10-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

(Mark One)

þ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2011

or

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from             to             

Commission file no. 1-7615

Kirby Corporation

(Exact name of registrant as specified in its charter)

Nevada	74-1884980
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
55 Waugh Drive, Suite 1000 Houston, Texas	77007
(Address of principal executive offices)	(Zip Code)

Registrant’s telephone number, including area code:

(713) 435-1000

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class	Name of Each Exchange on Which Registered
Common Stock — $.10 Par Value Per Share	New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:

None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.    Yes  þ    No  ¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Exchange Act.    Yes  ¨    No  þ

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

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

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.  ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer	þ	Accelerated filer	¨
Non-accelerated filer	¨  (Do not check if a smaller reporting company)	Smaller reporting company	¨

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

The aggregate market value of common stock held by nonaffiliates of the registrant as of June 30, 2011, based on the closing sales price of such stock on the New York Stock Exchange on June 30, 2011, was $2,915,796,000. For purposes of this computation, all executive officers, directors and 10% beneficial owners of the registrant are deemed to be affiliates. Such determination should not be deemed an admission that such executive officers, directors and 10% beneficial owners are affiliates.

As of February 22, 2012, 55,847,000 shares of common stock were outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

The Company’s definitive proxy statement in connection with the Annual Meeting of Stockholders to be held April 24, 2012, to be filed with the Commission pursuant to Regulation 14A, is incorporated by reference into Part III of this report.

KIRBY CORPORATION

2011 FORM 10-K

TABLE OF CONTENTS

	Page
PART I
Item 1. Business		3
THE COMPANY		3
Documents and Information Available on Web Site		3
BUSINESS AND PROPERTY		4
MARINE TRANSPORTATION		5
Marine Transportation Industry Fundamentals		6
Inland Tank Barge Industry		6
Coastal Tank Barge Industry		8
Competition in the Tank Barge Industry		8
Marine Transportation Acquisitions		8
Products Transported		9
Demand Drivers in the Tank Barge Industry		10
Marine Transportation Operations		10
Contracts and Customers		14
Employees		14
Properties		14
Governmental Regulations		15
Environmental Regulations		16
DIESEL ENGINE SERVICES		18
Diesel Engine Services Acquisition		18
Marine Operations		19
Marine Customers		19
Marine Competitive Conditions		20
Power Generation Operations		20
Power Generation Customers		20
Power Generation Competitive Conditions		20
Railroad Operations		21
Land-Based Operations		21
Land-Based Customers		21
Land-Based Competitive Conditions		22
Employees		22
Properties		22
Executive Officers of the Registrant		22
Item 1A. Risk Factors		25
Item 1B. Unresolved Staff Comments		30
Item 2. Properties		30
Item 3. Legal Proceedings		30
PART II
Item  5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities		32
Item 6. Selected Financial Data		33
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations		33
Item 7A. Quantitative and Qualitative Disclosures about Market Risk		58
Item 8. Financial Statements and Supplementary Data		60
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure		60
Item 9A. Controls and Procedures		60
PART III
Items 10 Through 14		62
PART IV
Item 15. Exhibits and Financial Statement Schedules		100

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PART I

Item 1. Business

THE COMPANY

Kirby Corporation (the “Company”) was incorporated in Nevada on January 31, 1969 as a subsidiary of Kirby Industries, Inc. (“Industries”). The Company became publicly owned on September 30, 1976 when its common stock was distributed pro rata to the stockholders of Industries in connection with the liquidation of Industries. At that time, the Company was engaged in oil and gas exploration and production, marine transportation and property and casualty insurance. Since then, through a series of acquisitions and divestitures, the Company has become a marine transportation and diesel engine services company. In 1990, the name of the Company was changed from “Kirby Exploration Company, Inc.” to “Kirby Corporation” because of the changing emphasis of its business. Today, 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, and along all three United States coasts and in Alaska and Hawaii. The Company transports petrochemicals, black oil products, refined petroleum products and agricultural chemicals by tank barge. Through the diesel engine services segment, the Company provides after-market service for medium-speed and high-speed diesel engines and reduction gears used in marine and power generation applications. The Company also distributes and services high-speed diesel engines and transmissions, pumps and compression products, and manufactures oilfield service equipment, including hydraulic fracturing equipment, for land-based pressure pumping and oilfield service markets.

Unless the context otherwise requires, all references herein to the Company include the Company and its subsidiaries.

The Company’s principal executive office is located at 55 Waugh Drive, Suite 1000, Houston, Texas 77007, and its telephone number is (713) 435-1000. The Company’s mailing address is P.O. Box  1745, Houston, Texas 77251-1745.

Documents and Information Available on Web Site

The Internet address of the Company’s web site is http://www.kirbycorp.com. The Company makes available free of charge through its web site, all of its filings with the Securities and Exchange Commission (“SEC”), including its annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports, as soon as reasonably practicable after they are electronically filed with or furnished to the SEC.

The following documents are available on the Company’s web site in the Investor Relations section under Corporate Governance:

• Audit Committee Charter

• Compensation Committee Charter

• Governance Committee Charter

• Business Ethics Guidelines

• Corporate Governance Guidelines

The Company is required to make prompt disclosure of any amendment to or waiver of any provision of its Business Ethics Guidelines that applies to any director or executive officer or to its chief executive officer, chief financial officer, chief accounting officer or controller or persons performing similar functions. The Company will make any such disclosure that may be necessary by posting the disclosure on its web site in the Investor Relations section under Corporate Governance.

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BUSINESS AND PROPERTY

The Company, through its subsidiaries, conducts operations in two business segments: marine transportation and diesel engine services.

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, and along all three United States coasts and in Alaska and Hawaii. The Company transports petrochemicals, black oil products, refined petroleum products, and agricultural chemicals by tank barge. The Company also owns and operates four offshore dry-bulk barges and tugboats engaged in the coastal transportation of dry-bulk cargoes. The segment is a provider of transportation services for its customers and, in almost all cases, does not assume ownership of the products that it transports. All of the Company’s vessels, except four, operate under the United States flag and are qualified for domestic trade under the Jones Act.

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 reduction gears, and manufactures oilfield service equipment, including hydraulic fracturing equipment. The Company primarily services the marine, power generation, oilfield service, and land-based oil and gas operator and producer markets.

The Company and its marine transportation and diesel engine services segments have approximately 4,225 employees, substantially all of whom are in the United States.

The following table sets forth by segment the revenues, operating profits and identifiable assets attributable to the principal activities of the Company for the years indicated (in thousands):

	2011			2010			2009
Revenues from unaffiliated customers:
Marine transportation	$	1,194,607		$	915,046		$	881,298
Diesel engine services		655,810			194,511			200,860
Consolidated revenues	$	1,850,417		$	1,109,557		$	1,082,158
Operating profits:
Marine transportation	$	262,193		$	192,758		$	208,086
Diesel engine services		68,105			20,553			21,005
General corporate expenses		(17,915	)		(13,189	)		(12,239	)
Impairment of goodwill		—			—			(1,901	)
Gain (loss) on disposition of assets		(40	)		(78	)		1,079
		312,343			200,044			216,030
Equity in earnings of affiliates		347			283			874
Other income (expense)		(41	)		273			(266	)
Interest expense		(17,902	)		(10,960	)		(11,080	)
Earnings before taxes on income	$	294,747		$	189,640		$	205,558
Identifiable assets:
Marine transportation	$	2,307,821		$	1,383,252		$	1,336,358
Diesel engine services		608,886			185,824			185,573
		2,916,707			1,569,076			1,521,931
Investment in affiliates		3,682			3,336			3,052
General corporate assets		40,022			222,525			110,980
Consolidated assets	$	2,960,411		$	1,794,937		$	1,635,963

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MARINE TRANSPORTATION

The marine transportation segment is primarily a provider of transportation services by tank barge for the inland and coastal markets. As of February 22, 2012, the equipment owned or operated by the marine transportation segment consisted of 819 inland tank barges, 236 inland towboats, 59 coastal tank barges, 65 coastal tugboats, four offshore dry-cargo barges, four offshore tugboats and one docking tugboat with the following specifications and capacities:

Class of equipment	Number in class		Average age (in years)		Barrel capacities
Inland tank barges (owned and chartered):
Regular double hull:
20,000 barrels and under		342		20.2		3,980,000
Over 20,000 barrels		399		14.4		11,080,000
Specialty double hull		78		35.8		1,124,000
Total inland tank barges		819		18.9		16,184,000
Inland towboats (owned and chartered):
Less than 800 horsepower		1		43.0
800 to 1300 horsepower		100		33.7
1400 to 1900 horsepower		83		30.6
2000 to 2400 horsepower		24		15.8
2500 to 3200 horsepower		15		37.1
3300 to 4800 horsepower		11		32.4
Greater than 5000 horsepower		2		39.0
Total inland towboats		236		31.1
Coastal tank barges (owned and chartered):
Double hull:
30,000 barrels and under		18		11.6		443,000
50,000 to 70,000 barrels		8		8.9		463,000
80,000 to 90,000 barrels		20		9.4		1,648,000
100,000 to 110,000 barrels		6		5.7		615,000
120,000 to 150,000 barrels		2		14.0		274,000
Over 150,000 barrels		2		4.5		351,000
Single hull:
30,000 barrels and under		3		33.7		54,000
Total coastal tank barges		59		10.8		3,848,000
Coastal tugboats (owned):
1000 to 1900 horsepower		8		27.9
2000 to 2900 horsepower		10		26.0
3000 to 3900 horsepower		19		28.1
4000 to 4900 horsepower		15		21.7
5000 to 6900 horsepower		8		35.3
Greater than 7000 horsepower		5		23.8
Total coastal tugboats		65		26.8
					Deadweight Tonnage
Offshore dry-cargo barges (owned)		4		31.9		70,000
Offshore tugboats and docking tugboat (owned)		5		34.7

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The 236 inland towboats, 65 coastal tugboats, four offshore tugboats and one docking tugboat provide the power source and the 819 inland tank barges, 59 coastal tank barges and four offshore dry-cargo barges provide the freight capacity for the marine transportation segment. When the power source and freight capacity are combined, the unit is called a tow. The Company’s inland tows generally consist of one towboat and from one to 25 tank barges, depending upon the horsepower of the towboat, the river or canal capacity and conditions, and customer requirements. The Company’s coastal and offshore tows primarily consist of one tugboat and one tank barge or dry-cargo barge.

Marine Transportation Industry Fundamentals

The United States inland waterway system, composed of a network of interconnected rivers and canals that serve the nation as water highways, is one of the world’s most efficient transportation systems. The nation’s inland waterways are vital to the United States distribution system, with over 1.1 billion short tons of cargo moved annually on United States shallow draft waterways. The inland waterway system extends approximately 26,000 miles, 12,000 miles of which are generally considered significant for domestic commerce, through 38 states, with 635 shallow draft ports. These navigable inland waterways link the United States heartland to the world.

The United States coastal system consist of ports along the Atlantic, Gulf and Pacific coasts, as well as ports in Alaska, Hawaii and on the Great Lakes. Like the inland waterways, the coastal trade is vital to the United States distribution system, particularly the distribution of refined petroleum products from refineries and storage facilities to a variety of destinations, including other refineries, distribution terminals, power plants and ships. In addition to distribution directly from refineries and storage facilities, coastal tank barges are used frequently to distribute products from pipelines. Many coastal markets receive refined products principally from coastal tank barges.

Based on cost and safety, barge transportation is often the most efficient and safest means of transporting bulk commodities when compared with railroads and trucks. The cargo capacity of a 90,000 barrel three barge inland tow is the equivalent of 150 railroad tank cars or 470 tractor-trailer tank trucks. A typical Company lower Mississippi River linehaul tow of 15 barges has the carrying capacity of approximately 260 railroad tank cars or approximately 825 tractor-trailer tank trucks. The 260 railroad tank cars would require a freight train approximately 2 3/4 miles long and the 825 tractor-trailer tank trucks would stretch approximately 35 miles, assuming a safety margin of 150 feet between the trucks. The Company’s inland tank barge fleet capacity of 16.2 million barrels equates to approximately 27,000 railroad tank cars or approximately 84,500 tractor-trailer tank trucks. Furthermore, barging is much more energy efficient. One ton of bulk product can be carried 616 miles by inland barge on one gallon of fuel, compared with 498 miles by railroad or 150 miles by truck. In the coastal trade, the carrying capacity of a 100,000 barrel tank barge is the equivalent of approximately 165 railroad tank cars or approximately 525 tractor-trailer tank trucks. The Company’s coastal tank barge fleet capacity of 3.8 million barrels equates to approximately 6,350 railroad tank cars or approximately 20,200 tractor-trailer tank trucks.

Tank barge transportation is safer than most modes of transportation in the United States. Marine transportation generally involves less urban exposure than railroad or truck transportation and operates on a system with few crossing junctures and in areas relatively remote from population centers. These factors generally reduce both the number and impact of waterway incidents.

Inland Tank Barge Industry

The Company operates within the United States inland tank barge industry, a diverse and independent mixture of large integrated transportation companies and small operators, as well as captive fleets owned by United States refining and petrochemical companies. The inland tank barge industry provides marine

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transportation of bulk liquid cargoes for customers and, in the case of captives, for their own account, along the Mississippi River and its tributaries and the Gulf Intracoastal Waterway. The most significant markets in this industry include the transportation of petrochemicals, black oil products, refined petroleum products and agricultural chemicals. The Company operates in each of these markets. The use of marine transportation by the petroleum and petrochemical industry is a major reason for the location of United States refineries and petrochemical facilities on navigable inland waterways. Texas and Louisiana currently account for approximately 80% of the United States production of petrochemicals. Much of the United States farm belt is likewise situated with access to the inland waterway system, relying on marine transportation of farm products, including agricultural chemicals. The Company’s principal distribution system encompasses the Gulf Intracoastal Waterway from Brownsville, Texas, to Port St. Joe, Florida, the Mississippi River System and the Houston Ship Channel. The Mississippi River System includes the Arkansas, Illinois, Missouri, Ohio, Red, Tennessee, Yazoo, Ouachita and Black Warrior Rivers and the Tennessee-Tombigbee Waterway.

The number of tank barges that operate on the inland waterways of the United States declined from an estimated 4,200 in 1982 to 2,900 in 1993, remained relatively constant at 2,900 until 2002, decreased to 2,750 from 2002 through 2006, increased to 3,050 by the end of 2008 and 3,150 by the end of 2009, and is estimated at 3,100 at the end of 2010 and 2011. The Company believes the decrease from 4,200 in 1982 to 2,750 in 2006 primarily resulted from: the increasing age of the domestic tank barge fleet, resulting in scrapping; rates inadequate to justify new construction; a reduction in tax incentives, which previously encouraged speculative construction of new equipment; stringent operating standards to adequately cope with safety and environmental risk; the elimination of government regulations and programs supporting the many new small refineries and a proliferation of oil traders which created a strong demand for tank barge services; an increase in the average capacity per barge; and an increase in environmental regulations that mandate expensive equipment modification, which some owners were unwilling or unable to undertake given capital constraints and the age of their fleets. The cost of tank barge hull work for required periodic United States Coast Guard (“USCG”) certifications, as well as general safety and environmental concerns, force operators to periodically reassess their ability to recover maintenance costs. The increase from 2,750 in 2006 to an estimated 3,100 by the end of 2010 and 2011 primarily resulted from increased barge construction and deferred retirements due to strong demand and resulting capacity shortages through the 2008 third quarter.

From 2003 through 2006, the Company believes that new inland tank barge construction approximated retirements. During 2007 and 2008, sustained favorable market conditions stimulated additional new capacity. During the first nine months of 2008 and prior to the deterioration of the marine transportation markets in the 2008 fourth quarter, the Company and many competitors signed tank barge construction contracts with shipyards for 2009 and 2010 deliveries. During 2010, the Company estimated that industry wide approximately 115 new tank barges were placed in service and an estimated 165 tank barges were retired. For 2011, the Company estimated that industry wide 160 tank barges were delivered and placed in service and an estimated 100 to 125 tank barges were retired. Due to the improved demand during 2011 for inland petrochemical and black oil barges and federal tax incentives on new equipment, the Company estimates that industry wide approximately 230 tank barges were ordered during 2011 for delivery throughout 2012 and many older tank barges will be retired, dependent on 2012 market conditions. The risk of an oversupply of tank barges may be mitigated by continued increased petrochemical and black oil volumes and the fact that the inland tank barge industry has a mature fleet, with approximately 900 tank barges over 30 years old and approximately 500 of those over 35 years old, which may lead to retirement of older tank barges.

The average age of the nation’s inland tank barge fleet is 19 years, with 32% of the fleet built in the last 10 years. Single hull barges comprise approximately 3% of the nation’s tank barge fleet, with an average age of 35 years. The Company does not operate any single hull inland tank barges. Single hull barges are being driven from the nation’s tank barge fleet by market forces, stringent environmental regulations and rising maintenance costs. Single hull tank barges are required by current federal law to be retrofitted with double hulls or phased out of domestic service by December 31, 2014. Market bias may also result in reduced lives for single hull tank barges industry wide.

