstanding at June 30, 2013		417,284		$	53.88

The following table summarizes information about the Company’s outstanding and exercisable stock options under the employee plan at June 30, 2013:

		Options Outstanding								Options Exercisable
Range of Exercise Prices		Number Outstanding		Weighted Average Remaining Contractual Life in Years		Weighted Average Exercise Price		Aggregate Intrinsic Value		Number Exercisable		Weighted Average Exercise Price		Aggregate Intrinsic Value
$	23.98 - 32.56		93,249		3.4	$	31.96				93,249	$	31.96
$	34.40 - 36.35		14,000		1.3	$	34.96				14,000	$	34.96
$	46.74		100,569		4.6	$	46.74				67,039	$	46.74
$	65.28 - 70.65		209,466		6.1	$	68.34				33,299	$	65.80
$	23.98 - 70.65		417,284		5.0	$	53.88	$	10,706,000		207,587	$	42.36	$	7,717,000

The following is a summary of the restricted stock award activity under the employee plan described above for the six months ended June 30, 2013:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2012		418,128		$	45.39
Granted		128,125		$	68.28
Vested		(138,794	)	$	40.69
Forfeited		(6,582	)	$	63.91
Nonvested balance at June 30, 2013		400,877		$	54.03

The Company has a director stock award plan for nonemployee directors of the Company which provides for the issuance of stock options and restricted stock. The director plan provides for the automatic grants of stock options and restricted stock to nonemployee directors on the date of first election as a director and after each annual meeting of stockholders. In addition, the director plan allows for the issuance of stock options or restricted stock in lieu of cash for all or part of the annual director fee at the option of the director. The exercise prices for all options granted under the plan are equal to the fair market value per share of the Company’s common stock on the date of grant. The terms of the options are ten years. The options granted to a director when first elected vest immediately. The options granted and restricted stock issued after each annual meeting of stockholders vest six months after the date of grant. Options granted and restricted stock issued in lieu of cash director fees vest in equal quarterly increments during the year to which they relate. At June 30, 2013, 610,041 shares were available for future grants under the director plan. The director stock award plan is intended as an incentive to attract and retain qualified independent directors.

The following is a summary of the stock option activity under the director plan described above for the six months ended June 30, 2013:

	Outstanding Non- Qualified or Nonincentive Stock Options			Weighted Average Exercise Price
Outstanding at December 31, 2012		345,938		$	45.84
Granted		54,958		$	75.17
Exercised		(36,000	)	$	36.79
Outstanding at June 30, 2013		364,896		$	51.15

The following table summarizes information about the Company’s outstanding and exercisable stock options under the director plan at June 30, 2013:

		Options Outstanding								Options Exercisable
Range of Exercise Prices		Number Outstanding		Weighted Average Remaining Contractual Life in Years		Weighted Average Exercise Price		Aggregate Intrinsic Value		Number Exercisable		Weighted Average Exercise Price		Aggregate Intrinsic Value
$	17.88		12,000		0.8	$	17.88				12,000	$	17.88
$	20.28- 29.60		36,000		4.5	$	26.49				36,000	$	26.49
$	35.17- 36.82		56,036		3.3	$	35.91				56,036	$	35.91
$	41.24- 56.45		145,596		6.5	$	52.14				145,596	$	52.14
$	61.89- 62.48		60,306		8.9	$	62.38				60,306	$	62.38
$	75.17		54,958		9.8	$	75.17				239	$	75.17
$	17.88- 75.17		364,896		6.5	$	51.15	$	10,358,000		310,177	$	46.92	$	10,119,000

The following is a summary of the restricted stock award activity under the director plan described above for the six months ended June 30, 2013:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2012		348		$	62.99
Granted		10,536		$	75.65
Vested		(732	)	$	69.63
Nonvested balance at June 30, 2013		10,152		$	75.65

The total intrinsic value of all stock options exercised under all of the Company’s plans was $3,342,000 and $1,612,000 for the six months ended June 30, 2013 and 2012, respectively. The actual tax benefit realized for tax deductions from stock option exercises was $1,263,000 and $616,000 for the six months ended June 30, 2013 and 2012, respectively.

The total intrinsic value of all the restricted stock vestings under all of the Company’s plans was $9,230,000 and $11,004,000 for the six months ended June 30, 2013 and 2012, respectively. The actual tax benefit realized for tax deductions from restricted stock vestings was $3,489,000 and $4,204,000 for the six months ended June 30, 2013 and 2012, respectively.

As of June 30, 2013, there was $4,720,000 of unrecognized compensation cost related to nonvested stock options and $19,325,000 related to restricted stock. The stock options are expected to be recognized over a weighted average period of approximately 1.5 years and restricted stock over approximately 3.1 years. The total fair value of options vested was $1,714,000 and $1,326,000 during the six months ended June 30, 2013 and 2012, respectively. The fair value of the restricted stock vested was $9,230,000 and $11,004,000 for the six months ended June 30, 2013 and 2012, respectively.

The weighted average per share fair value of stock options granted during the six months ended June 30, 2013 and 2012 was $25.07 and $22.15, respectively. The fair value of the stock options granted during the six months ended June 30, 2013 and 2012 was $4,125,000 and $3,461,000, respectively. The Company currently uses treasury stock shares for restricted stock grants and stock option exercises. The fair value of each stock option was determined using the Black-Scholes option pricing model. The key input variables used in valuing the options during the six months ended June 30, 2013 and 2012 were as follows:

	Six months ended June 30,
	2013		2012
Dividend yield	None		None
Average risk-free interest rate		1.1%		1.1%
Stock price volatility		34%		33%
Estimated option term	Six years or seven years		Six years or seven years

(8)	OTHER COMPREHENSIVE INCOME

The Company’s changes in other comprehensive income for the three months and six months ended June 30, 2013 and 2012 were as follows (in thousands):

	Three months ended June 30,
	2013									2012
	Gross Amount			Income Tax (Provision) Benefit			Net Amount			Gross Amount			Income Tax (Provision) Benefit			Net Amount

Pension and postretirement benefits (a):
Amortization of net actuarial loss	$	1,934		$	(740	)	$	1,194		$	1,794		$	(704	)	$	1,090
Actuarial gains (losses)		(1,134	)		434			(700	)		(3,851	)		1,493			(2,358	)

Foreign currency translation adjustments		44			—			44			152			—			152

Change in fair value of derivative instruments (b):
Unrealized gains (losses)		(7	)		3			(4	)		4,258			(1,520	)		2,738
Reclassified to net earnings		−			−			−			(2,056	)		738			(1,318	)
Total	$	837		$	(303	)	$	534		$	297		$	7		$	304

	Six months ended June 30,
	2013									2012
	Gross Amount			Income Tax (Provision) Benefit			Net Amount			Gross Amount			Income Tax (Provision) Benefit			Net Amount

Pension and postretirement benefits (a):
Amortization of net actuarial loss	$	3,840		$	(1,469	)	$	2,371		$	3,395		$	(1,316	)	$	2,079
Actuarial gains (losses)		(1,134	)		434			(700	)		(3,851	)		1,493			(2,358	)

Foreign currency translation adjustments		249			—			249			447			—			447

Change in fair value of derivative instruments (b):
Unrealized gains (losses)		2,882			(1,009	)		1,873			7,974			(2,826	)		5,148
Reclassified to net earnings		(1,389	)		486			(903	)		(4,102	)		1,454			(2,648	)
Total	$	4,448		$	(1,558	)	$	2,890		$	3,863		$	(1,195	)	$	2,668

(a)	Actuarial gains (losses) are amortized into costs of sales and operating expenses or selling, general and administrative expenses as appropriate. (See Note 12 – Retirement Plans)

(b)	Reclassifications to net earnings of derivatives qualifying as effective hedges are recognized in interest expense or costs of sales and operating expenses as appropriate. (See Note 6 – Derivative Instruments)

(9)	SEGMENT DATA

The Company’s operations are classified into two reportable business segments as follows:

Marine Transportation — Marine transportation principally by United States flag vessels of liquid cargoes throughout the United States inland waterway system, coastwise along all three United States coasts and in Alaska and Hawaii and, to a lesser extent, United States coastal transportation of dry-bulk cargoes. The principal products transported include petrochemicals, black oil, refined petroleum products and agricultural chemicals.

Diesel Engine Services — Provides after-market services for medium-speed and high-speed diesel engines, reduction gears and ancillary products for marine and power generation applications, distributes and services high-speed diesel engines, transmissions, pumps and compression products, and manufactures and remanufactures oilfield service equipment, including pressure pumping units, for the land-based pressure pumping and oilfield service markets.

The Company’s two reportable business segments are managed separately based on fundamental differences in their operations. The Company evaluates the performance of its segments based on the contributions to operating income of the respective segments, before income taxes, interest, gains or losses on disposition of assets, other nonoperating income, noncontrolling interests, accounting changes, and nonrecurring items. Intersegment sales for the three months and six months ended June 30, 2013 and 2012 were not significant.