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The Company’s inland marine transportation segment also owns a two-thirds interest in Osprey Line, L.L.C. (“Osprey”), transporter of project cargoes and cargo containers by barge on the United States inland waterway system.

Coastal Tank Barge Industry

The Company also operates in the United States coastal tank barge industry, primarily operating tank barges in the 185,000 barrel or less category. This market is composed of approximately 20 large integrated transportation companies and small operators. The coastal tank barge industry provides marine transportation of bulk liquid cargoes along the United States Atlantic, Gulf and Pacific coasts, in Alaska and Hawaii and to a lesser extent on the Great Lakes. Products transported are primarily refined petroleum products and black oil products from refineries and storage facilities to a variety of destinations, including other refineries, distribution terminals, power plants and ships.

The number of coastal tank barges that operate in the 185,000 barrel or less category is approximately 275, of which the Company operates 59 or approximately 22%. The average age of the nation’s coastal tank barge fleet is 11 years. Single hull barges comprise approximately 8% of the nation’s coastal tank barge fleet, with an average age of 36 years. The Company operates three single hull coastal tank barges.

Competition in the Tank Barge Industry

The tank barge industry remains very competitive. Competition in this business has historically been based primarily on price; however, some of the industry’s customers, through an increased emphasis on safety, the environment, quality and a trend toward a “single source” supply of services, and most are more frequently requiring that their supplier of tank barge services have the capability to handle a variety of tank barge requirements. These requirements include distribution capability throughout the inland waterway system and coastal markets, with high levels of flexibility, safety, environmental responsibility and financial responsibility, as well as adequate insurance and high quality of service consistent with the customer’s own operational standards.

In the inland markets, the Company’s direct competitors are primarily noncaptive inland tank barge operators. “Captive” fleets are owned by major oil and petrochemical companies which occasionally compete in the inland tank barge market, but primarily transport cargoes for their own account. The Company is the largest inland tank barge carrier, both in terms of number of barges and total fleet barrel capacity. The Company’s inland tank barge fleet has grown from 71 tank barges in 1988 to 819 tank barges as of February 22, 2012, or approximately 26% of the estimated total number of domestic inland tank barges.

In the coastal markets, the Company’s direct competitors are the operators of United States ocean-going tank barges and United States refined petroleum products tankers, including the captive fleets of major oil companies. The Company is the largest coastal tank barge carrier in the 185,000 barrel or less class.

While the Company competes primarily with other tank barge companies, it also competes with companies who operate refined product and petrochemical pipelines, railroad tank cars, tractor-trailer tank trucks and foreign flag project carriers. As noted above, the Company believes that both inland and coastal marine transportation of bulk liquid products enjoys a substantial cost advantage over railroad and truck transportation. The Company believes that refined product and petrochemical pipelines, although often a less expensive form of transportation than inland and coastal tank barges, are not as adaptable to diverse products and are generally limited to fixed point-to-point distribution of commodities in high volumes over extended periods of time.

Marine Transportation Acquisitions

On December 15, 2011, the Company completed the purchase of the coastal tank barge fleet of Seaboats, Inc. and affiliated companies (“Seaboats”) consisting of three 80,000 barrel coastal tank barge and tugboats for $42,745,000 in cash. The three coastal tank barge and tugboats currently operate along the United States East Coast and have an average age of five years.

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On July 1, 2011, the Company completed the acquisition of K-Sea Transportation Partners L.P. (“K-Sea”) an operator of tank barges and tugboats participating in the coastal transportation primarily of refined petroleum products in the United States. The total value of the transaction was $603,427,000, excluding transaction fees, consisting of $227,617,000 of cash paid to K-Sea common and preferred unit holders and the general partner, $262,791,000 of cash to retire K-Sea’s outstanding debt, and $113,019,000 through the issuance of 1,939,234 shares of Company common stock valued at $58.28 per share, the Company’s closing share price on July 1, 2011.

On the acquisition date, K-Sea’s fleet, comprised of 57 coastal tank barges with a capacity of 3.8 million barrels and 63 tugboats, operated along the East Coast, West Coast and Gulf Coast of the United States, as well as in Alaska and Hawaii. K-Sea’s tank barge fleet, 54 of which were double hulled and had an average age of approximately nine years, is one of the youngest fleets in the coastal trade. K-Sea’s customers include major oil companies and refiners, many of which are current Company customers for inland tank barge services. K-Sea has operating facilities in New York, Philadelphia, Seattle and Honolulu.

On February 24, 2011, the Company purchased 21 inland and offshore tank barges and 15 inland towboats and offshore tugboats from Enterprise Marine Services LLC (“Enterprise”) for $53,200,000 in cash. Enterprise provided transportation and delivery services for ship bunkers (engine fuel) to cruise ships, container ships and freighters primarily in the Miami, Port Everglades and Cape Canaveral, Florida area, the three largest cruise ship ports in the United States, as well as Tampa, Florida, Mobile, Alabama and Houston, Texas.

On February 9, 2011, the Company purchased from Kinder Morgan Petcoke, L.P. (“Kinder Morgan”) for $4,050,000 in cash a 51% interest in Kinder Morgan’s shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel. Kinder Morgan retained the remaining 49% interest and the Company will manage the operation. In addition, the Company purchased a towboat from Kinder Morgan for $1,250,000 in cash.

Products Transported

During 2011, the Company’s inland marine transportation operation moved over 50 million tons of liquid cargo on the United States inland waterway system. Products transported for its customers along the inland waterway system consisted of the following: petrochemicals, black oil products, refined petroleum products and agricultural chemicals.

Petrochemicals. Bulk liquid petrochemicals transported include such products as benzene, styrene, methanol, acrylonitrile, xylene and caustic soda, all consumed in the production of paper, fibers and plastics. Pressurized products, including butadiene, isobutane, propylene, butane and propane, all requiring pressurized conditions to remain in stable liquid form, are transported in pressure barges. The transportation of petrochemical products represented 59% of the segment’s 2011 revenues. Customers shipping these products are refining and petrochemical companies.

Black Oil Products. Black oil products transported include such products as asphalt, residual fuel oil, No. 6 fuel oil, coker feedstock, vacuum gas oil, carbon black feedstock, crude oil and ship bunkers (engine fuel). Such products represented 20% of the segment’s 2011 revenues. Black oil customers are refining companies, marketers and end users that require the transportation of black oil products between refineries and storage terminals. Ship bunkers customers are oil companies and oil traders in the bunkering business.

Refined Petroleum Products. Refined petroleum products transported include the various blends of finished gasoline, gasoline blendstocks, jet fuel, No. 2 oil, naphtha, heating oil and diesel fuel, and represented 16% of the segment’s 2011 revenues. The Company also classifies ethanol in the refined petroleum product category. Customers are oil and refining companies, marketers and ethanol producers.

Agricultural Chemicals. Agricultural chemicals transported represented 5% of the segment’s 2011 revenues. They include anhydrous ammonia and nitrogen-based liquid fertilizer, as well as industrial ammonia. Agricultural chemical customers consist mainly of domestic and foreign producers of such products.

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Demand Drivers in the Tank Barge Industry

Demand for tank barge transportation services is driven by the production volumes of the bulk liquid commodities transported by barge. Marine transportation demand for the segment’s four primary commodity groups, petrochemicals, black oil products, refined petroleum products and agricultural chemicals, is based on differing circumstances. While the demand drivers of each commodity are different, the Company has the flexibility in certain cases of re-allocating inland equipment and coastal equipment between the petrochemical and refined products markets as needed.

Bulk petrochemical volumes have historically tracked the general domestic economy and correlate to the United States Gross Domestic Product. However, during late 2010 and 2011, production volumes of United States petrochemical plants improved steadily for both domestic consumption and exports, despite the United States economy which remained sluggish, with consistently high unemployment levels and weak consumer confidence. Lower priced domestic natural gas, a basic feedstock for the United States petrochemical industry, provides the industry with a competitive advantage against foreign petrochemical producers and led to increased production levels. As a result of the higher United States petrochemical production levels, marine transportation volumes for basic petrochemicals for both domestic consumers and terminals for export destinations improved. Petrochemical products are used primarily in consumer non-durable and durable goods.

The demand for black oil products, including ship bunkers, varies by type of product transported. Demand for transportation of residual oil, a heavy by-product of refining operations, varies with refinery utilization and usage of feedstocks. During 2011, the black oil products market continued to improve primarily due to United States refinery utilization levels. Refinery maintenance issues and new demand for the transportation of crude oil from shale formations in South Texas, as well as increased movements of Canadian crude oil from the Midwest to the Gulf Coast also positively impacted demand. Asphalt shipments are generally seasonal, with higher volumes shipped during April through November, months when weather allows for efficient road construction. Carbon black feedstock shipments generally track the general economy and are used in the production of automobiles and related parts, and in housing applications.

Refined petroleum product volumes are driven by United States gasoline and diesel fuel consumption, principally vehicle usage, air travel and weather conditions. Volumes can also relate to gasoline inventory imbalances within the United States. Generally, gasoline and No. 2 oil are exported from the Gulf Coast where refining capacity exceeds demand. The Midwest is a net importer of such products. Ethanol, produced in the Midwest, is moved from the Midwest to Gulf Coast customers. In the coastal trade, tank barges are frequently used to transport refined petroleum products from a coastal refinery or terminals served by pipelines to the end markets. Many coastal areas have access to refined petroleum products only by using marine transportation as the last link in the distribution chain.

Demand for marine transportation of domestic and imported agricultural fertilizer is directly related to domestic nitrogen-based liquid fertilizer consumption, driven by the production of corn, cotton and wheat. During periods of high natural gas prices, the manufacturing of nitrogen-based liquid fertilizer in the United States is curtailed. During these periods, imported products, which normally involve longer barge trips, replace the domestic products to meet Midwest and south Texas demands. Such products are delivered to the numerous small terminals and distributors throughout the United States farm belt.

Marine Transportation Operations

The marine transportation segment operates a fleet of 819 inland tank barges and 236 inland towboats, as well as 59 coastal tank barges and 65 coastal tugboats. The segment also owns and operates four offshore barge and tug units transporting dry-bulk commodities in coastal trade.

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Inland Operations. The segment’s inland operations are conducted through a wholly owned subsidiary, Kirby Inland Marine, LP (“Kirby Inland Marine”). Kirby Inland Marine’s operations consist of the Canal, Linehaul and River fleets, as well as barge fleeting services.

The Canal fleet transports petrochemical feedstocks, processed chemicals, pressurized products, black oil products and refined petroleum products along the Gulf Intracoastal Waterway, the Mississippi River below Baton Rouge, Louisiana, and the Houston Ship Channel. Petrochemical feedstocks and certain pressurized products are transported from one plant to another plant for further processing. Processed chemicals and certain pressurized products are moved to waterfront terminals and chemical plants. Certain black oil products are transported to waterfront terminals and products such as No. 6 fuel oil are transported directly to the end users. Refined petroleum products are transported to waterfront terminals along the Gulf Intracoastal Waterway for distribution.

The Linehaul fleet transports petrochemical feedstocks, chemicals, agricultural chemicals and lube oils along the Gulf Intracoastal Waterway, Mississippi River and the Illinois and Ohio Rivers. Loaded tank barges are staged in the Baton Rouge area from Gulf Coast refineries and petrochemical plants, and are transported from Baton Rouge to waterfront terminals and plants on the Mississippi, Illinois and Ohio Rivers, and along the Gulf Intracoastal Waterway, on regularly scheduled linehaul tows. Barges are dropped off and picked up going up and down river.

The River fleet transports petrochemical feedstocks, chemicals, refined petroleum products, agricultural chemicals and black oil products along the Mississippi River System above Baton Rouge. The River fleet operates unit tows, where a towboat and generally a dedicated group of barges operate on consecutive voyages between loading and discharge points. Petrochemical feedstocks and processed chemicals are transported to waterfront petrochemical and chemical plants, while black oil products, refined petroleum products and agricultural chemicals are transported to waterfront terminals.

The inland transportation of petrochemical feedstocks, chemicals and pressurized products is generally consistent throughout the year. Transportation of refined petroleum products, certain black oil products and agricultural chemicals is generally more seasonal. Movements of black oil products, such as asphalt, generally increase in the spring through fall months. Movements of refined petroleum products, such as gasoline blends, generally increase during the summer driving season, while heating oil movements generally increase during the winter months. Movements of agricultural chemicals generally increase during the spring and fall planting seasons.

The marine transportation inland operation moves and handles a broad range of sophisticated cargoes. To meet the specific requirements of the cargoes transported, the inland tank barges may be equipped with self-contained heating systems, high-capacity pumps, pressurized tanks, refrigeration units, stainless steel tanks, aluminum tanks or specialty coated tanks. Of the 819 inland tank barges currently operated, 618 are petrochemical and refined products barges, 123 are black oil barges, 63 are pressure barges, 10 are refrigerated anhydrous ammonia barges and 5 are specialty barges. Of the 819 inland tank barges, 776 are owned by the Company and 43 are leased.

The fleet of 236 inland towboats ranges from 600 to 6200 horsepower. Of the 236 inland towboats, 179 are owned by the Company and 57 are chartered. Towboats in the 600 to 1900 horsepower classes provide power for barges used by the Canal and Linehaul fleets on the Gulf Intracoastal Waterway and the Houston Ship Channel. Towboats in the 1400 to 6000 horsepower classes provide power for both the River and Linehaul fleets on the Gulf Intracoastal Waterway and the Mississippi River System. Towboats above 3600 horsepower are typically used on the Mississippi River System to move River fleet unit tows and provide Linehaul fleet towing. Based on the capabilities of the individual towboats used in the Mississippi River System, the tows range in size from 10,000 to 30,000 tons.

Marine transportation services for inland movements are conducted under long-term contracts, ranging from one to five years, some of which have renewal options, with customers with whom the Company has traditionally had long-standing relationships, as well as under spot contracts. During 2011 and 2010, approximately 75% of inland marine transportation revenues were from term contracts and 25% from spot contracts.

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All of the Company’s inland tank barges used in the transportation of bulk liquid products are of double hull construction and, where applicable, are capable of controlling vapor emissions during loading and discharging operations in compliance with occupational health and safety regulations and air quality regulations.

The Company’s inland marine transportation sector is one of the few inland tank barge operators with the ability to offer to its customers’ distribution capabilities throughout the Mississippi River System and the Gulf Intracoastal Waterway. Such distribution capabilities offer economies of scale resulting from the ability to match tank barges, towboats, products and destinations more efficiently.

Through the Company’s proprietary vessel management computer system, the fleet of barges and towboats is dispatched from a centralized dispatch at the corporate office. The towboats are equipped with satellite positioning and communication systems that automatically transmit the location of the towboat to the Company’s customer service department located in its corporate office. Electronic orders are communicated to the vessel personnel, with reports of towing activities communicated electronically back to the customer service department. The electronic interface between the customer service department and the vessel personnel enables more effective matching of customer needs to barge capabilities, thereby maximizing utilization of the tank barge and towboat fleet. The Company’s customers are able to access information concerning the movement of their cargoes, including barge locations, through the Company’s web site.

Kirby Inland Marine operates the largest commercial tank barge fleeting service (temporary barge storage facilities) in numerous ports, including Houston, Corpus Christi and Freeport, Texas, Baton Rouge and New Orleans, Louisiana and other locations on the Mississippi River. Included in the fleeting service is a 51% interest and management control of a shifting operation and fleeting service for dry cargo barges and tank barges on the Houston Ship Channel. Kirby Inland Marine provides service for its own barges, as well as outside customers, transferring barges within the areas noted, as well as fleeting barges.

Kirby Logistics Management (“KLM”) is a division of Kirby Inland Marine providing shore-based tankerman and support services to the Company and third parties. Services provided by KLM include barge tankermen, marine terminal, refinery and chemical plant dock operators, and terminal management services. KLM’s services to the Company and third parties cover the Gulf Coast, mid-Mississippi Valley, and the Ohio River Valley. During 2011, KLM’s approximately 150 shore tankermen/operators completed approximately 21,000 tank barge cargo transfers and provided in-plant services at 16 third party facilities.

The Company owns a two-thirds interest in Osprey, which transports project cargoes and cargo containers by barge on the United States inland waterway system.

Coastal Operations. The segment’s coastal operations are conducted through wholly owned subsidiaries, K-Sea Transportation Partners LLC, acquired on July 1, 2011, and Kirby Ocean Transport Company (“Kirby Ocean Transport”).

K-Sea provides marine transportation of primarily refined petroleum products and black oil products in each coastal region of the United States. The coastal operations consist of the Atlantic, New York, Pacific and Hawaii Divisions.

The Atlantic Division primarily operates along the eastern seaboard of the United States and along the Gulf Coast. The Atlantic Division vessels call on coastal states from Maine to Texas, servicing refineries, storage terminals and power plants. The Atlantic Division also operates equipment, to a lesser extent, on the Great Lakes, in the Caribbean, and in Venezuela and the Eastern Canadian provinces. The tank barges and tugboats operating in the Atlantic Division are among K-Sea’s largest, with tank barges ranging in the 80,000 to 165,000 barrel capacity range and coastal tugboats in the 3500 to 8000 horsepower range, transporting primarily refined petroleum products and black oil products.

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The New York Division primarily operates in the New York Harbor, close to container terminals, cruise piers, refineries and petroleum storage facilities. The New York Division also performs coastal voyages between Maine and Norfork, Virginia and manages operations in Philadelphia. The New York Division’s fleet consists of tank barges in the 10,000 to 89,000 barrel capacity range and tugboats in the 1800 to 3400 horsepower range, transporting refined petroleum products for local and regional customers, black oil products to power generation customers and the delivery of bunker fuel to ships.

The Pacific Division primarily operates along the Pacific coast of the United States, servicing refineries and storage terminals from Southern California to Washington State, throughout Alaska, including Dutch Harbor, Cook Inlet and the Alaska River Systems, and from California to Hawaii. The Pacific Division’s fleet consists of tank barges in the 13,000 to 185,000 barrel capacity range and tugboats in the 1000 to 11800 horsepower range, transporting primarily refined petroleum products.

The Hawaii Division services local petroleum retailers and oil companies distributing refined petroleum products and black oil products between the Hawaiian islands and provides other services to the local maritime community. The Hawaii Division’s fleet consists of tank barges in the 52,000 to 86,000 barrel capacity range and tugboats in the 1200 to 7200 horsepower range, transporting refined petroleum products for local and regional customers, black oil products to power generation customers, and the delivery of bunker fuel to ships. The Hawaii Division also provides service docking, standby tug assistance and line handling to vessels using the Single Point Mooring installation at Barbers Point, Oahu, a facility for large tankers to safely load and discharge their cargos through an offshore buoy and submerged pipeline without entering the port.

The coastal transportation of refined petroleum products and black oil products are impacted by seasonality, partially dependent on the area of operations. Operations along the West Coast, Alaska and the Great Lakes historically have been subject to more seasonal variations in demand than the operations along the East Coast and Gulf Coast regions. Seasonality generally does not impact the Hawaiian market. Movements of refined petroleum products such as various blends of gasoline are strongest during the summer driving season while heating oil generally increases during the winter months.

The coastal fleet consists of 59 tank barges, 56 of which are double hull and three of which are single hull, with 3.8 million barrels of capacity, primarily transporting refined petroleum products and black oil products. Of the 59 coastal tank barges currently operating, 44 are refined products and petrochemical barges and 15 are black oil barges, and 46 are owned by the Company and 13 are leased. The Company operates 65 Company-owned coastal tugboats ranging from 1000 to 11800 horsepower. Tugboats in the 1800 to 3400 horsepower classes provide power for barges used in the New York Division. Tugboats in the 1000 to 11800 horsepower classes provide power for barges used in the Atlantic, Pacific and Hawaii Divisions.

Coastal marine transportation services are conducted under long-term contracts, primarily one year or longer, some of which have renewal options for customers with which the Company has traditionally had long-standing relationships, as well as under spot contracts. During the 2011 second half, approximately 60% of the coastal marine transportation revenues were under term contracts and 40% were spot contract revenues.

Kirby Ocean Transport owns and operates a fleet of four offshore dry-bulk barges, four offshore tugboats and one docking tugboat. Kirby Ocean Transport operates primarily under term contracts of affreightment, including a contract that expires in 2020 with Progress Energy Florida (“PEF”) to transport coal across the Gulf of Mexico to PEF’s power generation facility at Crystal River, Florida.

Kirby Ocean Transport also has a contract with Holcim (US) Inc. (“Holcim”) to transport Holcim’s limestone requirements from a facility adjacent to the PEF facility at Crystal River to Holcim’s plant in Theodore, Alabama. The Holcim contract, which expires in March 2012, provides cargo for a portion of the return voyage for the vessels that carry coal to PEF’s Crystal River facility. Kirby Ocean Transport is also engaged in the transportation of coal, fertilizer and other bulk cargoes on a short-term basis between domestic ports and occasionally the transportation of grain from domestic ports to ports primarily in the Caribbean Basin.

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Contracts and Customers

Marine transportation inland and coastal services are conducted under term contracts, ranging from one to five years, some of which have renewal options, for customers with whom the Company has traditionally had long-standing relationships, as well as under spot contracts. The majority of the marine transportation contracts with its customers are for terms of one year. Most have been customers of the Company’s marine transportation segment for several years and management anticipates continued relationships; however, there is no assurance that any individual contract will be renewed.

A term contract is an agreement with a specific customer to transport cargo from a designated origin to a designated destination at a set rate (affreightment) or at a daily rate (time charter). The rate may or may not escalate during the term of the contract; however, the base rate generally remains constant and contracts often include escalation provisions to recover changes in specific costs such as fuel. Time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented approximately 55% of the marine transportation’s inland revenues under term contracts during 2011, 52% of revenue under term contracts during 2010 and 56% of the revenue under term contracts during 2009. A spot contract is an agreement with a customer to move cargo from a specific origin to a designated destination for a rate negotiated at the time the cargo movement takes place. Spot contract rates are at the current “market” rate and are subject to market volatility. The Company typically maintains a higher mix of term contracts to spot contracts to provide the Company with a predictable revenue stream while maintaining spot market exposure to take advantage of new business opportunities and existing customers’ peak demands. During 2010 and 2011, approximately 75% of marine transportation’s inland revenues were from term contracts and 25% from spot contracts. During the 2011 second half, approximately 60% of the marine transportation’s liquid coastal revenues were under term contracts and 40% from spot contracts. Coastal time charters represented approximately 90% of the marine transportation coastal revenues under term contracts during the 2011 second half.

No single customer of the marine transportation segment accounted for more than 10% of the Company’s revenues in 2011. The Dow Chemical Company (“Dow”), with which the Company has a contract through 2016, accounted for 12% of the Company’s revenues in 2010 and 11% in 2009. SeaRiver Maritime, Inc. (“SeaRiver”), the United States transportation affiliate of Exxon Mobil Corporation, with which the Company has a contract through 2013, accounted for 11% of the Company’s revenues in 2010 and 10% in 2009.

Employees

The Company’s marine transportation segment has approximately 2,900 employees, of which approximately 2,125 are vessel crew members. None of the segment’s inland operations are subject to collective bargaining agreements. The segment’s coastal operation is composed of employees subject to collective bargaining agreements in certain geographic areas. Approximately 300 of K-Sea’s seagoing personnel were employed under one contract with a division of the International Longshoreman’s Association (“ILA”) that expired on June 30, 2011. An election was held as a result of a separate union petitioning the National Labor Relations Board (“NLRB”) for a decertification of the ILA representation and the establishment of an alternative union, the Richmond Terrace Bargaining Unit. On February 10, 2012, the eligible employees voted to certify the Richmond Terrace Bargaining Unit as representative of the employees formerly represented by the ILA. As of February 21, 2012, the union election results are pending certification by the NLRB.

Properties

The principal office of Kirby Inland Marine, Kirby Ocean Transport and Osprey is located in Houston, Texas, in the Company’s facilities under a lease that expires in December 2015. Kirby Inland Marine’s operating locations are on the Mississippi River at Baton Rouge and New Orleans, Louisiana, and Greenville, Mississippi, two locations in Houston, Texas, on and near the Houston Ship Channel, one in Miami, Florida, and one in Corpus Christi, Texas. The New Orleans and Houston facilities are owned, and the Baton Rouge, Greenville, Miami and Corpus Christi facilities are leased. KLM’s principal office is located in a facility owned by Kirby Inland Marine in Houston, Texas, near the Houston Ship Channel.

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The principal office of K-Sea is located in East Brunswick, New Jersey under a lease that expires in December 2013. K-Sea’s operating facilities are located in Staten Island, New York, Seattle, Washington, Philadelphia, Pennsylvania and Honolulu, Hawaii. All operating facilities are leased, including pier and wharf facilities, and office and warehouse space.

Governmental Regulations

General. The Company’s marine transportation operations are subject to regulation by the USCG, federal laws, state laws and certain international conventions.

Most of the Company’s tank barges are inspected by the USCG and carry certificates of inspection. The Company’s inland and coastal towing vessels and coastal dry-bulk barges are not currently subject to USCG inspection requirements; however, regulations are currently under development that would subject inland and coastal towing vessels to USCG inspection requirements. Most of the Company’s coastal tugboats and coastal tank and dry-bulk barges are built to American Bureau of Shipping (“ABS”) classification standards and are inspected periodically by ABS to maintain the vessels in class. The crews employed by the Company aboard vessels, including captains, pilots, engineers, tankermen and ordinary seamen, are licensed by the USCG.

The Company is required by various governmental agencies to obtain licenses, certificates and permits for its vessels depending upon such factors as the cargo transported, the waters in which the vessels operate and other factors. The Company is of the opinion that the Company’s vessels have obtained and can maintain all required licenses, certificates and permits required by such governmental agencies for the foreseeable future.

The Company believes that additional security and environmental related regulations may be imposed on the marine industry in the form of contingency planning requirements. Generally, the Company endorses the anticipated additional regulations and believes it is currently operating to standards at least equal to anticipated additional regulations.

Jones Act. The Jones Act is a federal cabotage law that restricts domestic marine transportation in the United States to vessels built and registered in the United States, manned by United States citizens, and owned and operated by United States citizens. For a corporation to qualify as United States citizens for the purpose of domestic trade it is to be 75% owned and controlled by United States citizens. The Company monitors citizenship and meets the requirements of the Jones Act for its owned vessels.

Compliance with United States ownership requirements of the Jones Act is important to the operations of the Company, and the loss of Jones Act status could have a material negative effect on the Company. The Company monitors the citizenship of its employees and stockholders.

User Taxes. Federal legislation requires that inland marine transportation companies pay a user tax based on propulsion fuel used by vessels engaged in trade along the inland waterways that are maintained by the United States Army Corps of Engineers. Such user taxes are designed to help defray the costs associated with replacing major components of the inland waterway system, such as locks and dams. A significant portion of the inland waterways on which the Company’s vessels operate is maintained by the Army Corps of Engineers.

The Company presently pays a federal fuel tax of 20.1 cents per gallon consisting of a .1 cent per gallon leaking underground storage tank tax and a 20 cents per gallon waterway user tax.

Security Requirements. The Maritime Transportation Security Act of 2002 requires, among other things, submission to and approval by the USCG of vessel and waterfront facility security plans (“VSP” and “FSP”, respectively). The Company’s VSP and FSP have been approved and the Company is operating in compliance with the plans for all of its vessels and facilities that are subject to the requirements.

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Environmental Regulations

The Company’s operations are affected by various regulations and legislation enacted for protection of the environment by the United States government, as well as many coastal and inland waterway states.

Water Pollution Regulations. The Federal Water Pollution Control Act of 1972, as amended by the Clean Water Act of 1977, the Comprehensive Environmental Response, Compensation and Liability Act of 1981 (“CERCLA”) and the Oil Pollution Act of 1990 (“OPA”) impose strict prohibitions against the discharge of oil and its derivatives or hazardous substances into the navigable waters of the United States. These acts impose civil and criminal penalties for any prohibited discharges and impose substantial strict liability for cleanup of these discharges and any associated damages. Certain states also have water pollution laws that prohibit discharges into waters that traverse the state or adjoin the state, and impose civil and criminal penalties and liabilities similar in nature to those imposed under federal laws.

The OPA and various state laws of similar intent substantially increased over historic levels the statutory liability of owners and operators of vessels for oil spills, both in terms of limit of liability and scope of damages.

One of the most important requirements under the OPA is that all newly constructed tank barges engaged in the transportation of oil and petroleum in the United States be double hulled, and all existing single hull tank barges be retrofitted with double hulls or phased out of domestic service by December 31, 2014.

The Company manages its exposure to losses from potential discharges of pollutants through the use of well maintained and equipped vessels, through safety, training and environmental programs, and through the Company’s insurance program. In addition, the Company’s inland fleet consists entirely of double hull barges and with only three single hull barges in the coastal fleet. There can be no assurance, however, that any new regulations or requirements or any discharge of pollutants by the Company will not have an adverse effect on the Company.

Financial Responsibility Requirement. Commencing with the Federal Water Pollution Control Act of 1972, as amended, vessels over 300 gross tons operating in the Exclusive Economic Zone of the United States have been required to maintain evidence of financial ability to satisfy statutory liabilities for oil and hazardous substance water pollution. This evidence is in the form of a Certificate of Financial Responsibility (“COFR”) issued by the USCG. The majority of the Company’s tank barges are subject to this COFR requirement, and the Company has fully complied with this requirement since its inception. The Company does not foresee any current or future difficulty in maintaining the COFR certificates under current rules.

Clean Air Regulations. The Federal Clean Air Act of 1979 requires states to draft State Implementation Plans (“SIPs”) designed to reduce atmospheric pollution to levels mandated by this act. Several SIPs provide for the regulation of barge loading and discharging emissions. The implementation of these regulations requires a reduction of hydrocarbon emissions released into the atmosphere during the loading of most petroleum products and the degassing and cleaning of barges for maintenance or change of cargo. These regulations require operators who operate in these states to install vapor control equipment on their barges. The Company expects that future emission regulations will be developed and will apply this same technology to many chemicals that are handled by barge. Most of the Company’s barges engaged in the transportation of petrochemicals, chemicals and refined products are already equipped with vapor control systems. Although a risk exists that new regulations could require significant capital expenditures by the Company and otherwise increase the Company’s costs, the Company believes that, based upon the regulations that have been proposed thus far, no material capital expenditures beyond those currently contemplated by the Company and no material increase in costs are likely to be required.

Contingency Plan Requirement. The OPA and several state statutes of similar intent require the majority of the vessels and terminals operated by the Company to maintain approved oil spill contingency plans as a condition of operation. The Company has approved plans that comply with these requirements. The OPA also

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requires development of regulations for hazardous substance spill contingency plans. The USCG has not yet promulgated these regulations; however, the Company anticipates that they will not be more difficult to comply with than the oil spill plans.

Occupational Health Regulations. The Company’s inspected vessel operations are primarily regulated by the USCG for occupational health standards. Uninspected vessel operations and the Company’s shore personnel are subject to the United States Occupational Safety and Health Administration regulations. The Company believes that it is in compliance with the provisions of the regulations that have been adopted and does not believe that the adoption of any further regulations will impose additional material requirements on the Company. There can be no assurance, however, that claims will not be made against the Company for work related illness or injury, or that the further adoption of health regulations will not adversely affect the Company.

Insurance. The Company’s marine transportation operations are subject to the hazards associated with operating vessels carrying large volumes of bulk cargo in a marine environment. These hazards include the risk of loss of or damage to the Company’s vessels, damage to third parties as a result of collision, fire or explosion, loss or contamination of cargo, personal injury of employees and third parties, and pollution and other environmental damages. The Company maintains insurance coverage against these hazards. Risk of loss of or damage to the Company’s vessels is insured through hull insurance currently insuring approximately $2 billion in hull values. Liabilities such as collision, cargo, environmental, personal injury and general liability are insured up to $1 billion per occurrence.

Environmental Protection. The Company has a number of programs that were implemented to further its commitment to environmental responsibility in its operations. In addition to internal environmental audits, one such program is environmental audits of barge cleaning vendors principally directed at management of cargo residues and barge cleaning wastes. Others are the participation by the Company in the American Waterways Operators Responsible Carrier program and the American Chemistry Council Responsible Care program, both of which are oriented towards continuously reducing the barge industry’s and chemical and petroleum industries’ impact on the environment, including the distribution services area.

Safety. The Company manages its exposure to the hazards associated with its business through safety, training and preventive maintenance efforts. The Company places considerable emphasis on safety through a program oriented toward extensive monitoring of safety performance for the purpose of identifying trends and initiating corrective action, and for the purpose of rewarding personnel achieving superior safety performance. The Company believes that its safety performance consistently places it among the industry leaders as evidenced by what it believes are lower injury frequency and pollution incident levels than many of its competitors.

Training. The Company believes that among the major elements of a successful and productive work force are effective training programs. The Company also believes that training in the proper performance of a job enhances both the safety and quality of the service provided. New technology, regulatory compliance, personnel safety, quality and environmental concerns create additional demands for training. The Company has developed and instituted effective training programs.

Centralized training is provided through the Operations Personnel and Training Department, which is charged with developing, conducting and maintaining training programs for the benefit of all of the Company’s operating entities. It is also responsible for ensuring that training programs are both consistent and effective. The Company’s training facility includes state-of-the-art equipment and instruction aids, including a full bridge wheelhouse simulator, a working towboat, two tank barges and a tank barge simulator for tankermen training. During 2011, approximately 2,500 certificates were issued for the completion of courses at the training facility.