The following table sets forth the Company’s revenues and profit or loss by reportable segment for the three months and six months ended June 30, 2013 and 2012 and total assets as of June 30, 2013 and December 31, 2012 (in thousands):

	Three months ended June 30,						Six months ended June 30,
	2013			2012			2013			2012
Revenues:
Marine transportation	$	423,868		$	342,195		$	842,386		$	678,152
Diesel engine services		140,040			169,653			280,307			400,631
	$	563,908		$	511,848		$	1,122,693		$	1,078,783
Segment profit (loss):
Marine transportation	$	97,563		$	71,730		$	186,816		$	140,220
Diesel engine services		14,932			15,118			28,954			38,672
Other		(10,361	)		(9,021	)		(21,700	)		(17,696	)
	$	102,134		$	77,827		$	194,070		$	161,196

	June 30, 2013		December 31, 2012
Total assets:
Marine transportation	$	3,054,231	$	2,951,723
Diesel engine services		616,496		647,986
Other		53,582		53,419
	$	3,724,309	$	3,653,128

The following table presents the details of “Other” segment loss for the three months and six months ended June 30, 2013 and 2012 (in thousands):

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

General corporate expenses	$	(3,780	)	$	(3,219	)	$	(7,174	)	$	(6,175	)
Gain on disposition of assets		537			69			505			41
Interest expense		(7,219	)		(5,901	)		(15,207	)		(11,741	)
Other income		101			30			176			179
	$	(10,361	)	$	(9,021	)	$	(21,700	)	$	(17,696	)

The following table presents the details of “Other” total assets as of June 30, 2013 and December 31, 2012 (in thousands):

	June 30, 2013		December 31, 2012
General corporate assets	$	51,574	$	51,611
Investment in affiliates		2,008		1,808
	$	53,582	$	53,419

(10)	TAXES ON INCOME

Earnings before taxes on income and details of the provision for taxes on income for the three months and six months ended June 30, 2013 and 2012 were as follows (in thousands):

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

Earnings before taxes on income – United States	$	102,134	$	77,827	$	194,070	$	161,196
Provision for taxes on income:
Federal:
Current	$	8,102	$	10,416	$	17,532	$	20,096
Deferred		26,386		15,591		47,883		33,774
State and local		3,854		3,385		7,311		7,012
	$	38,342	$	29,392	$	72,726	$	60,882

(11)	EARNINGS PER SHARE

The following table presents the components of basic and diluted earnings per share of common stock for the three months and six months ended June 30, 2013 and 2012 (in thousands, except per share amounts):

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

Net earnings attributable to Kirby	$	63,093		$	47,551		$	119,671		$	98,495
Undistributed earnings allocated to restricted shares		(459	)		(375	)		(859	)		(769	)
Income available to Kirby common stockholders - basic		62,634			47,176			118,812			97,726
Undistributed earnings allocated to restricted shares		459			375			859			769
Undistributed earnings reallocated to restricted shares		(457	)		(374	)		(856	)		(765	)
Income available to Kirby common stockholders - diluted	$	62,636		$	47,177		$	118,815		$	97,730

Shares outstanding:
Weighted average common stock issued and outstanding		56,752			55,869			56,712			55,839
Weighted average unvested restricted stock		(413	)		(441	)		(407	)		(436	)
Weighted average common stock outstanding - basic		56,339			55,428			56,305			55,403
Dilutive effect of stock options		190			212			188			235
Weighted average common stock outstanding - diluted		56,529			55,640			56,493			55,638

Net earnings per share attributable to Kirby common stockholders:
Basic	$	1.11		$	.85		$	2.11		$	1.76
Diluted	$	1.11		$	.85		$	2.10		$	1.76

Certain outstanding options to purchase approximately 165,000 and 157,000 shares of common stock were excluded in the computation of diluted earnings per share as of June 30, 2013 and 2012, respectively, as such stock options would have been antidilutive.

(12)	RETIREMENT PLANS

The Company sponsors a defined benefit plan for its inland vessel personnel and shore based tankermen. The plan benefits are based on an employee’s years of service and compensation. The plan assets consist primarily of equity and fixed income securities.

The Company’s pension plan funding strategy has historically been to contribute an amount equal to the greater of the minimum required contribution under ERISA or the amount necessary to fully fund the plan on an accumulated benefit obligation (“ABO”) basis at the end of the fiscal year. The ABO is based on a variety of demographic and economic assumptions, and the pension plan assets’ returns are subject to various risks, including market and interest rate risk, making an accurate prediction of the pension plan contribution difficult. Based on current pension plan assets and market conditions, the Company does not expect to make a contribution to its pension plan prior to December 31, 2013 to fund its 2013 pension plan obligations. As of June 30, 2013, no 2013 year contributions have been made.

The Company sponsors an unfunded defined benefit health care plan that provides limited postretirement medical benefits to employees who meet minimum age and service requirements, and to eligible dependents. The plan limits cost increases in the Company’s contribution to 4% per year. The plan is contributory, with retiree contributions adjusted annually. The plan eliminated coverage for future retirees as of December 31, 2011. The Company also has an unfunded defined benefit supplemental executive retirement plan (“SERP”) that was assumed in an acquisition in 1999. That plan ceased to accrue additional benefits effective January 1, 2000.

The components of net periodic benefit cost for the Company’s defined benefit plans for the three months and six months ended June 30, 2013 and 2012 were as follows (in thousands):

		Pension Benefits
		Pension Plan						SERP
		Three months ended June 30,						Three months ended June 30,
		2013			2012			2013		2012
Components of net periodic benefit cost:
Service cost	$	3,243		$	2,539		$	—	$	—
Interest cost		2,867			2,670			18		19
Expected return on plan assets		(4,039	)		(3,218	)		—		—
Amortization of actuarial loss		2,083			1,946			4		3
Net periodic benefit cost	$	4,154		$	3,937		$	22	$	22

		Pension Benefits
		Pension Plan						SERP
		Six months ended June 30,						Six months ended June 30,
		2013			2012			2013		2012
Components of net periodic benefit cost:
Service cost	$	6,414		$	5,105		$	—	$	—
Interest cost		5,702			5,254			35		37
Expected return on plan assets		(8,066	)		(6,438	)		—		—
Amortization of actuarial loss		4,139			3,698			9		7
Net periodic benefit cost	$	8,189		$	7,619		$	44	$	44

The components of net periodic benefit cost for the Company’s postretirement benefit plan for the three months and six months ended June 30, 2013 and 2012 were as follows (in thousands):

		Other Postretirement Benefits						Other Postretirement Benefits
		Postretirement Welfare Plan						Postretirement Welfare Plan
		Three months ended June 30,						Six months ended June 30,
		2013			2012			2013			2012
Components of net periodic benefit cost:
Service cost	$	—		$	—		$	—		$	—
Interest cost		28			34			56			67
Amortization of actuarial gain		(153	)		(156	)		(308	)		(310	)
Net periodic benefit cost	$	(125	)	$	(122	)	$	(252	)	$	(243	)

(13)	CONTINGENCIES

On January 30, 2012 in the U.S. District Court for the District of New Jersey in a case styled Rescue Mission of El Paso., Inc., et al. v. John J. Nicola, et al., the Company, its subsidiary, K-Sea Transportation Partners L.P. ("K-Sea"), and current and former officers and directors of K-Sea were named defendants in a putative class action complaint asserting that during the period of January 30, 2009 to January 27, 2010, K-Sea allegedly failed to disclose certain facts regarding K-Sea’s operations and financial condition, and asserting violations of Sections 10(b)(5) and 20(a) of the Securities and Exchange Act of 1934 and Rule 10b-5 thereunder. Plaintiff sought class certification, compensatory damages, attorneys’ fees and costs. The Plaintiff filed its Amended Consolidated Complaint on behalf of the class on July 9, 2012. The Company filed a motion to dismiss in response to the Complaint. On June 18, 2013, the Court granted the Company's motion to dismiss the case.

The Company is involved in various legal and other proceedings which are incidental to the conduct of its business, none of which in the opinion of management will have a material effect on the Company’s financial condition, results of operations or cash flows. Management believes that it has recorded adequate reserves and believes that it has adequate insurance coverage or has meritorious defenses for these other claims and contingencies.

The Company has issued guaranties or obtained standby letters of credit and performance bonds supporting performance by the Company and its subsidiaries of contractual or contingent legal obligations of the Company and its subsidiaries incurred in the ordinary course of business. The aggregate notional value of these instruments was $45,818,000 at June 30, 2013, including $6,128,000 in letters of credit and $39,690,000 in performance bonds. All of these instruments have an expiration date within five years. The Company does not believe demand for payment under these instruments is likely and expects no material cash outlays to occur in connection with these instruments.

Item 1A.

Risk Factors

The Company continues to be subject to the risk factors previously disclosed in its “Risk Factors” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.

Item 2.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Statements contained in this Form 10-Q that are not historical facts, including, but not limited to, any projections contained herein, are forward-looking statements and involve a number of risks and uncertainties. Such statements can be identified by the use of forward-looking terminology such as “may,” “will,” “expect,” “anticipate,” “estimate” or “continue,” or the negative thereof or other variations thereon or comparable terminology. The actual results of the future events described in such forward-looking statements in this Form 10-Q could differ materially from those stated in such forward-looking statements. Among the factors that could cause actual results to differ materially are: adverse economic conditions, industry competition and other competitive factors, adverse weather conditions such as high water, low water, tropical storms, hurricanes, tsunamis, fog and ice, marine accidents, lock delays, fuel costs, interest rates, construction of new equipment by competitors, government and environmental laws and regulations, and the timing, magnitude and number of acquisitions made by the Company. For a more detailed discussion of factors that could cause actual results to differ from those presented in forward-looking statements, see Item 1A-Risk Factors found in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012. Forward-looking statements are based on currently available information and the Company assumes no obligation to update any such statements.