Quality. Kirby Inland Marine and Kirby Ocean Transport has made a substantial commitment to the implementation, maintenance and improvement of Quality Assurance Systems in compliance with the International Quality Standard, ISO 9001 and are currently certified. K-Sea is certified under ABS HSQE. These

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Quality Assurance Systems and HSQE certification have enabled both shore and vessel personnel to effectively manage the changes which occur in the working environment. In addition, such Quality Assurance Systems and ABS HSQE certification have enhanced the Company’s safety and environmental performance.

DIESEL ENGINE SERVICES

The Company, through wholly owned subsidiary Kirby Engines Systems, Inc. (“Kirby Engine Systems”), is engaged in the overhaul and repair of medium-speed and high-speed diesel engines and reduction gears, and related parts sales used in marine and power generation applications, and distributes and services high-speed diesel engines and transmissions, pumps and compression products, and manufactures oilfield service equipment, including hydraulic fracturing equipment, used in land-based pressure pumping, oilfield service, power generation and transportation applications. During early 2011, the distributorship with Electro-Motive Diesel, Inc. (“EMD”), providing replacement parts and service to the shortline, industrial, Class II and certain transit railroads, was terminated.

For the marine market, the Company sells Original Equipment Manufacturers (OEM) replacement parts, provides service mechanics to overhaul and repair engines and reduction gears, and maintains facilities to rebuild component parts or entire engines and reduction gears. For the power generation market, the Company provides service and parts capabilities and safety-related products to power generation operators and to the nuclear industry, and manufactures engine generator and pump sets for the power generation operators and municipalities.

In April 2011, the Company expanded its diesel engine services operation with the purchase of United Holdings LLC (“United”), a manufacturer, diesel engine and transmission distributor and service provider for the land-based oil and gas services market, oil and gas operators and producers, compression companies, power generation companies, on-highway transportation companies and agricultural markets. United’s principal businesses are the distribution and service of diesel engines, pumps and transmissions, the manufacture and remanufacture of oilfield service equipment, including hydraulic fracturing equipment, and the manufacture of compression equipment for natural gas transmission and for natural gas fired power generation plants.

No single customer of the diesel engine services segment accounted for more than 10% of the Company’s revenues in 2011, 2010 or 2009. The diesel engine services segment also provides service to the Company’s marine transportation segment, which accounted for approximately 3% of the diesel engine services segment’s 2011 revenues and 5% of 2010 and 2009 revenues. Such revenues are eliminated in consolidation and not included in the table below.

The following table sets forth the revenues for the diesel engine services segment for the three years ended December 31, 2011 (dollars in thousands):

	2011					2010					2009
	Amounts		%			Amounts		%			Amounts		%
Manufacturing	$	238,685		37	%	$	—		—	%	$	—		—	%
Overhauls and service		277,924		42			123,009		63			122,847		61
Direct parts sales		139,201		21			71,502		37			78,013		39
	$	655,810		100	%	$	194,511		100	%	$	200,860		100	%

Diesel Engine Services Acquisition

On April 15, 2011, the Company purchased United, a distributor and service provider of engine and transmission related products for the oil and gas services, power generation and on-highway transportation industries, and manufacturer of oilfield service equipment. The purchase price was $271,192,000 in cash, plus a

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three-year earnout provision for up to an additional $50,000,000 payable in 2014, dependent on achieving certain financial targets. United, headquartered in Oklahoma City, Oklahoma with 21 locations across seven states, distributes and services equipment and parts for Allison Transmission (“Allison”), MTU Detroit Diesel (“MTU”), Daimler Trucks NA (“Daimler”), and other diesel and natural gas engines. United also manufactures oilfield service equipment, including hydraulic fracturing equipment. United’s principal customers are oilfield service companies, oil and gas operators and producers, compression companies and on-highway transportation companies.

Marine Operations

The Company is engaged in the overhaul and repair of medium-speed and high-speed diesel engines and reduction gears, line boring, block welding services and related parts sales for customers in the marine industry, which represented 21% of the segment’s 2011 revenues. Medium-speed diesel engines have an engine speed of 400 to 1000 revolutions per minute (“RPM”) with a horsepower range of 800 to 32000. High-speed diesel engines have an engine speed of over 1,000 RPM and a horsepower range of 50 to 8375. The Company services medium-speed and high-speed diesel engines utilized in the inland and offshore barge industries. It also services marine equipment and offshore drilling equipment used in the offshore petroleum exploration and oil service industry, marine equipment used in the offshore commercial fishing industry and vessels owned by the United States government.

The Company has marine operations throughout the United States providing in-house and in-field repair capabilities and related parts sales. The Company’s emphasis is on service to its customers, and it sends its crews from any of its locations to service customers’ equipment anywhere in the world. The medium-speed operations are located in Houma, Louisiana, Chesapeake, Virginia, Paducah, Kentucky, Seattle, Washington and Tampa, Florida. The operations based in Chesapeake, Virginia and Tampa, Florida are authorized distributors for 17 eastern states and the Caribbean for EMD. The marine operations based in Houma, Louisiana, Paducah, Kentucky and Seattle, Washington are nonexclusive authorized service centers for EMD providing service and related parts sales. All of the marine locations are authorized distributors for Falk Corporation reduction gears and Oil States Industries, Inc. clutches. The Chesapeake, Virginia operation concentrates on East Coast inland and offshore dry-bulk, tank barge and harbor docking operators, the USCG and United States Navy (“Navy”). The Houma, Louisiana operation concentrates on the inland and offshore barge and oil services industries. The Tampa, Florida operation concentrates on Gulf of Mexico offshore dry-bulk, tank barge and harbor docking operators. The Paducah, Kentucky operation concentrates on the inland river towboat and barge operators and the Great Lakes carriers. The Seattle, Washington operation concentrates on the offshore commercial fishing industry, tugboat and barge industry, the USCG and Navy, and other customers in Alaska, Hawaii and the Pacific Rim.

The high-speed operations are located in Houma, Baton Rouge, Belle Chasse and New Iberia, Louisiana, Paducah, Kentucky, Mobile, Alabama and Houston, Texas. The Company serves as a factory-authorized marine dealer for Caterpillar diesel engines in Alabama, Kentucky and Louisiana. The Company also operates factory-authorized full service marine dealerships for Cummins, Detroit Diesel and John Deere diesel engines, as well as Allison transmissions and Twin Disk marine gears. High-speed diesel engines provide the main propulsion for approximately 75% of the United States flag commercial vessels and other marine applications, including engines for power generators and barge pumps.

Marine Customers

The Company’s major marine customers include inland and offshore barge operators, oil service companies, offshore fishing companies, other marine transportation entities, and the USCG and Navy.

Since the marine business is linked to the relative health of the diesel power tugboat and towboat industry, the offshore supply boat industry, the oil and gas drilling industry, the military and the offshore commercial fishing industry, there is no assurance that its present gross revenues can be maintained in the future. The results of the diesel engine services industry are largely tied to the industries it serves and, therefore, are influenced by the cycles of such industries.

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Marine Competitive Conditions

The Company’s primary competitors are independent diesel engine services companies and other factory-authorized distributors, authorized service centers and authorized marine dealers. Certain operators of diesel powered marine equipment also elect to maintain in-house service capabilities. While price is a major determinant in the competitive process, reputation, consistent quality, expeditious service, experienced personnel, access to parts inventories and market presence are also significant factors. A substantial portion of the Company’s business is obtained by competitive bids. However, the Company has entered into preferential service agreements with certain large operators of diesel powered marine equipment, providing such operators with one source of support and service for all of their requirements at pre-negotiated prices.

Many of the parts sold by the Company are generally available from other service providers, but the Company is one of a limited number of authorized resellers of EMD, Caterpillar, Cummins, MTU and John Deere parts. The Company is also the only marine distributor for Falk reduction gears throughout the United States.

Power Generation Operations

The Company is engaged in the overhaul and repair of diesel engines and reduction gears, line boring, block welding service and related parts sales for power generation customers, which represented 9% of the segment’s 2011 revenues. The Company is also engaged in the sale and distribution of parts for diesel engines and governors to the nuclear industry. The Company services users of diesel engines that provide standby, peak and base load power generation, as well as users of industrial reduction gears, such as the cement, paper and mining industries.

The Company provides in-house and in-field repair capabilities and safety-related products to power generation operators from its Rocky Mount, North Carolina, Paducah, Kentucky and Seattle, Washington locations. The operation based in Rocky Mount, North Carolina is an EMD authorized distributor for 17 eastern states and the Caribbean for power generation applications, and provides in-house and in-field service. The Rocky Mount operation is also the exclusive worldwide distributor of EMD products to the nuclear industry, the exclusive worldwide distributor for Woodward Governor products to the nuclear industry, the exclusive worldwide distributor of Cooper Energy Services, Inc. products to the nuclear industry, and owns the assets and technology necessary to support the Nordberg medium-speed diesel engines used in nuclear applications. In addition, the Rocky Mount operation is a non-exclusive distributor for Honeywell International Incorporated industrial measurement and control products to the nuclear industry, an exclusive distributor for Norlake Manufacturing Company transformer products to the nuclear industry and a non-exclusive distributor of analog Weschler Instruments metering products and an exclusive distributor of digital Weschler metering products to the nuclear industry. The Paducah, Kentucky operation provides in-house and in-field repair services for Falk industrial reduction gears in the Midwest. The Seattle, Washington operation provides in-house and in-field repair services for Alco engines located on the West Coast and the Pacific Rim.

Power Generation Customers

The Company’s power generation customers are primarily domestic utilities and the worldwide nuclear power industry.

Power Generation Competitive Conditions

The Company’s primary competitors are other independent diesel service companies and manufacturers. While price is a major determinant in the competitive process, reputation, consistent quality, expeditious service, experienced personnel, access to parts inventories and market presence are also significant factors. A substantial portion of the Company’s business is obtained by competitive bids. However, the Company has entered into preferential service agreements with certain large operators of diesel powered generation equipment, providing such operators with one source of support and service for all of their requirements at pre-negotiated prices.

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As noted under Power Generation Operations above, the Company is the exclusive worldwide distributor of EMD, Cooper, Woodward, Nordberg and Norlake parts for the nuclear industry, and non-exclusive distributor for Honeywell and Weschler parts for the nuclear industry. Specific regulations relating to equipment used in nuclear power generation require extensive testing and certification of replacement parts. Non-genuine parts and parts not properly tested and certified cannot be used in nuclear applications.

Railroad Operations

During early 2011, the distributorship with EMD providing replacement parts and service to the shortline, industrial, Class II and certain transit railroads throughout the continental United States was terminated. Revenues from the terminated business represented 1% of the segment’s 2011 revenues.

Land-Based Operations

The Company is engaged in the distribution and service of diesel engines, pumps and transmissions, the manufacture and remanufacture of oilfield service equipment and the manufacture of compression equipment for natural gas transmission and for natural gas fired power generation plants, all of which represented 69% of the segment’s 2011 revenues. The Company offers a full line of custom fabricated oilfield service equipment, fully tested and field ready. The Company manufactures products or components that are purchased by a company and marketed under the purchasing company’s brand name. The Company distributes, sells parts and services diesel engines and transmissions for on and off-highway use and provides in-house and in-field service capabilities. The Company is the largest off-highway distributor of Allison, a major distributor of MTU in North America, and a distributor of Isuzu diesel engines. The Company is also the exclusive distributor for Daimler for engines and related equipment in Oklahoma, Arkansas and Louisiana. The Company manufactures and remanufacturers oilfield service equipment, including hydraulic fracturing equipment, pressure pumping units, nitrogen pumping units, cementers, hydration equipment, mud pumps and blenders. The Company also manufactures and packages custom compressor systems, including electric motor driven systems, natural gas driven systems and industrial air systems, and manufactures natural gas General Motors and Isuzu diesel-powered engines for a variety of applications from 40 to 500 horsepower. Lastly, the Company is a dealer of Thermo King refrigerated systems for trucks, railroad cars and other land transportation markets in south and central Texas.

The Company’s land-based operations is based in Oklahoma City, Oklahoma with 21 locations across seven states in key oil and gas producing regions and major transportation corridors. The distribution and service facilities are located in Oklahoma City and Tulsa, Oklahoma, Little Rock and Van Buren, Arkansas and Shreveport, Louisiana. The Company’s manufacturing facilities are located in five locations in Oklahoma City, two locations in Commerce City, Colorado and one location each in Casper, Wyoming, Billings, Montana and Lubbock and Amarillo, Texas. The Company’s refrigeration facilities are located in Houston, Pharr, Laredo, San Antonio and Austin, Texas.

Land-Based Customers

The Company’s major land-based customers include large and mid-cap oilfield service providers, oil and gas operators and producers, compression companies, domestic utilities, on-highway transportation companies and companies associated with the agricultural markets. The Company has long standing relationships with most of its customers.

Since the land-based business is linked to the oilfield services industry, oil and gas operators, and producers, there is no assurance that its present gross revenues can be maintained in the future. The results of the land-based diesel engines services industry are largely tied to the industries it serves and, therefore, are influenced by the cycles of such industries.

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Land-Based Competitive Conditions

The Company’s primary competitors are other oilfield service manufacturers and services companies. While price is a major determinant in the competitive process, equipment availability, reputation, consistent quality, expeditious service, experienced personnel, access to parts inventories and market presence are also significant factors. A substantial portion of the Company’s business is obtained by competitive bids.

Employees

The Company’s diesel engine services segment has approximately 1,200 employees. None of the segment’s operations are subject to collective bargaining agreements.

Properties

The principal offices of the diesel engine services segment are located in Houma, Louisiana and Oklahoma City, Oklahoma.

The marine and power generation operations operate 12 parts and service facilities, with two facilities located in Houma, Louisiana, and one facility each located in Baton Rouge, Belle Chasse and New Iberia, Louisiana, Mobile, Alabama, Houston, Texas, Chesapeake, Virginia, Rocky Mount, North Carolina, Paducah, Kentucky, Tampa, Florida and Seattle, Washington. All of these facilities are leased except the Houma, Belle Chasse and New Iberia, Louisiana facilities, which are owned by the Company.

The land-based operations operate 20 distribution and service and manufacturing facilities across seven states in key oil and gas producing regions and major transportation corridors. The distribution and service facilities are located in Oklahoma City and Tulsa, Oklahoma, Little Rock and Van Buren, Arkansas and Shreveport, Louisiana. The Oklahoma City, Oklahoma, Shreveport, Louisiana and the Little Rock, Arkansas facilities are owned by the Company and the Tulsa, Oklahoma and Van Buren, Arkansas facilities are leased. The Company’s manufacturing facilities are located in five locations in Oklahoma City, two locations in Commerce City, Colorado and one location each in Casper, Wyoming, Billings, Montana and Lubbock and Amarillo, Texas. All of the manufacturing facilities are leased except the Lubbock and Amarillo, Texas facilities, which are owned by the Company. The Company’s refrigeration facilities are located in Houston, Pharr, Laredo, San Antonio and Austin, Texas. All of these facilities are leased except for the San Antonio facility which is owned by the Company.

Executive Officers of the Registrant

The executive officers of the Company are as follows:

Name	Age	Positions and Offices
Joseph H. Pyne	64	Chairman of the Board and Chief Executive Officer
Gregory R. Binion	47	President and Chief Operating Officer
David W. Grzebinski	50	Executive Vice President and Chief Financial Officer
David D. Whisenhunt	59	Executive Vice President — Diesel Engine Services
William G. Ivey	68	President — Kirby Inland Marine
James F. Farley	60	President — K-Sea Transportation
Bill F. Moore, Jr.	59	President — United Holdings
Dorman L. Strahan	55	President — Kirby Engine Systems
Ronald A. Dragg	48	Vice President and Controller
G. Stephen Holcomb	66	Vice President — Investor Relations and Assistant Secretary
Amy D. Husted	43	Vice President — Legal
David R. Mosley	47	Vice President and Chief Information Officer
Joseph H. Reniers	37	Vice President — Human Resources
Renato A. Castro	40	Treasurer

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No family relationship exists among the executive officers or among the executive officers and the directors. Officers are elected to hold office until the annual meeting of directors, which immediately follows the annual meeting of stockholders, or until their respective successors are elected and have qualified.

Joseph H. Pyne holds a degree in liberal arts from the University of North Carolina and has served the Company as Chairman of the Board and Chief Executive Officer since April 2011. He served the Company as Chairman of the Board, President and Chief Executive Officer from April 2010 to April 2011 and as President and Chief Executive Officer from 1995 to April 2010, Executive Vice President from 1992 to 1995 and as President of Kirby Inland Marine from 1984 to November 1999. He has served the Company as a Director since 1988. He also served in various operating and administrative capacities with Kirby Inland Marine from 1978 to 1984, including Executive Vice President from January to June 1984. Prior to joining the Company, he was employed by Northrop Services, Inc. and served as an officer in the Navy.

Gregory R. Binion holds a degree in business administration from the University of Texas. He has served the Company as President and Chief Operating Officer since April 2011, served as President of Kirby Inland Marine from October 2008 to April 2011 and as Vice President of Corporate Development and Strategy from September 2007 to October 2008. He previously served as Kirby Inland Marine’s Vice President — Sales from 2003 to 2007 and Vice President — Canal Operations from 1999 to 2003. Prior to joining the Company in October of 1999, he served Hollywood Marine, an inland tank barge company acquired by the Company in October 1999, for 11 years in a variety of sales and operational roles.

David W. Grzebinski is a Chartered Financial Analyst and holds a Masters in Business Administration degree from Tulane University and a degree in chemical engineering from the University of South Florida. He has served as Executive Vice President and Chief Financial Officer since March 2010, having joined the Company in February 2010. Prior to joining the Company, he served in various administrative positions since 1988 with FMC Technologies Inc., including Controller, Energy Services, Treasurer, and Director of Global SAP and Industry Relations. Prior to joining FMC, he was employed by Dow Chemical.

David F. Whisenhunt holds a degree in finance from the University of Texas. He has served the Company as Executive Vice President — Diesel Engine Services since July 2011. Prior to joining the Company in 2011, he served as President of ProEnergy EPC Services LLC from 2008 to 2011, President of Wood Group Power Solutions, Inc. from 2001 to 2008 and Vice President of General Electric Company Packaged Power from 1998 to 2001. From 1976 to 1998, he served in various positions with Stewart & Stevenson Services, Inc., including Vice President of Gas Turbine Services from 1991 to 1998.

William G. Ivey attended the University of Houston and has served the Company as President of Kirby Inland Marine since April 2011 and served as Executive Vice President, Sales and Marketing from 1989 to April 2011. He joined the Company in 1989 with the acquisition of Alamo Inland Marine. Prior to joining the Company he served in various sales and marketing positions with inland marine companies dating back to 1970.

James F. Farley holds a Master of Science degree from Thunderbird School of Global Management and a bachelor of arts degree from Texas Tech University. He has served the Company as President of K-Sea Transportation since February 2012 and served as Executive Vice President – Operations of Kirby Inland Marine from 2003 to February 2012. Prior to joining the Company in 2003, he held senior level marketing, logistics and operations positions in the marine transportation industry.

Bill F. Moore, Jr. holds a degree in business administration from Oklahoma State University. He has served the Company as President of United Holdings since April 2011. Prior to joining the Company in April of 2011 with the acquisition of United, he served as President and Chief Executive Officer of United Holdings LLC from 2008 to April 2011. From 1974 to 2008 he held various sales and management positions with United, including various Vice President positions.

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Dorman L. Strahan attended Nicholls State University and has served the Company as President of Kirby Engine Systems since May 1999, President of Marine Systems since 1986 and President of Engine Systems since 1996. After joining the Company in 1982 in connection with the acquisition of Marine Systems, he served as Vice President of Marine Systems until 1985.

Ronald A. Dragg is a Certified Public Accountant and holds a Master of Science in Accountancy degree from the University of Houston and a degree in finance from Texas A&M University. He has served the Company as Vice President and Controller since January 2007. He also served as Controller from November 2002 to January 2007, Controller — Financial Reporting from January 1999 to October 2002, and Assistant Controller — Financial Reporting from October 1996 to December 1998. Prior to joining the Company, he was employed by Baker Hughes Incorporated.

G. Stephen Holcomb holds a degree in business administration from Stephen F. Austin State University and has served the Company as Vice President — Investor Relations and Assistant Secretary since November 2002. He also served as Vice President, Controller and Assistant Secretary from 1989 to November 2002, Controller from 1987 through 1988 and as Assistant Controller from 1976 through 1986. Prior to that, he was Assistant Controller of Kirby Industries from 1973 to 1976. Prior to joining the Company in 1973, he was employed by Cooper Industries, Inc.

Amy D. Husted holds a doctorate of jurisprudence from South Texas College of Law and a degree in political science from the University of Houston. She has served the Company as Vice President — Legal since January 2008 and served as Corporate Counsel from November 1999 through December 2007. Prior to joining the Company, she served as Corporate Counsel of Hollywood Marine from 1996 to 1999 after joining Hollywood Marine in 1994.

David R. Mosley holds a degree in computer science from Texas A&M University and has served the Company as Vice President and Chief Information Officer since May 2007. Prior to joining the Company in 2007, he served as Vice President and Chief Information Officer for Prudential Real Estate Services Company from 2005 to May 2007, Vice President — Service Delivery for Iconixx Corporation from 1999 to 2005, Vice President — Product Development and Services for ADP Dealer Services from 1995 to 1999 and in various information technology development and management positions from 1987 to 1995.

Joseph H. Reniers holds a degree in mechanical engineering from the United States Naval Academy and a Masters in Business Administration from the University of Chicago Booth School of Business. He has served as Vice President — Human Resources since March 2010. Prior to joining the Company, he was a management consultant with McKinsey & Company serving a wide variety of industrial clients. Prior to joining McKinsey, he served as a nuclear power officer in the Navy.

Renato A. Castro is a Certified Public Accountant and holds a Masters in Business Administration degree from Tulane University and a degree in civil engineering from the National Autonomous University of Honduras. He has served the Company as Treasurer since April 2010 and served as Manager of Financial Analysis from 2007 to April 2010. He also served as Financial Analyst from 2005 through 2006 and Assistant Controller of Kirby Inland Marine from 2001 through 2004. Prior to joining the Company, he was employed by a subsidiary of Astaldi S.p.A. in their transport infrastructure division.

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Item 1A. Risk Factors

The following risk factors should be considered carefully when evaluating the Company, as its businesses, results of operations, or financial condition could be materially adversely affected by any of these risks. The following discussion does not attempt to cover factors, such as trends in the United States and global economies or the level of interest rates, among others, that are likely to affect most businesses.

The Inland Waterway infrastructure is aging and may result in increased costs and disruptions to the Company’s marine transportation segment. Maintenance of the United States inland waterway system is vital to the Company’s operations. The system is composed of over 12,000 miles of commercially navigable waterway, supported by over 240 locks and dams designed to provide flood control, maintain pool levels of water in certain areas of the country and facilitate navigation on the inland river system. The United States inland waterway infrastructure is aging, with more than half of the locks over 50 years old. As a result, due to the age of the locks, scheduled and unscheduled maintenance outages may be more frequent in nature, resulting in delays and additional operating expenses. One-half of the cost of new construction and major rehabilitation of locks and dams is paid by marine transportation companies through a 20 cent per gallon diesel fuel tax and the remaining 50% is paid from general federal tax revenues. Failure of the federal government to adequately fund infrastructure maintenance and improvements in the future would have a negative impact on the Company’s ability to deliver products for its customers on a timely basis. In addition, any additional user taxes that may be imposed in the future to fund infrastructure improvements would increase the Company’s operating expenses.

The Company is subject to adverse weather conditions in its marine transportation segment. The Company’s marine transportation segment is subject to weather conditions on a daily basis. Adverse weather conditions such as high or low water on the inland waterway systems, fog and ice, tropical storms, hurricanes and tsunamis on both the inland waterway systems and throughout the United States coastal waters can impair the operating efficiencies of the marine fleet. Such adverse weather conditions can cause a delay, diversion or postponement of shipments of products and are totally beyond the control of the Company. In addition, adverse water and weather conditions can negatively affect a towing vessel’s performance, tow size, loading drafts, fleet efficiency, place limitations on night passages and dictate horsepower requirements. During the 2011 second quarter, high water and flooding throughout the Mississippi River System and along the Gulf Intracoastal Waterway near Morgan City negatively impacted the quarter by an estimated $.07 per share. During 2010 and 2009, the Company experienced more favorable weather conditions and water levels. The Company’s operations for 2011, 2010 and 2009 were not materially affected by Gulf Coast hurricanes and tropical storms.

The Company could be adversely impacted by a marine accident or spill event. A marine accident or spill event could close a portion of the inland waterway system or a coastal area of the United States for a period of time. Although statistically marine transportation is the safest means of transporting bulk commodities, accidents do occur, both involving Company equipment and equipment owned by other marine carriers.

The Company transports a wide variety of petrochemicals, black oil products, refined petroleum products and agricultural chemicals throughout the Mississippi River System, the Gulf Intracoastal Waterway and along all three United States coasts and in Alaska and Hawaii. The Company manages its exposure to losses from potential discharges of pollutants through the use of well maintained and equipped tank barges and towing vessels, through safety, training and environmental programs, and through the Company’s insurance program, but a discharge of pollutants by the Company could have an adverse effect on the Company.

The Company’s marine transportation segment is dependent on its ability to adequately crew its towing vessels. The Company’s towing vessels are crewed with employees who are licensed or certified by the USCG, including its captains, pilots, engineers and tankermen. The success of the Company’s marine transportation segment is dependent on the Company’s ability to adequately crew its towing vessels. As a result, the Company invests significant resources in training its crews and providing crew members an opportunity to advance from a deckhand to the captain of a Company towboat or tugboat, or on the coastal tugboats from a deckhand to the chief engineer. Lifestyle issues are a deterrent for employment for inland and coastal crew members. Inland

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crew members generally work a 20 days on, 10 days off rotation, or a 30 days on, 15 days off rotation. For the coastal fleet, crew members are generally required to work a 14 days on, 14 days off, 21 days on, 21 days off or 30 days on, 30 days off rotation, dependent upon the location. With the rising unemployment rates during 2008 and 2009 and continued high unemployment rates during 2010 and 2011 associated with the economic recession, crewing levels have remained adequate.

The Company’s coastal marine transportation business is composed of employees subject to collective bargaining agreements in certain geographic areas. Any work stoppages or labor disturbances could disrupt business in those areas. Approximately 300 of K-Sea’s seagoing personnel were employed under one contract with a division of the ILA that expired on June 30, 2011. An election was held as a result of a separate union petitioning the NLRB for a decertification of the ILA representation and the establishment of an alternative union, the Richmond Terrace Bargaining Unit. On February 10, 2012, the eligible employees voted to certify the Richmond Terrace Bargaining Unit as representative of the employees formerly represented by the ILA. As of February 21, 2012, the union election results are pending certification by the NLRB.

Reduction in the number of acquisitions made by the Company may curtail future growth. Since 1987, the Company has been successful in the integration of 29 acquisitions in its marine transportation segment and 16 acquisitions in its diesel engine services segment. Acquisitions have played a significant part in the growth of the Company. The Company’s marine transportation revenue in 1987 was $40.2 million compared with $1.2 billion in 2011. Diesel engine services revenue in 1987 was $7.1 million compared with $655.8 million in 2011. While the Company is of the opinion that future acquisition opportunities exist in both its marine transportation and diesel engine services segments, the Company may not be able to continue to grow through acquisitions to the extent that it has in the past.

The Company’s failure to comply with the Foreign Corrupt Practices Act (“FCPA”) could have a negative impact on its ongoing operations. The Company’s operations outside the United States require the Company to comply with a number of United States and international regulations. For example, its operations in countries outside the United States are subject to the FCPA, which prohibits United States companies or their agents and employees from providing anything of value to a foreign official for the purposes of influencing any act or decision of these individuals in their official capacity to help obtain or retain business, direct business to any person or corporate entity, or obtain any unfair advantage. The Company has internal control policies and procedures and has implemented training and compliance programs for its employees and agents with respect to the FCPA. However, the Company’s policies, procedures and programs may not always protect it from reckless or criminal acts committed by its employees or agents, and severe criminal or civil sanctions would be the result of violations of the FCPA. The Company is also subject to the risks that its employees, joint venture partners, and agents outside of the United States may fail to comply with other applicable laws.

The Company’s marine transportation segment is subject to the Jones Act. The Company’s marine transportation segment competes principally in markets subject to the Jones Act, a federal cabotage law that restricts domestic marine transportation in the United States to vessels built and registered in the United States, and manned and owned by United States citizens. The Company presently meets all of the requirements of the Jones Act for its owned vessels. The loss of Jones Act status could have a significant negative effect on the Company. The requirements that the Company’s vessels be United States built and manned by United States citizens, the crewing requirements and material requirements of the USCG, and the application of United States labor and tax laws increases the cost of United States flag vessels when compared with comparable foreign flag vessels. The Company’s business could be adversely affected if the Jones Act were to be modified so as to permit foreign competition that is not subject to the same United States government imposed burdens. Since the events of September 11, 2001, the United States government has taken steps to increase security of United States ports, coastal waters and inland waterways. The Company feels that it is unlikely that the current cabotage provisions of the Jones Act would be modified or eliminated in the foreseeable future.

The Secretary of Homeland Security is vested with the authority and discretion to waive the Jones Act to such extent and upon such terms as she may prescribe whenever she deems that such action is necessary in the interest of national defense. In response to the effects of Hurricanes Katrina and Rita, the Secretary of Homeland

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Security waived the Jones Act generally for the transportation of petroleum products from September 1 to September 19, 2005 and from September 26, 2005 to October 24, 2005. In June 2011, the Secretary of Homeland Security waived the Jones Act for the transportation of petroleum released from the Strategic Petroleum Reserve. Continued waiver of the Jones Act, whether in response to natural disasters or otherwise, could result in increased competition from foreign tank vessel operators, which could negatively impact the marine transportation segment.

The Company’s marine transportation segment is subject to regulation by the USCG, federal laws, state laws and certain international conventions, as well as numerous environmental regulations. The majority of the Company’s vessels are subject to inspection by the USCG and carry certificates of inspection. The crews employed by the Company aboard vessels are licensed or certified by the USCG. The Company is required by various governmental agencies to obtain licenses, certificates and permits for its vessels. The Company’s operations are also affected by various United States and state regulations and legislation enacted for protection of the environment. The Company incurs significant expenses to comply with applicable laws and regulations and any significant new regulation or legislation, including climate change laws or regulations, could have an adverse effect on the Company.

The Company is subject to risks associated with possible climate change legislation, regulation and international accords. Greenhouse gas emissions have increasingly become the subject of a large amount of international, national, regional, state and local attention. On December 7, 2009, the United States Environmental Protection Agency (“EPA”) furthered its focus on greenhouse gas emissions when it issued its endangerment finding in response to a decision of the Supreme Court of the United States. The EPA found that the emission of six greenhouse gases, including carbon dioxide (which is emitted from the combustion of fossil fuels), may reasonably be anticipated to endanger public health and welfare. Based on this finding, the EPA defined the mix of these six greenhouse gases to be “air pollution” subject to regulation under the Clean Air Act. Although the EPA has stated a preference that greenhouse gas regulation be based on new federal legislation rather than the existing Clean Air Act, many sources of greenhouse gas emissions may be regulated without the need for further legislation.

The United States Congress has considered in the past legislation that would create an economy-wide “cap-and-trade” system that would establish a limit (or cap) on overall greenhouse gas emissions and create a market for the purchase and sale of emissions permits or “allowances.” Any proposed cap-and-trade legislation would likely affect the chemical industry due to anticipated increases in energy costs as fuel providers pass on the cost of the emissions allowances, which they would be required to obtain under cap-and-trade to cover the emissions from fuel production and the eventual use of fuel by the Company or its energy suppliers. In addition, cap-and-trade proposals would likely increase the cost of energy, including purchases of diesel fuel, steam and electricity, and certain raw materials used or transported by the Company. Proposed domestic and international cap-and-trade systems could materially increase raw material and operating costs of the Company’s customer base. Future environmental regulatory developments related to climate change in the United States that restrict emissions of greenhouse gases could result in financial impacts on the Company’s operations that cannot be predicted with certainty at this time.

The Company’s marine transportation segment is subject to volatility in the United States production of petrochemicals. For 2011, 59% of the marine transportation segment’s revenues were from the movement of petrochemicals, including the movement of raw materials and feedstocks from one refinery and petrochemical plant to another, as well as the movement of more finished products to end users and terminals for export. During 2011, petrochemical volumes continued to improve compared with 2010 and 2009 primarily due to lower priced domestic natural gas that improved the competitiveness of the United States petrochemical industry in global markets, thereby producing increased marine transportation volumes for basic petrochemicals to both domestic consumers and terminals for export destinations. This improvement in volumes was partially offset by the continued generally weak United States economy. Higher natural gas prices and other factors could negatively impact the United States petrochemical industry and its production volumes, which would negatively impact the Company.

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The Company’s marine transportation segment could be adversely impacted by the construction of tank barges by its competitors. At the present time, there are an estimated 3,100 inland tank barges in the United States, of which the Company operates 819, or 26%. The number of tank barges peaked at an estimated 4,200 in 1982, slowly declined to 2,750 by 2003, and with the favorable market conditions through the first nine months of 2008 gradually increased to 3,150 by late 2009 and currently stands at an estimated 3,100. Strong tank barge transportation markets in 2006, 2007 and through the first nine months of 2008 absorbed the additional capacity built by the industry. During 2007 and the first nine months of 2008, prior to the deterioration of the marine transportation markets in the 2008 fourth quarter, the Company and many competitors signed tank barge construction contracts with shipyards for 2009 deliveries. The Company believes that 192 tank barges were delivered and placed in service during 2009, of which 50, including seven new chartered barges, were for the Company, and an estimated 140 tank barges were retired, 101 of which were the Company’s. The Company estimates that 160 tank barges were placed in service during 2011, of which 40 were for the Company, and an estimated 100 to 125 were retired, 66 of which were the Company’s. Due to the improved demand during 2011 for inland petrochemical and black oil barges and federal tax incentives on new equipment, the Company estimates that approximately 230 tank barges were ordered during 2011 and early 2012 for delivery throughout 2012, 55 of which are for the Company, and many older tank barges will be retired, dependent on 2012 market conditions.