For purposes of the Management’s Discussion, all net earnings per share attributable to Kirby common stockholders are “diluted earnings per share.” The weighted average number of common shares applicable to diluted earnings per share for the three months and six months ended June 30, 2013 and 2012 were as follows (in thousands):

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

Weighted average number of common stock - diluted		56,529		55,640		56,493		55,638

The increase in the weighted average number of common shares for the 2013 second quarter and first six months compared with the 2012 second quarter and first six months primarily reflects the issuance of 500,000 shares of Company common stock associated with the December 14, 2012 acquisition of Penn, the issuance of restricted stock and the exercise of stock options.

Overview

The Company is the nation’s largest domestic tank barge operator, transporting bulk liquid products throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise along all three United States coasts and in Alaska and Hawaii. The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge. As of June 30, 2013, the Company operated a fleet of 863 inland tank barges with 17.3 million barrels of capacity, and operated an average of 262 inland towboats during the 2013 second quarter. The Company’s coastal fleet consisted of 79 tank barges with 6.2 million barrels of capacity and 86 coastal tugboats. The Company also operates eight offshore barge and tug units transporting dry-bulk commodities in United States coastal trade. Through its diesel engine services segment the Company provides after-market services for medium-speed and high-speed diesel engines, reduction gears and ancillary products for marine and power generation applications, distributes and services high-speed diesel engines and transmissions, pumps and compression products, and manufactures and remanufacturers oilfield service equipment, including pressure pumping units, for the land-based pressure pumping and oilfield service markets.

For the 2013 second quarter, net earnings attributable to Kirby were $63,093,000, or $1.11 per share, on revenues of $563,908,000, compared with 2012 second quarter net earnings attributable to Kirby of $47,551,000, or $.85 per share, on revenues of $511,848,000. For the 2013 first six months, net earnings attributable to Kirby were $119,671,000, or $2.10 per share, on revenues of $1,122,693,000, compared with 2012 first six months net earnings attributable to Kirby of $98,495,000, or $1.76 per share, on revenues of $1,078,783,000. The 2013 second quarter and first six months results included a credit to selling, general and administrative expenses of $6,100,000 before taxes, or $.07 per share, and $10,400,000 before taxes, or $.11 per share, respectively, decreasing the fair value of the contingent earnout liability associated with the April 2011 acquisition of United. This compares with a charge to selling, general and administrative expenses of $100,000 before taxes for the 2012 second quarter and $4,300,000 before taxes, or $.05 per share, for the 2012 first six months, increasing the fair value of the contingent earnout liability. The 2013 second quarter included an estimated $.03 per share negative impact from high water on the Mississippi and Illinois Rivers and the negative impact of the closure for repair of the Algiers Lock near New Orleans on the Gulf Intracoastal Waterway, net of certain revenue and cost recovery from contracts with terms that provide reimbursements for delays and increased costs. Also, the 2012 second quarter and first six months operating results included a $499,000 before taxes, or $.01 per share, and $2,920,000 before taxes, or $.03 per share, respectively, severance charge associated with the integration of Kirby Offshore Marine’s administrative functions into the Company.

Marine Transportation

For the 2013 second quarter and first six months, 75% of the Company’s revenue was generated by its marine transportation segment. The segment’s customers include many of the major petrochemical and refining companies that operate in the United States. Products transported include intermediate materials used to produce many of the end products used widely by businesses and consumers — plastics, fiber, paints, detergents, oil additives and paper, among others, as well as residual fuel oil, ship bunkers, asphalt, gasoline, diesel fuel, heating oil, crude oil, gas condensate and agricultural chemicals. Consequently, the Company’s marine transportation business mirrors the volumes produced by the Company’s petroleum, petrochemical and refining customer base. The 2013 second quarter and first six months results include the operations of Allied, acquired on November 1, 2012, and Penn, acquired on December 14, 2012.

The Company’s marine transportation segment’s revenues for the 2013 second quarter and first six months increased 24% compared with the 2012 second quarter and first six months. The segment’s operating income for 2013 second quarter and first six months increased 36% and 33%, respectively, compared with the operating income for the 2012 second quarter and first six months. The higher marine transportation revenues reflected continued strong demand across all inland marine transportation markets, petrochemicals, black oil, refined petroleum products and agricultural chemicals, along with continued favorable pricing trends. The Company’s inland petrochemical and black oil fleets achieved consistent tank barge utilization levels in the 90% to 95% range throughout the 2013 second quarter and first six months. High water conditions on the Mississippi and Illinois Rivers during the entire 2013 second quarter, and the closure of the Algiers Lock located on the Gulf Intracoastal Waterway due to structural damage during the entire second quarter created heavy congestion and multi-day delays in the New Orleans area and along the alternate route to the Mississippi River at the Bayou Sorrels and Port Allen Locks. During the 2012 second quarter, low water conditions on the Mississippi River System in mid-May and throughout June created delays and increased transit times. The Company’s coastal marine transportation markets continued to improve with tank barge utilization levels in the 90% range, aided by the addition of petrochemical volumes with the acquisition of the Allied fleet and additional black oil volumes with the acquisition of Penn, along with increased transportation of crude oil and gas condensate.

During the 2013 and 2012 second quarters and first six months, approximately 75% of marine transportation’s inland revenues were under term contracts and 25% were spot contract revenues, thereby providing the operations with a predictable revenue stream. Inland time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented 58% and 57%, respectively, of the revenues under term contracts during the 2013 second quarter and first six months compared with 56% during the 2012 second quarter and first six months.

During the 2013 second quarter and first six months, approximately 75% of the coastal revenues were under term contracts and 25% were spot contract revenues. Coastal time charters represented approximately 90% of the revenues under term contracts during the 2013 second quarter and first six months. For the 2012 second quarter and first six months, approximately 60% of the coastal revenues were under term contracts and 40% were spot contract revenues. The increase in term contracts reflected stronger demand for coastal tank barges, new contracts with inland customers with coastal tank barge requirements and the 2012 fourth quarter acquisitions of Allied and Penn.

Rates on inland term contracts renewed in the 2013 second quarter and first six months increased in the 4% to 6% average range compared with term contracts renewed in the second quarter and first six months of 2012. Spot contract rates in the 2013 first and second quarters, which include the cost of fuel, increased modestly compared with the prior quarter. Effective January 1, 2013, annual escalators for labor and the producer price index on a number of inland multi-year contracts resulted in rate increases on those contracts by approximately 1%, excluding fuel.

Rates on coastal term contracts renewed in the 2013 second quarter and first six months increased in the 7% to 9% average range compared with term contracts renewed in the 2012 second quarter and first six months. Spot contract rates, which include the cost of fuel, improved in the 5% to 9% average range during the 2013 first quarter when compared with the 2012 fourth quarter, and spot contract rates for the 2013 second quarter improved in the 4% to 6% average range compared with the 2013 first quarter.

The marine transportation operating margin was 23.0% for the 2013 second quarter compared with 21.0% for the 2012 second quarter, and 22.2% for the 2013 first six months compared with 20.7% for the 2012 first six months.

Diesel Engine Services

For the 2013 second quarter and first six months, 25% of the Company’s revenue was generated by its diesel engine services segment, of which 48% and 53% was generated from overhauls and service, 28% and 23% from manufacturing, and 24% and 24% from direct parts sales, respectively. The results of the diesel engine services segment are largely influenced by the economic cycles of the marine and power generation markets and the land-based pressure pumping and oilfield services industries.

Diesel engine services revenues for the 2013 second quarter and first six months decreased 17% and 30%, respectively, and operating income decreased 1% and 25%, respectively, when compared with the second quarter and first six months of 2012. The 2013 second quarter and first six months results included a $6,100,000 before taxes and a $10,400,000 before taxes, respectively, credit to selling, general and administrative expenses, resulting from a net decrease in the fair value of the contingent earnout liability associated with the April 2011 acquisition of United. The 2012 second quarter and first six months results included a $100,000 before taxes and a $4,300,000 before taxes, respectively, charge to selling, general and administrative expenses from a net increase in the fair value of the contingent earnout liability associated with the acquisition of United. The 2013 second quarter and first six months decreases in revenues and operating income were mainly attributable to a continuation of lower demand for the manufacturing of pressure pumping units, as well as a decline in the sales and service of land-based diesel engines, transmissions and parts sales. Partially offsetting the decline in the manufacturing of pressure pumping units was an increase in the number of pressure pumping units remanufactured. The marine diesel engine services market remained stable, benefiting from major service projects for inland and coastal customers, partially offset by the deferral of scheduled service projects by Midwest customers negatively impacted by the decline in bulk shipments of coal and grain due to market conditions and the high water conditions on the Mississippi and Illinois Rivers throughout the 2013 second quarter. The power generation market, consisting of major engine-generator set upgrades market conditions and parts sales for both domestic and international power generation customers, was stable.

The diesel engine services operating margin for the 2013 second quarter was 10.7% compared with 8.9% for the 2012 second quarter. For the 2013 first six months, the operating margin was 10.3% compared with 9.7% for the first six months of 2012. The operating margin for the 2013 second quarter and first six months was positively impacted by the $6,100,000 and $10,400,000, respectively, credit to the contingent earnout liability noted above, while the operating margin for the 2012 second quarter and first six months was negatively impacted by the $100,000 and $4,300,000, respectively, charge to the contingent earnout liability.

Cash Flow and Capital Expenditures

The Company continued to generate strong operating cash flow during the 2013 first six months, with net cash provided by operating activities of $269,275,000 compared with $136,602,000 of net cash provided by operating activities for the 2012 first six months. The 97% increase was primarily from higher net earnings attributable to Kirby, higher depreciation and amortization and a higher deferred tax provision in the 2013 first six months versus the 2012 first six months, and an $86,018,000 net increase in cash flows from changes in operating assets and liabilities. In addition, during the 2013 and 2012 first six months, the Company generated cash of $2,573,000 and $1,250,000, respectively, from the exercise of stock options and $13,111,000 and $6,651,000, respectively, from proceeds from the disposition of assets.

For the 2013 first six months, cash generated and borrowings under the Company’s revolving credit facility were used for capital expenditures of $168,175,000, including $106,297,000 for inland tank barge and towboat construction, $12,333,000 for progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units completed in the 2013 second quarter, and $49,545,000 primarily for upgrading the existing marine transportation fleet. The Company’s debt-to-capitalization ratio decreased to 35.7% at June 30, 2013 from 39.9% at December 31, 2012, primarily due to a decrease of $113,870,000 of debt outstanding and the increase in total equity from net earnings attributable to Kirby for the 2013 first six months of $119,671,000, exercise of stock options, and the amortization of unearned equity compensation. As of June 30, 2013, the Company had $70,940,000 outstanding under its revolving credit facility, $442,000,000 outstanding under its term loan, of which $78,000,000 was classified as current portion of long-term debt, $500,000,000 of senior notes outstanding and $8,300,000 outstanding under its credit agreement.

During the 2013 first six months, the Company took delivery of 51 new inland tank barges with a total capacity of approximately 1,100,000 barrels, and retired 26 inland tank barges and returned three charter inland tank barges, reducing its capacity by approximately 450,000 barrels. As a result, the Company added a net 22 inland tank barges and approximately 650,000 barrels of capacity.

The Company projects that capital expenditures for 2013 will be in the $230,000,000 to $240,000,000 range. The 2013 construction program will consist of 68 inland tank barges with a total capacity of 1,375,000 barrels and three inland towboats. Based on current commitments, steel prices and projected delivery schedules, the Company’s 2013 payments on new inland tank barges and towboats will be approximately $135,000,000 and approximately $12,000,000 in progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units delivered in the 2013 second quarter with an estimated total cost of $53,000,000 for each unit. The balance of approximately $83,000,000 to $93,000,000 is primarily capital upgrades and improvements to existing marine equipment and marine transportation and diesel engine services facilities.

Outlook

Petrochemical and black oil inland tank barge utilization levels remained strong during the 2013 first six months, in the 90% to 95% range. While the United States economy remains sluggish with consistently high unemployment levels, the United States petrochemical industry continues to see strong production levels for both domestic consumption and exports. Low priced domestic natural gas, a basic feedstock for the United States petrochemical industry, provides the industry with a competitive advantage against foreign petrochemical producers. As a result, United States petrochemical production has remained strong throughout 2012 and the 2013 first six months, thereby producing increased marine transportation volumes of basic petrochemicals to both domestic consumers and terminals for export destinations. The black oil market has also remained strong throughout 2012 and the 2013 first six months, primarily due to a continued stable United States refinery utilization levels, aided by the export of diesel fuel and heavy fuel oil, and demand for the transportation of crude oil and gas condensate from shale formations in South Texas, as well as the movement of Canadian, Bakken and Utica crude oil and gas condensate from the Midwest to the Gulf Coast.

The United States petrochemical industry is globally competitive based on a number of factors, including a highly integrated and efficient transportation system of pipelines, tank barges, railroads and trucks, largely depreciated yet well maintained and operated facilities, and a low cost feedstock slate, which includes natural gas. Certain United States producers have announced plans for plant capacity expansions and the reopening of idled petrochemical facilities. The current production volumes from the Company’s petrochemical and refinery customers have resulted in the Company’s inland petrochemical and black oil tank barge utilization levels in the 90% to 95% range and any increased production from current facilities, plant expansions or the reopening of idled facilities should drive feedstock and production volumes higher, in turn leading to higher tank barge utilization levels and higher term and contract pricing, which could be mitigated by additional tank barge capacity.

As of June 30, 2013, the Company estimated there were approximately 3,350 inland tank barges in the industry fleet, of which approximately 500 were over 35 years old and approximately 300 of those were over 40 years old. Given the age profile of the industry inland tank barge fleet, the expectation is that older tank barges will continue to be removed from service and replaced by new tank barges that will enter the fleet. During 2012 and the first six months of 2013, with continued strong demand for inland petrochemical and black oil tank barges and federal tax incentives on new equipment, the Company estimates that approximately 275 inland tank barges were ordered industry-wide during 2012 and early 2013 for delivery throughout 2013. Many older tank barges will be retired, with the extent of the retirements dependent on 2013 petrochemical and refinery production levels, crude oil and gas condensate movements and industry-wide tank barge utilization levels.

During 2011 and the first half of 2012, the marine transportation segment was negatively impacted by excess coastal tank barge capacity limiting tank barge utilization to the 75% range. The coastal operations reflected improvements in market conditions during the 2012 second half and the first half of 2013, with tank barge utilization improving to the 75% to 80% range in the 2012 third quarter, 85% to 90% in the 2012 fourth quarter, and to the 90% range in the 2013 first and second quarters. During the 2012 second half and 2013 first half, the Company experienced increased demand for coastal crude and gas condensate moves and success in expanding the coastal customer base to include inland customers with coastal requirements. The acquisitions of Allied and Penn during the 2012 fourth quarter also contributed to the higher 2013 first six months revenue and operating income. As of June 30, 2013, the Company estimated there were approximately 265 tank barges operating in the 195,000 barrel or less coastal industry fleet, the sector of the market in which the Company operates. The Company believes that very few coastal tank barges were built during 2012, and that very few orders for coastal tank barges have been placed for 2013 deliveries and beyond.

In the diesel engine services segment, with the increase in drilling rigs operating in the Gulf of Mexico, positive inland marine transportation markets during 2012 and the first six months of 2013, and improving coastal marine transportation markets during the 2012 second half and 2013 first half, service activity levels for the marine diesel engine market reflected a modest improvement and should continue to modestly improve as activity increases. The power generation market should remain stable, benefiting from engine-generator set upgrades and parts sales for both domestic and international customers. The land-based diesel engine services market consists of manufacturing and remanufacturing of oilfield service equipment, including pressure pumping units, and servicing their components, which include high-speed diesel engines, transmissions and pumps, many of the same components used by marine customers. Currently, an estimated 18 million horsepower is employed in the North American pressure pumping business. With the current low price of natural gas, the exploration of United States natural gas shale formations has declined, resulting in excess pressure pumping horsepower. However, with the current high price of crude oil, the exploration of United States crude oil shale formations has remained active. As a result of the excess pressure pumping horsepower, new orders for pressure pumping units essentially stopped and the supply and distribution portion of the land-based market slowed. While the Company believes its land-based diesel engine business is at the bottom of the current cycle, it expects it to remain profitable and expects improvement in this market in late 2013 or early 2014. The focus of the Company, currently as well as into the future, will be on the remanufacturing and service of existing pressure pumping equipment.

Acquisitions

On December 28, 2012, the Company purchased the assets of Flag for $6,864,000 in cash. Flag was an East Coast high-speed diesel engine service provider, operating factory-authorized full service marine dealerships for Caterpillar, Cummins, MTU and John Deere diesel engines. Financing of the acquisition was through the Company’s revolving credit facility.

On December 14, 2012, the Company completed the acquisition of Penn, an operator of tank barges and tugboats participating in the coastal transportation of refinery feedstocks, asphalt and crude oil in the United States. The total value of the transaction was $300,538,000, consisting of $146,750,000 of cash, $29,080,000 through the issuance of 500,000 shares of Company common stock valued at $58.16 per share, and $124,708,000 of cash for the retirement of Penn’s debt. Penn’s fleet, comprised of 18 double hull tank barges with a capacity of 1.9 million barrels and 16 tugboats, operates along the East Coast and Gulf Coast of the United States. Financing of the acquisition was through a combination of new senior notes and the issuance of Company common stock.

On November 1, 2012, the Company purchased from Allied 10 coastal tank barges with a total capacity of 680,000 barrels, three offshore dry-bulk barges with a total capacity of 48,000 deadweight tons and seven coastal tugboats for $108,547,000 in cash plus a provision for up to $10,000,000 that will be paid contingent on developments with the sugar provisions in the United States Farm Bill. The fair value of the contingent liability recorded at the acquisition date was $9,756,000. A payment of $5,000,000 was made in the 2013 first quarter on the contingent liability. Allied provided coastal transportation of petrochemicals as well as dry sugar products in the Northeast, Atlantic and Gulf Coast regions of the United States. Financing of the equipment acquisition was through the Company’s revolving credit facility.

Results of Operations

The Company reported 2013 second quarter net earnings attributable to Kirby of $63,093,000, or $1.11 per share, on revenues of $563,908,000, compared with 2012 second quarter net earnings attributable to Kirby of $47,551,000, or $.85 per share, on revenues of $511,848,000. Net earnings attributable to Kirby for the 2013 first six months were $119,671,000, or $2.10 per share, on revenues of $1,122,693,000, compared with $98,495,000, or $1.76 per share, on revenues of $1,078,783,000 for the 2012 first six months. The 2013 second quarter and first six months results included a credit to selling, general and administrative expenses of $6,100,000 before taxes, or $.07 per share, and $10,400,000 before taxes, or $.11 per share, respectively, decreasing the fair value of the contingent earnout liability associated with the April 2011 acquisition of United. This compares with a charge to selling, general and administrative expenses of $100,000 before taxes for the 2012 second quarter and $4,300,000 before taxes, or $.05 per share, for the 2012 first six months, increasing the fair value of the contingent earnout liability. The 2013 second quarter included an estimated $.03 per share negative impact from high water conditions on the Mississippi and Illinois Rivers and the negative impact of the closure of the Algiers Lock located near New Orleans on the Gulf Intracoastal Waterway for repairs, net of certain revenue and cost recovery from contracts with terms that provide reimbursements for delays and increased costs. Also, the 2012 second quarter and first six months operating results included a $499,000 before taxes, or $.01 per share, and $2,920,000 before taxes, or $.03 per share, respectively, severance charge associated with the integration of Kirby Offshore Marine’s administrative functions into the Company.