The risk of an oversupply of inland tank barges may be mitigated by the fact that the inland tank barge industry has a mature fleet. Of the estimated 3,100 tank barges in the industry at the present time, approximately 500 are over 35 years old and approximately 250 of those are over 40 years old. With the high cost of maintaining the USCG certification requirements for older tank barges and the current low term contract and spot contract rate environment limiting recovery of maintenance costs for older barges, the Company expects older barges will continue to be removed from service and industry supply and demand will continue to slowly move closer to balance.

At the present time, with the industry coastal tank barge market utilization rates in the 70% to 80% range, very few coastal tank barges were built during 2011 and the Company believes very few orders for coastal tank barges have been placed for 2012 deliveries.

Higher fuel prices could increase operating expenses. The cost of fuel during 2011 was approximately 14% of marine transportation revenue, as the Company consumed 54.0 million gallons of diesel fuel at an average price of $3.10 per gallon. This compares with 2010 when the cost of fuel was approximately 11% of marine transportation revenue, as the Company consumed 43.3 million gallons of diesel fuel at an average price of $2.22 per gallon. All 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 adjust to 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.

Loss of a large customer or other significant business relationship could adversely affect the Company. Two marine transportation customers, Dow and SeaRiver, accounted for approximately 16% of the Company’s 2011 revenue, 23% of 2010 revenue and 21% of 2009 revenue. Although the Company considers its relationships with Dow and SeaRiver to be strong, the loss of either customer could have an adverse effect on the Company.

The Company’s diesel engine services segment has a 46-year relationship with EMD, the largest manufacturer of medium-speed diesel engines. In addition, the Company serves as both an EMD distributor and service center for select markets and locations for both service and parts. Sales and service of EMD products account for approximately 3% of the Company’s revenue for 2011. Although the Company considers its relationship with EMD to be strong, the loss of the EMD distributorship and service rights, or a disruption of the supply of EMD parts, could have a negative impact on the Company’s ability to service its customers.

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United has maintained continuous exclusive distribution rights for MTU and Allison since 1946. United is one of MTU’s top five distributors of off-highway engines in North America, with exclusive distribution rights in Oklahoma, Arkansas, Louisiana and Mississippi. In addition, as a distributor of Allison products, United has distribution rights in Oklahoma, Arkansas and Louisiana. United is also the exclusive distributor for Daimler for engines and related equipment in Oklahoma, Arkansas and Louisiana. Sales and service of MTU and Allison products account for approximately 4% and 7%, respectively, of the Company’s revenue during 2011. Although the Company considers its relationships with MTU and Allison to be strong, the loss of MTU, Allison or Daimler distributorships and service rights, or a disruption of the supply of MTU or Allison parts, could have a negative impact on the Company’s ability to service its customers.

The Company is subject to competition in both its marine transportation and diesel engine services segments. The inland and coastal tank barge industry remains very competitive. The Company’s primary competitors are noncaptive inland tank barge operators and coastal operators. The Company also competes with companies who operate refined product and petrochemical pipelines, railroad tank cars and tractor-trailer tank trucks. Increased competition from any significant expansion of or additions to facilities or equipment by the Company’s competitors could have a negative impact on the Company’s results of operations.

The diesel engine services industry is also very competitive. The segment’s primary marine competitors are independent diesel services companies and other factory-authorized distributors, authorized service centers and authorized marine dealers. Certain operators of diesel powered marine equipment also elect to maintain in-house service capabilities. In the power generation market, the primary competitors are other independent service companies. The segment’s land-based market’s principal competitors are independent diesel engine service and oilfield manufacturing companies and other factory-authorized distributors and service centers. In addition, certain oilfield service companies that are customers of the Company also manufacture and service a portion of their own oilfield equipment. Increased competition in the diesel engine services industry could result in less oilfield equipment being manufactured, lower rates for service and parts pricing and result in less manufacturing, service and repair opportunities and parts sales for the Company.

Significant increases in the construction cost of inland tank barges and towboats may limit the Company’s ability to earn an adequate return on its investment in new tank barges and towboats. The price of steel increased significantly from 2006 to 2009, thereby increasing the construction cost of new tank barges and towboats. The Company’s average construction price for a new 30,000 barrel capacity inland tank barge ordered in 2008 for 2009 delivery was approximately 90% higher than in 2000, primarily due to the increase in steel prices. During 2009, the United States and global recession negatively impacted demand levels for inland tank barges and as a result, the construction price of inland tank barges for 2010 delivery fell significantly, primarily due to a significant decrease in steel prices, as well as a decrease in the number of tank barges ordered. The average construction price for tank barges ordered in 2011 for delivery in 2012 increased, but remained significantly below the construction price for tank barges built in 2008 and delivered in 2009.

The Company’s diesel engine services segment could be adversely impacted by future legislation or additional regulation of hydraulic fracturing practices. The Company, through its United subsidiary, is a distributor and service provider of engine and transmission related products for the oil and gas services, power generation and transportation industries, and a manufacturer of oilfield service equipment, including hydraulic fracturing equipment. The EPA is studying hydraulic fracturing practices, and legislation may be introduced in Congress that would authorize the EPA to impose additional regulations on hydraulic fracturing. In addition, a number of states are evaluating the adoption of legislation or regulations governing hydraulic fracturing. Such federal or state legislation and/or regulations could materially impact customers’ operations and greatly reduce or eliminate demand for the Company’s hydraulic fracturing equipment and related products. The Company is unable to predict whether future legislation or any other regulations will ultimately be enacted, and if so, the impact on the Company’s diesel engine services segment.

The Company’s diesel engine services segment could be adversely impacted by the construction of hydraulic fracturing horsepower by its competitors. At the present time, there is an estimated 14 million horsepower of

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hydraulic fracturing equipment in North America used in the hydraulic fracturing of shale formations. Increased expansion of, or additions to, facilities or equipment by the Company’s competitors could have a negative impact on the Company’s results of operations. A significant drop in demand as well could result in oversupply in the pressure pumping market as attrition rates may not be high enough to absorb the new capacity entering the market and could negatively impact the Company’s results of operations.

Item 1B. Unresolved Staff Comments

Not applicable.

Item 2. Properties

The information appearing in Item 1 under “Marine Transportation– Properties” and “Diesel Engine Services– Properties” is incorporated herein by reference. The Company believes that its facilities are adequate for its needs and additional facilities would be available if required.

Item 3. Legal Proceedings

In June 2011, the Company as well as three other companies received correspondence from the EPA concerning ongoing cleanup and restoration activities under CERCLA with respect to a Superfund site, the Gulfco Marine Maintenance Site (“Gulfco”), located in Freeport, Texas. In prior years, various subsidiaries of the Company utilized a successor to Gulfco to perform tank barge cleaning services, sand blasting and repair on certain Company vessels. The EPA continues to investigate activities at the site to assess additional Potentially Responsible Parties (“PRPs”). Since 2005, four named PRPs have participated in the investigation, cleanup and restoration of the site under an administrative order from EPA. Information received to date indicates that approximately $3,500,000 has been incurred in connection with the cleanup effort in addition to EPA’s oversight costs of approximately $1,800,000. To date, neither the EPA nor the named PRPs have performed an allocation of potential liability in connection with the site nor have they provided requested cost and expenses supporting documentation related to the site. The Company is investigating its activities at the site in order to assess what, if any, liability it has in connection with the site.

In 2009, the Company was named a PRP in addition to a group of approximately 250 named PRPs under CERCLA with respect to a Superfund site, the Portland Harbor Superfund site (“Portland Harbor”) in Portland, Oregon. The site was declared a Superfund site in December 2000 as a result of historical heavily industrialized use due to manufacturing, shipbuilding, petroleum storage and distribution, metals salvaging, and electrical power generation activities which led to contamination of Portland Harbor, an urban and industrial reach of the lower Willamette River located immediately downstream of downtown Portland. The Company’s involvement arises from four spills at the site after it was declared a Superfund site, as a result of predecessor entities’ actions in the area. To date, there is no information suggesting the extent of the costs or damages to be claimed from the 250 noticed PRPs. Based on the nature of the involvement at the Portland Harbor site, the Company believes its potential contribution is de minimis; however, to date neither the EPA nor the named PRPs have performed an allocation of potential liability in connection with the site nor have they provided costs and expenses in connection with the site.

In 2000, the Company and a group of approximately 45 other companies were notified that they are PRPs under the CERCLA with respect to a Superfund site, the Palmer Barge Line Superfund Site (“Palmer”), located in Port Arthur, Texas. In prior years, Palmer had provided tank barge cleaning services to various subsidiaries of the Company. The Company and three other PRPs entered into an agreement with the EPA to perform a remedial investigation and feasibility study and, subsequently, a limited remediation was performed and is now complete. During the 2007 third quarter, five new PRPs entered into an agreement with the EPA related to the Palmer site. In July 2008, the EPA sent a letter to approximately 30 PRPs for the Palmer site, including the Company, indicating that it intends to pursue recovery of $2,949,000 of costs it incurred in relation to the site. The Company and the other PRPs continue to discuss suggested pro rata allocations of costs to all PRPs with the EPA and the U.S. Department of Justice (“DOJ”) in order to resolve the EPA’s past costs claim.

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In 2000, the Company and approximately 50 other companies were notified that they are PRPs under the CERCLA with respect to a Superfund site, the State Marine of Port Arthur Superfund Site (“State Marine”), located in Port Arthur, Texas. In the past, State Marine performed tank barge cleaning and services for various subsidiaries of the Company. In March 2010, the DOJ and EPA issued a letter to seven PRPs, which include the former owners/operator of the site and others, including the Company, indicating their intent to pursue reimbursement of its past costs of approximately $2,977,000 in connection with clean-up activities in relation to the site. The Company and the other PRPs will continue to pursue documentation concerning the site activities related to all PRPs in order to determine appropriate allocation of past costs relative to activities at the site to develop suggested pro rata sharing to resolve the EPA’s past cost claim.

With respect to the above sites, the Company has recorded reserves, if applicable, for its estimated potential liability for its portion of the EPA’s past costs claim based on information developed to date including various factors such as the Company’s liability in proportion to other responsible parties and the extent to which such costs are recoverable from third parties.

On July 25, 2011, a subsidiary of the Company was named as a defendant in the U.S. District Court for the Southern District of Texas - Galveston Division, in a complaint styled Figgs. v. Kirby Inland Marine, et al., which alleges that the plaintiff individually as a vessel tankerman, and on behalf of other current and former similarly situated vessel tankerman employed with the Company, is entitled to overtime pay under the Fair Labor Standards Act. Plaintiffs assert that vessel tankerman are not seaman who are expressly exempt from overtime pay provisions under the law. The case was conditionally certified as a collective action on December 22, 2011 at which time the Court prescribed a notice period for current and former employees to voluntarily participate as a plaintiff. The notice period closes on February 27, 2012 after which time discovery will be conducted with respect to the merits of the case. Plaintiff seeks to maintain a collective action, compensatory damages in the form of back pay, attorney fees, cost and liquidated damages. As discovery as to the merits of the case has not been conducted to date, the Company is unable to assess the liability at this time. Accordingly, the Company is not able to estimate any amount of loss or range of loss.

On January 30, 2012 in the U.S. District Court for the District of New Jersey and styled Rescue Mission of El Paso., Inc., et al. v. John J. Nicola, et als., the Company, its subsidiary, 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 conditions, and asserting violations of Section a 10(b)(5) and 20(a) of the Securities and Exchange Act of 1934 and Rule 10b-5 thereunder. Plaintiff seeks class certification, compensatory damages, attorneys fees and costs. The Company believes that this suit is without merit and intends to vigorously defend itself in this matter based on the information available to the Company at this time. The Company does not expect the outcome of this matter to have a material adverse effect on its consolidated financial statements; however, there can be no assurance as to the ultimate outcome of this matter.

In addition, 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.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

The Company’s common stock is traded on the New York Stock Exchange under the symbol KEX. The following table sets forth the high and low sales prices per share for the common stock for the periods indicated:

	Sales Price
	High		Low
2012
First Quarter (through February 22, 2012)	$	70.22	$	61.20
2011
First Quarter		60.00		43.29
Second Quarter		58.25		50.97
Third Quarter		60.00		47.23
Fourth Quarter		66.36		49.00
2010
First Quarter		38.77		30.83
Second Quarter		43.96		36.60
Third Quarter		43.33		35.78
Fourth Quarter		45.78		39.25

As of February 22, 2012, the Company had 55,847,000 outstanding shares held by approximately 800 stockholders of record; however, the Company believes the number of beneficial owners of common stock exceeds this number.

The Company does not have an established dividend policy. Decisions regarding the payment of future dividends will be made by the Board of Directors based on the facts and circumstances that exist at that time. Since 1989, the Company has not paid any dividends on its common stock. The Company’s revolving credit facility and term loan contain covenants restricting the payment of dividends by the Company at any time when there is a default under the revolving credit facility and term loan.

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Item 6. Selected Financial Data

The comparative selected financial data of the Company and consolidated subsidiaries is presented for the five years ended December 31, 2011. The information should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and Results of Operations of the Company in Item 7 and the Financial Statements included under Item 8 (selected financial data in thousands, except per share amounts).

	December 31,
	2011		2010		2009		2008		2007
Revenues:
Marine transportation	$	1,194,607	$	915,046	$	881,298	$	1,095,475	$	928,834
Diesel engine services		655,810		194,511		200,860		264,679		243,791
	$	1,850,417	$	1,109,557	$	1,082,158	$	1,360,154	$	1,172,625
Net earnings attributable to Kirby	$	183,026	$	116,249	$	125,941	$	157,168	$	123,341
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.35	$	2.16	$	2.34	$	2.92	$	2.31
Diluted	$	3.33	$	2.15	$	2.34	$	2.91	$	2.29
Common stock outstanding:
Basic		54,191		53,331		53,192		53,238		52,831
Diluted		54,413		53,466		53,313		53,513		53,263
	December 31,
	2011		2010		2009		2008		2007
Property and equipment, net	$	1,822,173	$	1,118,161	$	1,085,057	$	990,932	$	906,098
Total assets	$	2,960,411	$	1,794,937	$	1,635,963	$	1,526,098	$	1,430,475
Long-term debt, including current portion	$	802,005	$	200,134	$	200,239	$	247,307	$	297,383
Total equity	$	1,454,158	$	1,159,139	$	1,056,095	$	893,555	$	772,807

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Statements contained in this Form 10-K 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-K 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. Forward-looking statements are based on currently available information and the Company assumes no obligation to update any such statements.

For purposes of 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 2011, 2010 and 2009 were 54,413,000, 53,466,000 and 53,313,000, respectively.

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The increase in the weighted average number of common shares for 2011 compared with 2010 and 2009 primarily reflect the issuance of 1,939,234 shares of Company common stock associated with the July 1, 2011 acquisition of K-Sea, 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, and along all three United States coasts and in Alaska and Hawaii. The Company transports petrochemicals, black oil products, refined petroleum products and agricultural chemicals by tank barge. As of December 31, 2011, the Company operated a fleet of 819 inland tank barges, including 43 leased barges, with 16.2 million barrels of capacity, and operated an average of 240 inland towboats during 2011, of which an average of 61 were chartered. The Company’s coastal fleet consisted of 59 tank barges, of which 13 are leased and three are single hull, with 3.8 million barrels of capacity, and 65 owned coastal tugboats. The Company also owns and operates four 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 oilfield service equipment, including hydraulic fracturing equipment, for the land-based pressure pumping and oilfield service markets.

For 2011, net earnings attributable to Kirby were $183,026,000, or $3.33 per share, on revenues of $1,850,417,000, compared with 2010 net earnings attributable to Kirby of $116,249,000, or $2.15 per share, on revenues of $1,109,557,000. The 2011 second quarter and year results included an estimated $.07 per share negative impact from high water and flooding throughout the Mississippi River System and along the Gulf Intracoastal Waterway in the Morgan City area, net of certain revenue and cost recovery from contracts with terms that provide reimbursements for delays and increased costs. The 2011 year results included a $.01 per share severance charge associated with the consolidation of K-Sea’s administrative staff with the administrative staff of the Company and a $.07 per share charge associated with increasing the fair value of the United contingent earnout liability, partially offset by a $.03 per share credit in the provision for taxes on income associated with a favorable multi-year ruling.

Marine Transportation

For 2011, 65% 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 raw materials for 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 and agricultural chemicals. Consequently, the Company’s inland marine transportation business tends to mirror the volumes produced by the Company’s petrochemical and refining customer base, while the Company’s coastal marine transportation business tends to mirror the general performance of the United States economy. The 2011 results include the operations of K-Sea, acquired on July 1, 2011, and described below.

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The following table shows the marine transportation markets serviced by the Company, the marine transportation revenue distribution for 2011, products moved and the drivers of the demand for the products the Company transports:

Markets Serviced	2011 Revenue Distribution			Products Moved	Drivers
Petrochemicals		59	%	Benzene, Styrene, Methanol, Acrylonitrile, Xylene, Caustic Soda, Butadiene, Propylene	Consumer non-durables —70% Consumer durables — 30%
Black Oil Products		20	%	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		16	%	Gasoline, No. 2 Oil, Jet Fuel, Heating Oil, Naphtha, Diesel Fuel, Ethanol	Vehicle Usage, Air Travel, Weather Conditions, Refinery Utilization
Agricultural Chemicals		5	%	Anhydrous Ammonia, Nitrogen-Based Liquid Fertilizer, Industrial Ammonia	Corn, Cotton and Wheat Production, Chemical Feedstock Usage

The Company’s marine transportation segment’s revenues for 2011 increased 31% compared with 2010 and operating income for 2011 increased 36% compared with 2010. The higher marine transportation revenues reflected the acquisition of K-Sea on July 1, 2011, as well as an improvement in inland tank barge demand and equipment utilization due to strong production volumes from United States petrochemical customers, for both domestic and foreign destinations, and from black oil products customers due to steady refinery production levels, the continued export of heavy fuel oil, new demand for the transportation of crude oil from shale formations in South Texas and an increase in the movement of Canadian crude oil from the Midwest to the Gulf Coast. The Company’s inland petrochemical and black oil products fleets achieved tank barge utilization levels in the low-to-mid 90% range during 2011. Diesel fuel prices for 2011 increased 39% compared with 2010, thereby positively impacting marine transportation revenue as fuel is escalated and de-escalated through revenue adjustment clauses in customers’ term contracts, or the customer pays for the fuel. Marine transportation revenues for 2011 were negatively impacted by the high water and flooding during the 2011 second quarter as described above, net of certain revenue and cost recovery from contracts with terms that provide reimbursements for delays and increased costs. For 2011, the Company’s coastal equipment utilization rate averaged in the mid-to-high 70% range. The Atlantic, Pacific and Hawaii fleets experienced higher utilization rates, while the New York harbor fleet reflected a lower utilization rate due to overcapacity of equipment in the bunkering markets.

During 2011, approximately 75% of the inland marine transportation revenues were under term contracts and 25% were spot contract revenues. Time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented 55% of the inland revenues under term contracts during 2011 compared with 52% during 2010. Inland term contract rates renewed in the 2011 first, second, third and fourth quarters increased an average of 2% to 4%, 3% to 5%, 7% to 9% and 4% to 6%, respectively, when compared with term contract rate renewals in the corresponding quarters of 2010. Spot contract rates in the 2011 first quarter, which include the cost of fuel, increased an average of 5% to 7% compared with the 2010 fourth quarter and spot market rates for the 2011 second quarter increased an average of 7% to 9% compared with the 2011 first quarter, partially due to the high water and flooding during the quarter that increased industry wide equipment utilization levels. Spot contracts rates for the 2011 third quarter increased an average of 9% to 11% compared with the 2011 second quarter. Spot contracts rates for the 2011 fourth quarter increased an average of 7% to 9% compared with the 2011 third quarter. Effective January 1, 2011, annual escalators for labor and the producer price index on a number of multi-year contracts resulted in rate increases on those contracts by 1% to 2%, excluding fuel.

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During 2011, approximately 60% of the coastal marine transportation revenues were under term contracts and 40% were spot contract revenues. Coastal time charters represented approximately 90% of the revenues under term contracts during 2011.

For the coastal operations, term contracts renewed in the 2011 third and fourth quarters were relatively stable compared with contract rates in the 2010 third and fourth quarters, while spot contract rates for the third and fourth quarters improved in the 2% to 4% range compared with the prior 2011 quarters.

The marine transportation operating margin for 2011 was 21.9% compared with 21.1% for 2010. The higher margin reflected the improved petrochemical and black oil products demand and equipment utilization levels, and higher term contract and spot contract pricing. These were partially offset by the lower operating margins from the coastal market, by the cost impact of rising diesel fuel prices, by the 2011 second quarter loss of revenue and additional operating expenses resulting from the high water and flooding as discussed above, and by the fourth quarter severance charge discussed above.

Diesel Engine Services

During 2011, 35% of the Company’s revenue was generated by its diesel engine services segment, of which 37% was generated from manufacturing, 42% from overhauls and service and 21% from direct parts sales. 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. The 2011 results include the operations of United, acquired on April 15, 2011, and described below. During 2011, the distributorship with EMD providing replacement parts and service to the shortline, industrial, Class II and certain transit railroads was terminated.

The following table shows the markets serviced by the Company, the revenue distribution for 2011, and the customers for each market:

Markets Serviced	2011 Revenue Distribution			Customers
Land-Based		69	%	Land-Based Oilfield Services, Oil and Gas Operators and Producers, Compression, On-Highway Transportation
Marine		21	%	Inland River Carriers — Dry and Liquid, Offshore Towing — Dry and Liquid, Offshore Oilfield Services — Drilling Rigs & Supply Boats, Harbor Towing, Dredging, Great Lakes Ore Carriers
Power Generation		9	%	Standby Power Generation, Pumping Stations
Railroad		1	%	Passenger (Transit Systems), Class II, Shortline, Industrial

The Company’s diesel engine services segment’s 2011 revenue and operating income increased 237% and 231%, respectively, compared with 2010. The increases primarily reflected the acquisition of United on April 15, 2011, as United benefited from the strong demand for the manufacture and service of hydraulic fracturing equipment to meet the increased North American shale gas and crude oil production, and from the sale and service of transmissions and diesel engines and manufacture of compression systems. In addition, the increase in revenues and operating income reflected a strong medium-speed power generation market with engine-generator set upgrade projects and higher parts and engine sales and the improved inland liquid and dry marine markets, partially offset by continued weak service levels and direct parts sales in both the medium-speed and high-speed Gulf Coast oil services market.

The diesel engine services segment’s operating margin for 2011 was 10.4% compared with 10.6% for 2010. The 2011 operating margin reflected higher than historical operating margin for United, primarily the result of the higher volume leverage.

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Cash Flow and Capital Expenditures

The Company continued to generate strong operating cash flows during 2011 with net cash provided by operating activities of $311,995,000 compared with net cash provided by operating activities for 2010 of $245,246,000. The 27% increase for 2011 was primarily from higher net earnings attributable to Kirby, higher depreciation and amortization and a higher deferred tax provision in 2011 versus 2010, partially offset by a larger net decrease in cash flows from changes in operating assets and liabilities of $67,100,000, primarily due to increased receivables and inventories associated with the stronger business activity levels and a larger pension contribution in 2011 compared to 2010. In addition, during 2011 and 2010, the Company generated cash of $4,367,000 and $4,884,000, respectively, from the exercise of stock options, and $11,821,000 and $9,725,000, respectively, from proceeds from the disposition of assets.

For 2011, cash generated, borrowings under the Company’s revolving credit facility, the new term loan, and cash and cash equivalents were used for capital expenditures of $226,238,000, including $114,703,000 for inland tank barge and towboat construction, $33,335,000 for progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units scheduled for completion in 2012, and $78,200,000 primarily for upgrading the existing marine transportation fleet, and $859,512,000 for acquisitions of businesses and marine equipment. The Company’s debt-to-capitalization ratio increased to 35.5% at December 31, 2011 from 14.7% at December 31, 2010, primarily due to borrowing under a new term loan used to purchase K-Sea and borrowings under the Company’s revolving credit facility used to purchase United, less the increase in total equity from net earnings attributable to Kirby for 2011 of $183,026,000, stock issued with a fair value of $113,019,000 in connection with the acquisition of K-Sea, exercise of stock options and the amortization of unearned equity compensation. As of December 31, 2011, the Company had $95,000,000 outstanding under its revolving credit facility and $507,000,000 outstanding under the term loan, of which $39,000,000 was classified as current portion of long-term debt.

During 2011, the Company took delivery of 40 inland tank barges with a total capacity of approximately 1,100,000 barrels and one inland towboat. During 2011, the Company retired 66 inland tank barges, reducing its capacity by approximately 1,250,000 barrels.

The Company projects that capital expenditures for 2012 will be in the $255,000,000 to $265,000,000 range, including approximately $100,000,000 for the construction of 55 inland tank barges and five inland towboats and approximately $70,000,000 in progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units for delivery in the 2012 fourth quarter with an estimated total cost of $52,000,000 for each unit.

Outlook

Petrochemical and black oil products inland tank barge utilization levels continued to improve during 2011, reaching the highest utilization levels, in the low to mid 90% range, since the third quarter of 2008. While the United States economy remains sluggish, with consistently high unemployment levels and weak consumer confidence, the United States petrochemical industry has seen a steady improvement in production for both domestic consumption and exports. Lower 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 improved during the 2010 and 2011 years, thereby producing increased marine transportation volumes for basic petrochemicals to both domestic consumers and terminals for export destinations. The black oil products market also continued to improve during 2011, primarily due to a stable United States refinery utilization level aided by the export of diesel fuel and heavy fuel oil, refinery maintenance issues and new demand for the transportation of crude oil from shale formations in South Texas, as well as an increase in the movement of Canadian crude oil from the Midwest to the Gulf Coast. The coastal liquid trade is more reflective of the weaker United States economy with refined products volumes below the 2007 highs.

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The United States petrochemical industry is globally competitive based on a number of factors including a highly integrated and efficient transportation system of pipelines, railroads, trucks and tank barges, a 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 increased production volumes from the Company’s petrochemical customers have resulted in the Company’s inland tank barge utilization levels in the low to mid 90% 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.

During 2009 and 2010, the marine transportation segment was negatively impacted by excess industry inland tank barge capacity. At the end of 2011, the Company estimated there were approximately 3,100 inland tank barges in the industry fleet, of which approximately 500 were over 35 years old and approximately 250 of those 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 barges that will enter the fleet. During 2011, with the improved demand for inland petrochemical and black oil products tank barges and federal tax incentives on new equipment, the Company estimates that approximately 230 inland tank barges were ordered industry-wide for delivery throughout 2012, and many older tank barges will be retired, dependent on 2012 petrochemical and refinery production levels, crude oil movements and industry-wide tank barge utilization levels.

With the acquisition of K-Sea on July 1, 2011, the marine transportation segment expanded its bulk liquid transportation segment into the United States Jones Act coastal trade. K-Sea’s principal customers are United States based refiners, many of which were already customers of the Company. The acquisition extended the Company’s tank barge service to its customers with coastal marine transportation requirements on the East Coast, Gulf Coast and West Coast, as well as in Alaska and Hawaii. As of December 31, 2011, the Company estimated there were approximately 275 tank barges in the 185,000 barrel or less coastal fleet, of which approximately 8% are single hull that will be required to be removed from service by December 31, 2014. The Company presently operates three single hull tank barges in the coastal trade, less than 1% of its barrel capacity.

In the diesel engine services segment, the Gulf Coast oil services market remained depressed during 2011, but with the recent issuance of Gulf of Mexico drilling permits should show a slow improvement during the 2012 year as drilling activity increases. With the acquisition of United on April 15, 2011, the segment entered the land-based diesel engine and transmission services business. United manufactures oilfield service equipment, including hydraulic fracturing units and services their components, which include high-speed diesel engines, transmissions and pumps, many of the same components used by marine customers. At the date of the acquisition of United, an estimated 10 million horsepower was employed in the North American hydraulic fracturing business, with significant additional horsepower forecast to be added in the future. As of December 31, 2011, an estimated 14 million horsepower was employed in the North American hydraulic fracturing business. Although the high level of installed horsepower could slow the demand for newly manufactured units, it does provide an opportunity for remanufacturing and services to existing horsepower. United is well positioned to benefit from a strong land-based services market going forward.

Critical Accounting Policies and Estimates

The preparation of financial statements in conformity with United States generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company evaluates its estimates and assumptions on an ongoing basis based on a combination of historical information and various other assumptions that are believed to be reasonable under the particular circumstances. Actual results may differ from these estimates based on different assumptions or conditions. The Company believes the critical accounting policies that most impact the consolidated financial statements are

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described below. It is also suggested that the Company’s significant accounting policies, as described in the Company’s financial statements in Note 1, Summary of Significant Accounting Policies, be read in conjunction with this Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Accounts Receivable. The Company extends credit to its customers in the normal course of business. The Company regularly reviews its accounts and estimates the amount of uncollectible receivables each period and establishes an allowance for uncollectible amounts. The amount of the allowance is based on the age of unpaid amounts, information about the current financial strength of customers, and other relevant information. Estimates of uncollectible amounts are revised each period, and changes are recorded in the period they become known. Historically, credit risk with respect to these trade receivables has generally been considered minimal because of the financial strength of the Company’s customers; however, the current United States and global recession could impact the collectability of certain customers’ trade receivables which could have a material effect on the Company’s results of operations.

Property, Maintenance and Repairs. Property is recorded at cost. Improvements and betterments are capitalized as incurred. Depreciation is recorded on the straight-line method over the estimated useful lives of the individual assets. When property items are retired, sold or otherwise disposed of, the related cost and accumulated depreciation are removed from the accounts with any gain or loss on the disposition included in the statement of earnings. Maintenance and repairs are charged to operating expense as incurred. The Company reviews long-lived assets for impairment by vessel class whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. Recoverability of the assets is measured by a comparison of the carrying amount of the assets to future net cash expected to be generated by the assets. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs to sell. There are many assumptions and estimates underlying the determination of an impairment event or loss, if any. The assumptions and estimates include, but are not limited to, estimated fair market value of the assets and estimated future cash flows expected to be generated by these assets, which are based on additional assumptions such as asset utilization, length of service the asset will be used, and estimated salvage values. Although the Company believes its assumptions and estimates are reasonable, deviations from the assumptions and estimates could produce a materially different result.

Goodwill. The excess of the purchase price over the fair value of identifiable net assets acquired in transactions accounted for as a purchase are included in goodwill. Management monitors the recoverability of goodwill on an annual basis, or whenever events or circumstances indicate that interim impairment testing is necessary. The amount of goodwill impairment, if any, is typically measured based on projected discounted future operating cash flows using a discount rate reflecting the Company’s average weighted cost of capital. The assessment of the recoverability of goodwill will be impacted if estimated future operating cash flows are not achieved. There are many assumptions and estimates underlying the determination of an impairment event or loss, if any. Although the Company believes its assumptions and estimates are reasonable, deviations from the assumptions and estimates could produce a materially different result.

Accrued Insurance. The Company is subject to property damage and casualty risks associated with operating vessels carrying large volumes of bulk liquid and dry cargo in a marine environment. The Company maintains insurance coverage against these risks subject to a deductible, below which the Company is liable. In addition to expensing claims below the deductible amount as incurred, the Company also maintains a reserve for losses that may have occurred but have not been reported to the Company, or are not yet fully developed. The Company uses historic experience and actuarial analysis by outside consultants to estimate an appropriate level of reserves. If the actual number of claims and magnitude were substantially greater than assumed, the required level of reserves for claims incurred but not reported or fully developed could be materially understated. The Company records receivables from its insurers for incurred claims above the Company’s deductible. If the solvency of the insurers became impaired, there could be an adverse impact on the accrued receivables and the availability of insurance.

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Acquisitions

On December 15, 2011, the Company completed the purchase of the coastal tank barge fleet of Seaboats, consisting of three 80,000 barrel coastal tank barges and tugboats for $42,745,000 in cash. The three coastal tank barges and tugboats currently operate along the United States East Coast and have an average age of five years. Financing of the equipment acquisition was through the Company’s revolving credit facility.

On July 1, 2011, the Company completed the acquisition of K-Sea, an operator of tank barges and tugboats participating in the coastal transportation primarily of refined petroleum products in the United States. The total value of the transaction was $603,427,000, excluding transaction fees, consisting of $227,617,000 of cash paid to K-Sea common and preferred unit holders and the general partner, $262,791,000 of cash to retire K-Sea’s outstanding debt, and $113,019,000 through the issuance of 1,939,234 shares of Company common stock valued at $58.28 per share, the Company’s closing share price on July 1, 2011. The transaction was financed through a combination of the new $540,000,000 term loan and the issuance of Company common stock.

On the acquisition date, K-Sea’s fleet, comprised of 57 coastal tank barges with a capacity of 3.8 million barrels and 63 tugboats, operated along the East Coast, West Coast and Gulf Coast of the United States, as well as in Alaska and Hawaii. K-Sea’s tank barge fleet, 54 of which were double hulled and had an average age of approximately nine years, is one of the youngest fleets in the coastal trade. K-Sea’s customers include major oil companies and refiners, many of which are current Company customers for inland tank barge services. K-Sea has operating facilities in New York, Philadelphia, Seattle and Honolulu.