The following table sets forth the Company’s marine transportation and diesel engine services revenues for the 2013 second quarter compared with the second quarter of 2012, the first six months of 2013 compared with the first six months of 2012 and the percentage of each to total revenues for the comparable periods (dollars in thousands):

	Three months ended June 30,										Six months ended June 30,
	2013		%			2012		%			2013		%			2012		%
Marine transportation	$	423,868		75	%	$	342,195		67	%	$	842,386		75	%	$	678,152		63	%
Diesel engine services		140,040		25			169,653		33			280,307		25			400,631		37
	$	563,908		100	%	$	511,848		100	%	$	1,122,693		100	%	$	1,078,783		100	%

Marine Transportation

The Company, through its marine transportation segment, is a provider of marine transportation services, operating tank barges and towing vessels transporting bulk liquid products throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise along all three United States coasts and in Alaska and Hawaii. The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge. As of June 30, 2013, the Company operated 863 inland tank barges, including 45 leased barges, with a total capacity of 17.3 million barrels. This compares with 818 inland tank barges operated as of June 30, 2012, including 40 leased barges, with a total capacity of 16.4 million barrels. The Company operated an average of 262 inland towboats during the 2013 second quarter, of which an average of 79 were chartered, compared with 239 during the 2012 second quarter, of which an average of 57 were chartered. The Company’s coastal tank barge fleet as of June 30, 2013 consisted of 79 tank barges, two of which were single hull and 12 of which were chartered, with 6.2 million barrels of capacity, and 86 tugboats. This compares with 57 coastal tank barges, three of which were single hull and 12 were leased, with 3.9 million barrels of capacity, and 64 tugboats as of June 30, 2012. The Company operates eight offshore dry-bulk barge and tugboat units, of which one of the tugboats is chartered, engaged in the offshore transportation of dry-bulk cargoes. The Company also owns a two-thirds interest in Osprey Line, L.L.C., which transports project cargoes and cargo containers by barge, as well as a 51% interest in a shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel.

The following table sets forth the Company’s marine transportation segment’s revenues, costs and expenses, operating income and operating margins for the three months and six months ended June 30, 2013 compared with the three months and six months ended June 30, 2012 (dollars in thousands):

	Three months ended June 30,									Six months ended June 30,
	2013			2012			% Change			2013			2012			% Change
Marine transportation revenues	$	423,868		$	342,195			24	%	$	842,386		$	678,152			24	%
Costs and expenses:
Costs of sales and operating expenses		259,332			210,466			23			518,561			413,873			25
Selling, general and administrative		26,439			24,886			6			55,415			53,405			4
Taxes, other than on income		3,928			3,433			14			7,838			6,885			14
Depreciation and amortization		36,606			31,680			16			73,756			63,769			16
		326,305			270,465			21			655,570			537,932			22
Operating income	$	97,563		$	71,730			36	%	$	186,816		$	140,220			33	%
Operating margins		23.0	%		21.0	%					22.2	%		20.7	%

Marine Transportation Revenues

The following table shows the marine transportation markets serviced by the Company, the marine transportation revenue distribution for the 2013 second quarter and first six months, products moved and the drivers of the demand for the products the Company transports:

Markets Serviced	2013 Second Quarter Revenue Distribution	2013 Six Months Revenue Distribution	Products Moved	Drivers
Petrochemicals	48%	48%	Benzene, Styrene, Methanol, Acrylonitrile, Xylene, Caustic Soda, Butadiene, Propylene	Consumer non-durables – 70%, Consumer durables – 30%

Black Oil	24%	24%	Residual Fuel Oil, Coker Feedstock, Vacuum Gas Oil, Asphalt, Carbon Black Feedstock, Crude Oil, Ship Bunkers	Fuel for Power Plants and Ships, Feedstock for Refineries, Road Construction

Refined Petroleum Products	24%	24%	Gasoline, No. 2 Oil, Jet Fuel, Heating Oil, Naphtha, Diesel Fuel, Ethanol	Vehicle Usage, Air Travel, Weather Conditions, Refinery Utilization

Agricultural Chemicals	4%	4%	Anhydrous Ammonia, Nitrogen – Based Liquid Fertilizer, Industrial Ammonia	Corn, Cotton and Wheat Production, Chemical Feedstock Usage

Marine transportation revenues for the 2013 second quarter and first six months increased 24% when compared with the 2012 second quarter and first six months, reflecting the expansion of the coastal transportation business with the acquisition of Allied on November 1, 2012 and Penn on December 14, 2012. The inland tank barge fleet contributed approximately 70% and the coastal fleet approximately 30% of the 2013 second quarter and first six months marine transportation revenues. Equipment utilization during the 2013 second quarter and first six months for the inland petrochemical and black oil fleets remained in the 90% to 95% range and the coastal equipment utilization was in the 90% range, a major improvement over the 75% reported for the 2012 second quarter and first six months.

The petrochemical market, the Company’s largest market, contributed 48% of marine transportation revenues for the 2013 second quarter and first six months, reflecting continued strong volumes from Gulf Coast petrochemical plants for both domestic consumers and to terminals for export destinations. The 2013 second quarter and first six months also included revenues from the 10 coastal tank barges purchased from Allied that transport petrochemicals coastwise.

The black oil market, which contributed 24% of marine transportation revenues for the 2013 second quarter and first six months, also reflected continued strong demand, driven by steady refinery production levels, the export of heavy fuel oils, and increased demand for crude oil and gas condensate transportation on both the inland waterway system and coastwise. The 2013 second quarter and first six months also included revenues from the 18 coastal tank barges acquired with the acquisition of Penn, expanding the Company’s coastal black oil movements of refinery feedstocks, asphalt, crude oil and gas condensate.

The refined petroleum products market, which contributed 24% of marine transportation revenues for the 2013 second quarter and first six months, reflected higher demand for the movement of products in the inland and coastal markets, benefiting from additional volumes from major customers. The coastal refined products market was also driven by continued success in expanding the coastal customer base to inland customers with coastal requirements, as well as a colder winter in the Northeast that increased the demand for distillate products.

The agricultural chemical market, which contributed 4% of 2013 second quarter and first six months marine transportation revenues, saw weak demand during January and February due to winter weather and low water conditions in the Midwest. Demand increased significantly in March for both domestically produced and imported products and continued throughout the second quarter.

For the second quarter of 2013, the inland operations incurred 2,520 delay days, 116% more than the 1,164 delay days that occurred during the 2012 second quarter, and 23% more than the 2,049 delay days that occurred during the 2013 first quarter. For the first six months of 2013, 4,569 delay days occurred, 26% more than the 3,635 delay days that occurred during the 2012 first six months. Delay days measure the lost time incurred by a tow (towboat and one or more tank barges) during transit when the tow is stopped due to weather, lock conditions or other navigational factors. High water conditions on the Mississippi and Illinois Rivers during the entire 2013 second quarter, and the closure of the Algiers Lock located on the Gulf Intracoastal Waterway due to structural damage during the entire second quarter created heavy congestion and multi-day delays in the New Orleans area and along the alternate route to the Mississippi River at the Bayou Sorrels and Port Allen Locks. During the 2012 second quarter, low water conditions on the Mississippi River System in mid-May and throughout June created delays and increased transit times.

During the 2013 and 2012 second quarters and first six months, approximately 75% of marine transportation’s inland revenues were under term contracts and 25% were spot contract revenues. Inland time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented 58% and 57%, respectively, of the revenues under term contracts during the 2013 second quarter and first six months compared with 56% during the 2012 second quarter and first six months. The 75% term contract and 25% spot contract mix provides the inland operations with a predictable revenue stream.

During the 2013 second quarter and first six months, approximately 75% of the coastal revenues were under term contracts and 25% were spot contract revenues. Coastal time charters represented approximately 90% of the revenues under term contracts. For the 2012 second quarter and first six months, approximately 60% of the coastal revenues were under term contracts and 40% were spot contract revenues. The increase in term contracts reflected the stronger demand for coastal tank barges, as well as the 2012 fourth quarter acquisitions of Allied and Penn.

Marine Transportation Costs and Expenses

Costs and expenses for the 2013 second quarter and first six months increased 21% and 22% respectively, compared with the 2012 second quarter and first six months. Costs of sales and operating expenses for the 2013 second quarter and first six months increased 23% and 25%, respectively, compared with the second quarter and first six months of 2012, primarily reflecting the Allied and Penn fourth quarter of 2012 acquisitions, as well as higher costs and expenses due to increased inland and coastal marine transportation demand. In addition, the high water and Algiers Lock issues noted above increased operating expenses.

The inland operations operated an average of 262 towboats during the 2013 second quarter, of which an average of 79 towboats were chartered, compared with 239 during the 2012 second quarter, of which an average of 57 were chartered. During the 2013 first six months, the inland operations operated and average of 259 towboats, of which an average of 76 towboats were chartered, compared with 240 towboats operated during the 2012 first six months, of which an average of 58 were chartered. The increase in the number of towboats operated was a reflection of the higher tank barge utilization levels in the petrochemical and black oil markets during the 2013 second quarter and first six months compared with the 2012 second quarter and first six months, as well as higher demand for towboats associated with the high water and lock closure issues noted above. As demand increases or decreases, or as weather or water conditions dictate, the Company charters-in or releases chartered towboats in an effort to balance horsepower needs with current requirements. The Company has historically used chartered towboats for approximately one-third of its horsepower requirements.

During the 2013 second quarter, the inland operations consumed 11.1 million gallons of diesel fuel compared to 10.8 million gallons consumed during the 2012 second quarter. The average price per gallon of diesel fuel consumed during the 2013 second quarter was $3.22 compared with $3.35 for the 2012 second quarter. For the 2013 first six months, the inland operations consumed 22.1 million gallons of diesel fuel compared to 21.7 million gallons consumed during the 2012 first six months. The average price per gallon of diesel fuel consumed during the 2013 first six months was $3.24 compared with $3.26 for the 2012 first six months. Fuel escalation and de-escalation clauses on term contracts are designed to rebate fuel costs when prices decline and recover additional fuel costs when fuel prices rise; however, there is generally a 30 to 90 day delay before the contracts are adjusted. Spot contracts do not have escalators for fuel.

Selling, general and administrative expenses for the 2013 second quarter and first six months increased 6% and 4%, respectively, compared with the 2012 second quarter and first six months, reflecting the acquisitions of Allied and Penn, and a 2013 first quarter severance charge of $370,000 associated with the integration of Penn's administrative functions into the Company. The 2012 second quarter and first six months included a $499,000 and $2,920,000, respectively, severance charge associated with the integration of Kirby Offshore Marine’s administrative functions into the Company.

Depreciation and amortization for the 2013 second quarter and first six months increased 16% compared with the 2012 second quarter and first six months. The increases were primarily attributable to increased capital expenditures, including new inland tank barges and towboats, and the acquisitions of Allied and Penn.

Marine Transportation Operating Income and Operating Margins

Marine transportation operating income for the 2013 second quarter and first six months increased 36% and 33%, respectively, compared with the 2012 second quarter and first six months. The operating margin was 23.0% for the 2013 second quarter compared with 21.0% for the 2012 second quarter. The operating margin for the 2013 first six months was 22.2% compared with 20.7% for the 2012 first six months. The higher operating income and operating margin was a reflection of continued high inland utilization, leading to higher inland term and spot contract rates negotiated throughout 2012 and the 2013 first six months, as well as higher coastal utilization, including the Allied and Penn equipment, that led to higher coastal term and spot contract rates negotiated in the 2012 fourth quarter and the 2013 first six months.

Diesel Engine Services

The Company, through its diesel engine services segment, sells genuine replacement parts, provides service mechanics to overhaul and repair medium-speed and high-speed diesel engines, transmissions, reduction gears, pumps and compression products, maintains facilities to rebuild component parts or entire medium-speed and high-speed diesel engines, transmissions and entire reduction gears, and manufactures and remanufactures oilfield service equipment, including pressure pumping units. The Company primarily services the marine, power generation and land-based oil and gas operator and producer markets.

The following table sets forth the Company’s diesel engine services segment’s revenues, costs and expenses, operating income and operating margins for the three months and six months ended June 30, 2013 compared with the three months and six months ended June 30, 2012 (dollars in thousands):

	Three months ended June 30,									Six months ended June 30,
	2013			2012			% Change			2013			2012			% Change
Diesel engine services revenues	$	140,040		$	169,653			(17	)%	$	280,307		$	400,631			(30	)%

Costs and expenses:
Costs of sales and operating expenses		110,255			135,450			(19	)		220,300			316,402			(30	)
Selling, general and administrative		11,669			15,860			(26	)		24,434			38,254			(36	)
Taxes, other than on income		457			462			(1	)		1,009			912			11
Depreciation and amortization		2,727			2,763			(1	)		5,610			6,391			(12	)
		125,108			154,535			(19	)		251,353			361,959			(31	)
Operating income	$	14,932		$	15,118			(1	)%	$	28,954		$	38,672			(25	)%
Operating margins		10.7	%		8.9	%					10.3	%		9.7	%

Diesel Engine Services Revenues

The following table shows the markets serviced by the Company’s diesel engine services segment, the revenue distribution for the 2013 second quarter and first six months and the customers for each market:

Markets Serviced	2013 Second Quarter Revenue Distribution	2013 Six Months Revenue Distribution	Customers
Land-Based	66%	65%	Land-Based Oilfield Services, Oil and Gas Operators and Producers, Compression, On-Highway Transportation

Marine	27%	27%	Inland River Carriers – Dry and Liquid, Offshore Towing – Dry and Liquid, Offshore Oilfield Services – Drilling Rigs & Supply Boats, Harbor Towing, Dredging, Great Lake Ore Carriers

Power Generation	7%	8%	Standby Power Generation, Pumping Stations

Diesel engine services revenues for the 2013 second quarter and first six months decreased 17% and 30%, respectively, when compared with the 2012 second quarter and first six months. The decrease for both 2013 periods was primarily attributable to a continuation of lower demand for the manufacturing of pressure pumping units, as well as a decline in the sale and service of land-based diesel engines, transmissions and parts. Partially offsetting the decline in the manufacturing of pressure pumping units was an increase in the number of pressure pumping units remanufactured. The marine diesel engine services market remained stable, benefiting from major service projects for inland and coastal customers, partially offset by the deferral of scheduled service projects by Midwest customers negatively impacted by the decline in bulk shipments of coal and grain due to market conditions and the high water conditions on the Mississippi and Illinois Rivers throughout the second quarter. The power generation market, consisting of major engine-generator set upgrades and parts sales for both domestic and international power generation customers, was stable.

Diesel Engine Services Costs and Expenses

Costs and expenses for the 2013 second quarter and first six months decreased 19% and 31%, respectively, compared with the 2012 second quarter and first six months. The comparable decreases in cost of sales and operating expenses for both 2013 periods were primarily attributable to the lower demand for the manufacturing of pressure pumping units, as well as the decline in the sale and service of land-based diesel engines, transmissions and parts. Selling, general and administrative expenses for the 2013 second quarter and first six months decreased 26% and 36%, respectively, when compared with the corresponding 2012 periods. The 2013 second quarter included a $6,100,000 credit and the 2013 first six months a $10,400,000 credit resulting from a decrease in the fair value of the contingent earnout liability associated with the April 2011 acquisition of United. This compares with a 2012 second quarter and first six months charge from an increase in the fair value of the contingent earnout liability of $100,000 and $4,300,000, respectively.

Diesel Engine Services Operating Income and Operating Margins

Diesel engine services operating income for the 2013 second quarter decreased 1% compared with the 2012 second quarter. For the 2013 first six months, diesel engine services operating income decreased 25% compared with the 2012 first six months. The decreases primarily reflected the significant reduction in the number of pressure pumping units manufactured and the decline in the sale and service of land-based diesel engines, transmissions and parts during the 2013 second quarter and first six months compared with the 2012 same periods. This decline was partially offset by an increase in the remanufacturing of older pressure pumping units. In addition, the 2013 second quarter and first six months operating income included the $6,100,000 and $10,400,000, respectively, earnout credit noted above.

The operating margin for the 2013 second quarter was 10.7% compared with 8.9% for the 2012 second quarter and 10.3% for the 2013 first six months compared with 9.7% for the 2012 first six months. The 2013 second quarter and first six months operating margin primarily reflected the weaker land-based oil services market but benefited from the $6,100,000 and $10,400,000, respectively, earnout credit noted above.

General Corporate Expenses

General corporate expenses for the 2013 second quarter were $3,780,000, a 17% increase compared with $3,219,000 for the second quarter of 2012. For the first six months of 2013, general corporate expenses were $7,174,000, a 16% increase compared with $6,175,000 for the first six months of 2012. The increases were primarily due to higher employee incentive compensation accruals and additional corporate personnel and related costs to support the Allied and Penn acquisitions.

Gain on Disposition of Assets

The Company reported a net gain on disposition of assets of $537,000 for the 2013 second quarter compared with a net gain of $69,000 for the 2012 second quarter. For the 2013 first six months, the Company reported a net gain on disposition of assets of $505,000 compared with a net gain of $41,000 for the first six months of 2012. The net gains were predominantly from the sale or retirement of marine equipment and the sale of a diesel engine services facility.

Other Income (Expense)

The following table sets forth other income, noncontrolling interests and interest expense for the three months and six months ended June 30, 2013 compared with the three months and six months ended June 30, 2012 (dollars in thousands):

	Three months ended June 30,									Six months ended June 30,
	2013			2012			% Change			2013			2012			% Change
Other income	$	101		$	30			237	%	$	176		$	179			(2	)%
Noncontrolling interests	$	(699	)	$	(884	)		(21	)%	$	(1,673	)	$	(1,819	)		(8	)%
Interest expense	$	(7,219	)	$	(5,901	)		22	%	$	(15,207	)	$	(11,741	)		30	%

Interest Expense

Interest expense for the 2013 second quarter and first six months increased 22% and 30%, respectively, compared with the 2012 second quarter and first six months. The increase for both periods was primarily the result of borrowings under the revolving credit facility to finance the November 2012 Allied acquisition, as well as the new senior notes to finance the December 2012 Penn acquisition. During the 2013 and 2012 second quarters, the average debt and average interest rate, including the effect of interest rate swaps for the 2012 second quarter, were $1,047,935,000 and 2.7%, and $778,108,000 and 3.1%, respectively. For the first six months of 2013 and 2012, the average debt and average interest rate, including the effect of interest rate swaps up through February 28, 2013, the date of the expiration of the swaps, were $1,095,445,000 and 2.8%, and $776,301,000 and 3.0%, respectively.

Financial Condition, Capital Resources and Liquidity

Balance Sheet

Total assets as of June 30, 2013 were $3,724,309,000 compared with $3,653,128,000 as of December 31, 2012. The following table sets forth the significant components of the balance sheet as of June 30, 2013 compared with December 31, 2012 (dollars in thousands):

	June 30, 2013		December 31, 2012		% Change
Assets:
Current assets	$	567,171	$	596,256		(5	)%
Property and equipment, net		2,383,963		2,315,165		3
Goodwill, net		599,001		596,030		1
Other assets		174,174		145,677		20
	$	3,724,309	$	3,653,128		2	%
Liabilities and stockholders’ equity:
Current liabilities	$	401,088	$	355,020		13	%
Long-term debt – less current portion		943,240		1,070,110		(12	)
Deferred income taxes		467,885		426,096		10
Other long-term liabilities		75,936		94,848		(20	)
Total equity		1,836,160		1,707,054		8
	$	3,724,309	$	3,653,128		2	%

Current assets as of June 30, 2013 decreased 5% compared with December 31, 2012. Trade accounts receivable increased 6%, primarily a reflection of the increase in revenues for the 2013 second quarter compared with the fourth quarter of 2012. Inventory in the diesel engine services segment decreased 21%, primarily due to a reduction in the number of engines and transmissions on hand at the Company’s land-based diesel engine service facilities that were purchased in 2012 for specific customers and sold in 2013, and the sale of pressure pumping units held on hand.

Property and equipment, net of accumulated depreciation, at June 30, 2013 increased 3% compared with December 31, 2012. The increase reflected $168,175,000 of capital expenditures for the 2013 first six months, more fully described under Capital Expenditures below, less $76,510,000 of depreciation expense for the 2013 first six months and $13,145,000 of property disposals during the 2013 first six months.

Other assets at June 30, 2013 increased 20% compared with December 31, 2012 primarily due to deferred major maintenance dry-dock expenditures on ocean-going vessels during the 2013 first six months.

Current liabilities as of June 30, 2013 increased 13% compared with December 31, 2012. The current portion of long-term debt at June 30, 2013 reflected the reclassification of an additional $13,000,000 of the term loan as current. Accounts payable increased 6%, a reflection of higher voyage and charter boat expenditures associated with higher marine transportation business activity levels, and increased shipyard expenditures due to the 2013 second quarter heavy maintenance schedule of the coastal marine transportation fleet. Accrued liabilities increased 7%, primarily from higher interest expense accruals from borrowings to finance the 2012 fourth quarter acquisitions of Allied and Penn, and the reclassification of $7,900,000 of the United contingent earnout liability from long-term to short-term as the payment is due in April 2014, partially offset by the payments during the 2013 first six months of employee incentive compensation accrued during 2012. Deferred revenues increased 87%, primarily reflecting increased advanced billings for coastal transportation customers.

Long-term debt, less current portion, as of June 30, 2013 decreased 12% compared with December 31, 2012, reflecting payments on the revolving credit facility and term loan during the 2013 first six months and the reclassification of $13,000,000 of the term loan to current portion of long-term debt.

Deferred income taxes as of June 30, 2013 increased 10% compared with December 31, 2012. The increase was primarily due to the 2013 first six months deferred tax provision of $47,883,000. The deferred tax provision was primarily due to bonus tax depreciation on qualifying expenditures due to the American Taxpayers Relief Act of 2012 that provides 50% bonus tax depreciation for capital investments placed in service through December 31, 2013.

Other long-term liabilities as of June 30, 2013 decreased 20% compared with December 31, 2012. The decrease was primarily due to the $10,400,000 decrease during the 2013 first six months in the fair value of the United contingent earnout liability, the reclassification of the remaining $7,900,000 United contingent earnout reserve to other current liabilities, all associated with the acquisition of United in April 2011, and a $5,000,000 payment associated with the $10,000,000 contingent liability recorded at the acquisition date of Allied pertaining to developments with the sugar provisions in the United States Farm Bill.

Total equity as of June 30, 2013 increased 8% compared with December 31, 2012. The increase was primarily the result of $119,671,000 of net earnings attributable to Kirby for the first six months of 2013, a $3,151,000 decrease in treasury stock, a $4,041,000 increase in additional paid-in capital and a $2,890,000 increase in accumulated OCI. The decrease in treasury stock was attributable to the exercise of stock options and the issuance of restricted stock. The increase in additional paid-in capital was due to the excess of proceeds received upon exercise of stock options and the issuance of restricted stock over the cost of the treasury stock issued. The increase in accumulated OCI primarily resulted from the net change in fair value of interest rate swap agreements, net of taxes, more fully described under Fair Value of Derivative Instruments below, and the decrease in unrecognized losses related to the Company’s defined benefit plans.

Long-Term Financing

The Company has $500,000,000 of senior notes (“Senior Notes Series A” and “Senior Notes Series B”) with a group of institutional investors, consisting of $150,000,000 of 2.72% Senior Notes Series A due February 27, 2020 and $350,000,000 of 3.29% Senior Notes Series B due February 27, 2023. The Company issued $82,500,000 of Senior Notes Series A and $192,500,000 of Senior Notes Series B on December 13, 2012, the proceeds of which were used to fund the acquisition of Penn. The Company issued $67,500,000 of Senior Notes Series A and $157,500,000 of Senior Notes Series B on February 27, 2013, the proceeds of which were used to refinance $200,000,000 of floating rate senior notes due February 28, 2013, with the balance used to pay down the Company’s unsecured revolving credit facility. No principal payments are required until maturity. The Senior Notes Series A and Series B contain certain covenants on the part of the Company, including an interest coverage covenant, a debt-to-capitalization covenant and covenants relating to liens, asset sales and mergers, among others. The Senior Notes Series A and Series B also specify certain events of default, upon the occurrence of which the maturity of the notes may be accelerated, including failure to pay principal and interest, violation of covenants or default on other indebtedness, among others. As of June 30, 2013, the Company was in compliance with all Senior Notes Series A and Series B covenants and had $150,000,000 of Senior Notes Series A outstanding and $350,000,000 of Senior Notes Series B outstanding.

The Company has a $325,000,000 unsecured revolving credit facility (“Revolving Credit Facility”) with a syndicate of banks, with JPMorgan Chase Bank, N.A. as the administrative agent bank, with a maturity date of November 9, 2015. The variable interest rate spread varies with the Company’s senior debt rating and is currently 1.5% over the London Interbank Offered Rate (“LIBOR”) or 0.5% over an alternate base rate calculated with reference to the agent bank’s prime rate, among other factors (“Alternate Base Rate”). The commitment fee is currently 0.3%. The Revolving Credit Facility contains certain restrictive financial covenants including an interest coverage ratio and a debt-to-capitalization ratio. In addition to financial covenants, the Revolving Credit Facility contains covenants that, subject to exceptions, restrict debt incurrence, mergers and acquisitions, sales of assets, dividends and investments, liquidations and dissolutions, capital leases, transactions with affiliates and changes in lines of business. Borrowings under the Revolving Credit Facility may be used for general corporate purposes, the purchase of existing or new equipment, the purchase of the Company’s common stock, or for business acquisitions. As of June 30, 2013, the Company was in compliance with all Revolving Credit Facility covenants and had $70,940,000 outstanding under the Revolving Credit Facility. The Revolving Credit Facility includes a $25,000,000 commitment which may be used for standby letters of credit. Outstanding letters of credit under the Revolving Credit Facility were $3,802,000 as of June 30, 2013.

The Company has a credit agreement (“Term Loan”) with a group of commercial banks, with Wells Fargo Bank, National Association as the administrative agent bank, with a maturity date of July 1, 2016. The Term Loan provides for a $540,000,000 five-year unsecured term loan facility with a variable interest rate based on LIBOR or an Alternate Base Rate. The interest rate spread varies with the Company’s senior debt rating and is currently 1.5% over LIBOR or 0.5% over the Alternate Base Rate. The outstanding balance of the Term Loan is subject to quarterly amortization in increasing amounts and is prepayable, in whole or in part, without penalty. The Term Loan contains certain restrictive financial covenants including an interest coverage ratio and a debt-to-capitalization ratio. In addition to financial covenants, the Term Loan contains covenants that, subject to exceptions, restrict debt incurrence, mergers and acquisitions, sales of assets, dividends and investments, liquidations and dissolutions, capital leases, transactions with affiliates and changes in lines of business. As of June 30, 2013, the Company was in compliance with all Term Loan covenants and had $442,000,000 outstanding under the Term Loan, $78,000,000 of which was classified as current portion of long-term debt.

The Company had $200,000,000 of unsecured floating rate senior notes (“Senior Notes”) that were retired on February 28, 2013, the maturity date of the Senior Notes, with the proceeds from the Senior Notes Series A and Senior Notes Series B described above.

The Company has a $10,000,000 line of credit (“Credit Line”) with Bank of America for short-term liquidity needs and letters of credit, with a maturity date of June 29, 2014. The Credit Line allows the Company to borrow at an interest rate agreed to by Bank of America and the Company at the time each borrowing is made or continued. The Company had $8,300,000 of borrowings outstanding under the Credit Line as of June 30, 2013. Outstanding letters of credit under the Credit Line were $947,000 as of June 30, 2013.

Interest Rate Risk Management

From time to time, the Company has utilized derivative financial instruments with respect to a portion of its interest rate risks to achieve a more predictable cash flow by reducing its exposure to interest rate fluctuations. These transactions generally are interest rate swap agreements and are entered into with large multinational banks. On February 28, 2013, all of the Company’s outstanding interest rate swaps expired. These interest rate swaps, with a notional amount of $200,000,000, were designated as cash flow hedges.

Foreign Currency Risk Management

Fair Value of Derivative Instruments

Liability Derivatives	Balance Sheet Location		June 30, 2013	December 31, 2012
Derivatives designated as hedging instruments under ASC 815:

Foreign currency contracts	Other accrued liabilities	$	30	$	−
Foreign currency contracts	Other long-term liabilities		−		39
Interest rate contracts	Other accrued liabilities		─		1,486

Total derivatives designated as hedging instruments under ASC 815		$	30	$	1,525
Total liability derivatives		$	30	$	1,525

Cash Flow Hedges

	Location of Gain (Loss)	Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)						Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
	Reclassified from	Three months ended						Three months ended
Derivatives in ASC 815 Cash	Accumulated OCI into Income	June 30,						June 30,
Flow Hedging Relationships:	(Effective Portion)	2013			2012			2013		2012
Interest rate contracts	Interest expense	$	─			$	2,030	$	─		$	(2,056	)

Foreign exchange contracts	Cost and sales of operating expenses		(8	)			172		─		─
Total		$	(8	)		$	2,202	$	─		$	(2,056	)

	Location of Gain (Loss)	Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)					Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
	Reclassified from	Six months ended					Six months ended
Derivatives in ASC 815 Cash	Accumulated OCI into Income	June 30,					June 30,
Flow Hedging Relationships:	(Effective Portion)	2013		2012			2013			2012
Interest rate contracts	Interest expense	$	1,486		$	3,623	$	(1,389	)		$	(4,100	)

Foreign exchange contracts.. ..	Cost and sales of operating expenses		7			249	─					(2	)
Total		$	1,493		$	3,872	$	(1,389	)		$	(4,102	)

The Company expects $30,000 of net losses on foreign currency contracts included in accumulated OCI will be transferred into earnings over the next year based on the maturity date of the forward contract.

Capital Expenditures

Capital expenditures for the 2013 first six months were $168,175,000 of which $106,297,000 was for construction of new inland tank barges and towboats, $12,333,000 for progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units completed in the 2013 second quarter, and $49,545,000 primarily for upgrading of the existing inland and coastal marine transportation equipment and diesel engine service facilities. Capital expenditures for the 2012 first six months were $153,846,000, of which $69,583,000 was for construction of new tank barges and towboats, and $32,323,000 for progress payments on the construction of the two offshore articulated dry-bulk barge and tugboat units, and $51,940,000 primarily for upgrading of existing inland and coastal marine transportation equipment and diesel engine service facilities. Financing of the construction of the inland tank barges and towboats and offshore dry-bulk barges and tugboats was through operating cash flows and available credit under the Company’s Revolving Credit Facility.

During the 2013 first six months, the Company took delivery of 51 new inland tank barges with a total capacity of approximately 1,100,000 barrels, and retired 26 inland tank barges and returned three charter inland tank barges, decreasing its capacity by approximately 450,000 barrels. As a result, the Company added a net 22 inland tank barges and approximately 650,000 barrels of capacity.

Funding for future capital expenditures is expected to be provided through operating cash flows and available credit under the Company’s Revolving Credit Facility.

Treasury Stock Purchases

The Company did not purchase any treasury stock during the 2013 first six months. As of August 2, 2013, the Company had approximately 2,685,000 shares available under its existing repurchase authorization. Historically, treasury stock purchases have been financed through operating cash flows and borrowing under the Company’s Revolving Credit Facility. The Company is authorized to purchase its common stock on the New York Stock Exchange and in privately negotiated transactions. When purchasing its common stock, the Company is subject to price, trading volume and other market considerations. Shares purchased may be used for reissuance upon the exercise of stock options or the granting of other forms of incentive compensation, in future acquisitions for stock or for other appropriate corporate purposes.

Liquidity

The Company generated net cash provided by operating activities of $269,275,000 during the 2013 first six months compared with $136,602,000 generated during the first six months of 2012. The 2013 first six months experienced a net increase in cash flows from changes in operating assets and liabilities of $10,245,000 compared with a net decrease in the 2012 first six months of $75,773,000. The reduction was primarily due to a decrease in inventory during the 2013 first six months due to the sale during 2013 of inventories to specific customers that were purchased in 2012 and the sale of pressure pumping units on hand. In addition, deferred revenue increased during the 2013 first six months due to increased advance billings for coastal transportation customers compared to a decrease in deferred revenue during the 2012 first six months.

Funds generated from operations are available for acquisitions, capital expenditure projects, common stock repurchases, repayments of borrowings, and for other corporate and operating requirements. In addition to net cash flow provided by operating activities, the Company also had available as of August 1, 2013, $281,550,000 under its Revolving Credit Facility and $9,053,000 available under its Credit Line.

Neither the Company, nor any of its subsidiaries, is obligated on any debt instrument, swap agreement, or any other financial instrument or commercial contract which has a rating trigger, except for pricing grids on its Revolving Credit Facility and Term Loan.

The Company expects to continue to fund expenditures for acquisitions, capital construction projects, common stock repurchases, repayment of borrowings, and for other operating requirements from a combination of available cash and cash equivalents, funds generated from operating activities and available financing arrangements.

The Revolving Credit Facility’s commitment is in the amount of $325,000,000 and expires November 9, 2015. As of June 30, 2013, the Company had $254,060,000 available under the Revolving Credit Facility. The Senior Notes Series A and Senior Notes Series B do not mature until February 27, 2020 and February 27, 2023, respectively, and require no prepayments. The outstanding balance of the Term Loan is subject to quarterly amortization in increasing amounts and is prepayable, in whole or in part, without penalty.

There are numerous factors that may negatively impact the Company’s cash flow in 2013. For a list of significant risks and uncertainties that could impact cash flows, see Note 13, Contingencies in the financial statements, and Item 1A — Risk Factors and Note 14, Contingencies and Commitments, in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012. Amounts available under the Company’s existing financial arrangements are subject to the Company continuing to meet the covenants of the credit facilities as described under “Long-Term Financing” above and in Note 6, Long-Term Debt, in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.

Marine transportation term contracts contain fuel escalation clauses or the customer pays for the fuel. However, there is generally a 30 to 90 day delay before contracts are adjusted depending on the specific contract. In general, the fuel escalation clauses are effective over the long-term in allowing the Company to recover changes in fuel costs due to fuel price changes. However, the short-term effectiveness of the fuel escalation clauses can be affected by a number of factors including, but not limited to, specific terms of the fuel escalation formulas, fuel price volatility, navigating conditions, tow sizes, trip routing, and the location of loading and discharge ports that may result in the Company over or under recovering its fuel costs. Spot contract rates generally reflect current fuel prices at the time the contract is signed but do not have escalators for fuel.

During the last three years, inflation has had a relatively minor effect on the financial results of the Company. The marine transportation segment has long-term contracts which generally contain cost escalation clauses whereby certain costs, including fuel as noted above, can be passed through to its customers. Spot contract rates include the cost of fuel and are subject to market volatility. The repair portion of the diesel engine services segment is based on prevailing current market rates.

Item 3.

Quantitative and Qualitative Disclosures about Market Risk

The Company is exposed to risk from changes in interest rates on certain of its outstanding debt. The outstanding loan balances under the Company’s bank credit facilities bear interest at variable rates based on prevailing short-term interest rates in the United States and Europe. A 10% change in variable interest rates would impact the 2013 interest expense by $182,000 based on balances outstanding at December 31, 2012, and would change the fair value of the Company’s debt by less than 1%.

Item 4.

Controls and Procedures

The Company’s management, with the participation of the Chief Executive Officer and the Chief Financial Officer, has evaluated the Company’s disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934 (the “Exchange Act”) as of June 30, 2013. Based on that evaluation, the Chief Executive Officer and the Chief Financial Officer concluded that, as of June 30, 2013, the disclosure controls and procedures were effective to ensure that information required to be disclosed by the Company in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms. There were no changes in the Company’s internal control over financial reporting during the quarter ended June 30, 2013 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1.

Legal Proceedings

Material developments in legal proceedings are disclosed in Note 13 to the condensed financial statements contained in this report. That disclosure is incorporated by reference into this Item 1.

Item 6.

Exhibits


31.1	–	Certification of Chief Executive Officer Pursuant to Rule 13a-14(a)
31.2	–	Certification of Chief Financial Officer Pursuant to Rule 13a-14(a)
32	–	Certification Pursuant to 18 U.S.C. Section 1350
101.INS*	–	XBRL Instance Document
101.SCH*	–	XBRL Taxonomy Extension Schema Document
101.CAL*	–	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*	–	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*	–	XBRL Taxonomy Extension Label Linkbase Document
101.PRE*	–	XBRL Taxonomy Extension Presentation Linkbase Document

These exhibits are furnished herewith. In accordance with Rule 406T of Regulation S-T, these exhibits are not deemed to be filed or part of a registration statement or prospectus for purposes of Sections 11 or 12 of the Securities Act of 1933, as amended, are not deemed to be filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise are not subject to liability under those sections.

SIGNATURES

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.

	KIRBY CORPORATION
	(Registrant)

	By:	/s/ DAVID W. GRZEBINSKI
		David W. Grzebinski
		Executive Vice President and
		Chief Financial Officer
Dated: August 2, 2013