On April 15, 2011, the Company purchased United, a distributor and service provider of engine and transmission related products for the oil and gas services, power generation and transportation industries, and manufacturer of oilfield service equipment. The purchase price was $271,192,000 in cash, plus a three-year earnout provision for up to an additional $50,000,000 payable in 2014, dependent on achieving certain financial targets. United, headquartered in Oklahoma City, Oklahoma with 21 locations across seven states, distributes and services equipment and parts for Allison, MTU, Daimler, and other diesel and natural gas engines. United also manufactures oilfield service equipment, including hydraulic fracturing equipment. United’s principal customers are oilfield service companies, oil and gas operators and producers, compression companies and on-highway transportation companies. Financing of the acquisition was through the Company’s operating cash flows and borrowings under the Company’s revolving credit facility.

On February 24, 2011, the Company purchased 21 inland and offshore tank barges and 15 inland towboats and offshore tugboats from Enterprise for $53,200,000 in cash. Enterprise provided transportation and delivery services for ship bunkers (engine fuel) to cruise ships, container ships and freighters primarily in the Miami, Port Everglades and Cape Canaveral, Florida area, the three largest cruise ship ports in the United States, as well as Tampa, Florida, Mobile, Alabama and Houston, Texas. Financing of the acquisition was through the Company’s operating cash flows.

On February 9, 2011, the Company purchased from Kinder Morgan for $4,050,000 in cash a 51% interest in Kinder Morgan’s shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel. Kinder Morgan retained the remaining 49% interest and the Company will manage the operation. In addition, the Company purchased a towboat from Kinder Morgan for $1,250,000 in cash. Financing of the acquisition was through the Company’s operating cash flows.

Results of Operations

The Company reported 2011 net earnings attributable to Kirby of $183,026,000, or $3.33 per share, on revenues of $1,850,417,000, compared with 2010 net earnings attributable to Kirby of $116,249,000, or $2.15 per share, on revenues of $1,109,557,000, and 2009 net earnings attributable to Kirby of $125,941,000, or $2.34 per share, on revenues of $1,082,158,000.

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Marine transportation revenues for 2011 were $1,194,607,000, or 65% of total revenues, compared with $915,046,000, or 82% of total revenues for 2010, and $881,298,000, or 81% of total revenues for 2009. Diesel engine services revenues for 2011 were $655,810,000, or 35% of total revenues, compared with $194,511,000, or 18% of total revenues for 2010, and $200,860,000, or 19% of total revenues for 2009.

As a result of the lower demand in both the marine transportation and diesel engine services segments during late 2008, 2009 and the first quarter of 2010, the Company took specific steps to reduce overhead and lower expenditures. During the 2009 first and fourth quarters, charges totaling $8,753,000, or $.10 per share, were taken for early retirement incentives and staff reductions in both the marine transportation and diesel engine services segments. During the 2010 first quarter, the Company continued its cost reduction initiatives by further reducing its marine transportation and corporate overhead costs through early retirements and staff reductions, incurring a charge of $4,072,000 before taxes, or $.05 per share. During 2011, the Company incurred a staff reduction charge of $1,252,000 associated with the integration of K-Sea into the Company. For 2011 the Company also incurred a $.07 per share charge associated with increasing the fair value of the United contingent earnout liability. In addition, the 2011 results included a $.03 per share multi-year income tax refund.

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, and along all three United States coasts and in Alaska and Hawaii. The Company transports petrochemical, black oil products, refined petroleum products and agricultural chemicals by tank barge. As of December 31, 2011, the Company operated 819 inland tank barges, with a total capacity of 16.2 million barrels, compared with 825 inland tank barges at December 31, 2010, with a total capacity of 15.9 million barrels. The Company operated an average of 240 inland towboats during 2011 and 221 during 2010. The Company’s coastal fleet as of December 31, 2011 consisted of 59 tank barges, three of which are single hull, with 3.8 million barrels of capacity, and 65 tugboats. The Company owns and operates four offshore dry-bulk barge and tugboats engaged in the coastal transportation of dry-bulk cargoes. The Company also owns a two-thirds interest in Osprey, 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 years ended December 31, 2011 (dollars in thousands):

	2011			2010			% Change 2010 to 2011			2009			% Change 2009 to 2010
Marine transportation revenues	$	1,194,607		$	915,046			31	%	$	881,298			4	%
Costs and expenses:
Costs of sales and operating expenses		717,443			540,427			33			494,139			9
Selling, general and administrative		91,688			80,938			13			80,897			—
Taxes, other than on income		11,991			12,213			(2	)		10,587			15
Depreciation and amortization		111,292			88,710			25			87,589			1
		932,414			722,288			29			673,212			7
Operating income	$	262,193		$	192,758			36	%	$	208,086			(7	)%
Operating margins		21.9	%		21.1	%					23.6	%

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2011 Compared with 2010

Marine Transportation Revenues

Marine transportation revenues for 2011 increased 31% compared with 2010, reflecting the expansion into the coastal transportation business with the acquisition of K-Sea on July 1, 2011. K- Sea contributed approximately 11% of 2011 marine transportation revenues. The increase also reflected strong United States petrochemical production levels and stable refinery production levels, resulting in equipment utilization levels in the low-to-mid 90% range for the inland petrochemical and black oil products fleets, as well as favorable term and spot contract pricing. In addition, average diesel fuel prices for 2011 increased 39% compared with 2010, positively impacting marine transportation revenues since fuel price increases are covered by fuel escalation and de-escalation clauses in the Company’s term contracts, or the customer pays for the fuel. Marine transportation revenues for the 2011 second quarter were negatively impacted from high water and flooding throughout the Mississippi River System and along the Gulf Intracoastal Waterway in the Morgan City area, net of certain revenues and cost recovery from contracts with terms that provide reimbursements for delays.

The petrochemical market, the Company’s largest market, contributed 59% of the marine transportation revenues for 2011. Throughout 2011, petrochemical demand reflected a continued improvement in business levels with some modest decline in demand reported in the fourth quarter. Lower priced natural gas, a basic feedstock for the United States petrochemical industry, provided the industry with a competitive advantage against foreign petrochemical producers. As a result, United States petrochemical production continued to improve during 2011, producing increased marine transportation volumes for the movement of basic petrochemicals for both domestic consumers and terminals for export destinations.

The black oil products market, which contributed 20% of 2011 marine transportation revenues, also saw demand improve during 2011, driven by the continued steady refinery production levels, the export of heavy fuel oil, refinery maintenance activity, new demand for crude oil transportation from the Eagle Ford shale formations in South Texas and increased demand for the movement of Canadian crude oil downriver from the Midwest to the Gulf Coast.

The refined petroleum products market, which contributed 16% of 2011 marine transportation revenues, reflected continued lower demand for movements of products both inland and coastal, consistent with prevailing conditions in the United States economy, partially offset by an improvement of river ethanol volumes. K-Sea, which primarily transports refined petroleum, saw equipment utilization rates in the mid-to-high 70%, with the Atlantic, Pacific and Hawaii fleets experiencing higher rates, partially offset by lower utilization rates in New York harbor due to overcapacity of equipment in the bunkering markets.

The agricultural chemical market, which contributed 5% of 2011 marine transportation revenues, reflected an early Midwest spring fill in the first quarter, a very weak second quarter as the spring Midwest inventory fill was curtailed due to the heavy rain and flooding which reduced farmers’ ability to apply fertilizer, and a favorable fall fill late in the third quarter and during portions of the fourth quarter.

For 2011, the inland operations of the marine transportation segment incurred 6,777 delay days, 17% more than the 5,772 delay days that occurred during 2010. 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 and other navigational factors. The 2011 first quarter delay days reflected more severe winter weather conditions, including ice, fog and high water conditions during portions of the quarter. The 2011 second quarter experienced record high water and flooding throughout the Mississippi River System and a portion of the Gulf Intracoastal Waterway near Morgan City. The 2011 third and fourth quarters reflected more normal weather conditions and water levels. This compares with the 2010 quarters that experienced more normal weather conditions and water levels. The higher 2011 first and second quarter delay days led to increased operating expenses compared with the comparable quarters of 2010.

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During 2011 and 2010, approximately 75% of the marine transportation’s inland operations revenues were under term contracts and 25% were spot contract revenues. Inland operations time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented 55% of the revenues under term contracts during 2011 compared with 52% during 2010. The 75% term contract and 25% spot contract mix provides the marine transportation’s inland operations with a predictable revenue stream.

Since the acquisition of K-Sea on July 1, 2011, approximately 60% of the coastal operations marine transportation revenues were under term contracts and 40% were spot contract revenues. Coastal time charters represented approximately 90% of the revenues under term contracts during 2011.

Inland operations term contract rates renewed in the 2011 first quarter increased an average of 2% to 4% compared with term contract rate renewals in the first quarter of 2010. For the 2011 second quarter, term contracts renewed increased an average of 3% to 5% compared with term contract renewals in the second quarter of 2010. For the 2011 third quarter, term contracts renewed increased an average of 7% to 9% compared with term contract renewals in the third quarter of 2010. For the 2011 fourth quarter, term contracts renewed increased an average of 4% to 6% compared with term contract renewals in the fourth quarter of 2010. Spot contract rates in the 2011 first quarter, which include the cost of fuel, increased an average of 5% to 7% compared with the 2010 fourth quarter, while spot market rates for the second quarter increased an average of 7% to 9% compared with the 2011 first quarter, principally due to higher equipment utilization levels, improved volumes and the high water and flooding during the quarter. For the 2011 third quarter, spot contract rates increased an average of 9% to 11% compared with the 2011 second quarter, principally due to higher equipment utilization levels, improved volumes and pent-up demand, the result of water levels during the 2011 second quarter. For the 2011 fourth quarter, spot contract rates increased an average of 7% to 9% compared with the 2011 third quarter. Effective January 1, 2011, annual escalators for labor and the producer price index on a number of inland operation multi-year contracts resulted in rate increases on those contracts by 1% to 2%, excluding fuel.

For the coastal operations, term contracts renewed in the 2011 third and fourth quarters were relatively stable compared with contract rate renewals in the 2010 third and fourth quarters and spot contract rates during the 2011 third and fourth quarters improved in the 2% to 4% range compared with the 2011 prior quarters.

Marine Transportation Costs and Expenses

Costs and expenses for 2011 increased 29% compared with 2010. Costs of sales and operating expenses for 2011 increased 33% compared with 2010, partially reflecting the K-Sea acquisition, as well as higher costs and expenses due to improved inland operations demand and higher diesel fuel costs. In addition, unfavorable winter weather and operating conditions during the 2011 first quarter and high water and flooding throughout the Mississippi River System during the 2011 second quarter contributed to increased operating expenses for 2011.

The inland operations of the marine transportation segment operated an average of 240 towboats during 2011, of which an average of 61 were chartered, compared with 221 during 2010, of which an average of 53 were chartered. The 2011 average includes the 16 towboats and tugboats purchased in the Enterprise and Kinder Morgan acquisitions. The increase in the number of towboats operated was a reflection of the higher tank barge utilization levels in the petrochemical and black oil products markets during 2011 and additional towboats chartered during the 2011 second quarter due to the high water and flooding and restrictions placed on the industry regarding tow sizes and horsepower requirements, and assist towboat requirements at bridges, locks, certain sections of affected waterways and barge fleeting areas. As demand increases or decreases, 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 2011, the marine transportation segment consumed 54.0 million gallons of diesel fuel compared to 43.3 million gallons consumed during 2010. The average price per gallon of diesel fuel consumed during 2011

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was $3.10, an increase of 40% compared with $2.22 per gallon for 2010. Fuel escalation and de-escalation clauses 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 2011 increased 13% compared with 2010, reflecting the 2011 second half expenses of K-Sea, higher incentive compensation and the $1,252,000 severance charge associated with the integration of K-Sea into the Company. The 2010 year included a retirement and shore staff reduction charge of $2,724,000.

Depreciation and amortization for 2011 increased 25% compared with 2010. The increases were primarily attributable to the K-Sea acquisition, increased capital expenditures, including new inland tank barges and towboats, and the acquisition in February 2011 of 21 tank barges and 15 towboats and tugboats from Enterprise and one towboat from Kinder Morgan.

Marine Transportation Operating Income and Operating Margins

The marine transportation operating income for 2011 increased 36% compared with 2010. The 2011 operating margin was 21.9% compared with 21.1% for 2010. The higher operating income and operating margin were a reflection of higher inland tank barge utilization in the petrochemical and black oil products markets, and higher inland term and spot contract rates negotiated throughout 2011. In addition, the higher operating income reflected the operating income of K-Sea since the July 1, 2011 acquisition date. The 2011 operating margin was partially offset by a lower operating margin from K-Sea, the 2011 second quarter impact of the high water and flooding and $1,252,000 severance charge as discussed above.

2010 Compared with 2009

Marine Transportation Revenues

Marine transportation revenues for 2010 increased 4% compared with 2009, reflecting an improvement in tank barge demand and equipment utilization levels in the Company’s petrochemical and black oil markets, primarily due to the continued modest improvement in production volumes from United States petrochemical plants throughout 2010, and the export of diesel fuel and black oil products produced at United States refineries. In addition, diesel fuel prices for 2010 increased 29% compared with 2009, thereby positively impacting marine transportation revenues since fuel price increases are covered by fuel escalation and de-escalation clauses in the Company’s term contracts.

The petrochemical market, the Company’s largest market, contributed 69% of the marine transportation revenue for 2010. Throughout 2010, petrochemical transportation demand reflected a continued improvement in business levels. Lower priced domestic natural gas, a basic feedstock for the United States petrochemical industry, provided the industry with a competitive advantage against foreign petrochemical producers. As a result, United States petrochemical production improved as the 2010 year progressed, thereby producing increased marine transportation volumes for basic petrochemicals to both domestic consumers and terminals for export destinations. As a result of the higher volumes, the Company’s petrochemical tank barge fleet’s utilization level was in the high 80% range during the majority of 2010. The 2010 first quarter’s improvement in the utilization level was also attributable to supply chain disruptions caused by petrochemical turnarounds and unscheduled plant maintenance. The black oil products market, which contributed 18% of 2010 marine transportation revenue, saw lower utilization of the fleet, as well as a heavy shipyard maintenance cycle for black oil barges during the 2010 first half. During the 2010 second half, a heavy United States refinery maintenance schedule which required additional black oil shipments between refineries, coupled with the export of diesel fuel and heavy fuel oil, resulted in the Company’s black oil fleet maintaining a high 80% range utilization level. The refined petroleum products market, which contributed 8% of 2010 marine transportation revenue, reflected continued lower demand for movements of products, consistent with prevailing conditions in the United States economy, partially offset by an improvement of river ethanol volumes. The agricultural chemical market, which

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contributed 5% of 2010 marine transportation revenue, was weak during the first quarter due to high Midwest inventory levels, fueled by heavy rain and snow which reduced the farmer’s ability to apply fertilizer, improved in the second quarter with the Midwest spring fill, declined in the third quarter with a worldwide shortage of fertilizer and improved in the fourth quarter with a delayed fall fill.

For 2010, the marine transportation segment incurred 5,772 delay days, 11% more than the 5,201 delay days that occurred in 2009. 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 and other navigational factors. The higher 2010 delay days led to increased operating expenses compared with 2009. The 2010 delay days reflected more normal weather and lock conditions, including ice and high water conditions during portions of the first and second quarters and numerous delays from scheduled lock repairs during the third quarter. This compares with 2009 first nine months that experienced milder winter weather conditions and favorable water levels. Delay days for the 2010 fourth quarter were 17% below the 2009 fourth quarter, primarily due to favorable weather during the month of December.

During 2010, approximately 75% of marine transportation revenues were under term contracts and 25% were spot contract revenues, compared with 80% under term contracts and 20% under spot contracts during the 2009 first nine months. The percentage applicable to term contracts declined beginning in the fourth quarter of 2009 as certain customers switched to spot contracts, and in some cases, short-term charters when their term contracts expired. Time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented approximately 52% of the revenues under term contracts during 2010 compared with approximately 56% during 2009. The 75% to 80% term contract and 20% to 25% spot contract mix provides the Company with a predictable revenue stream.

Rates on term contracts, net of fuel, renewed in the 2010 first quarter generally decreased an average of approximately 10% when compared with term contract renewals in the first quarter of 2009. Rates on term contracts renewed in the 2010 second quarter were relatively flat with the 2010 first quarter renewals, but when compared with the 2009 second quarter declined an average of 10% to 12%. For the 2010 third and fourth quarters, term contract renewals were relatively flat with the 2010 first and second quarters, as well as relatively flat compared with the 2009 third and fourth quarters. Spot contract rates, which include the cost of fuel, for the 2010 first quarter were up an average of 3% to 6% when compared with the 2009 fourth quarter, but down an average of 15% to 25% compared with the 2009 first quarter. Spot contract rates for the 2010 second quarter were up an average of 2% to 3% compared with the 2010 first quarter, but when compared with the 2009 second quarter was down an average of 10% to 15%. Spot contract rates for the 2010 third and fourth quarters were relatively flat to slightly positive compared with the 2010 second quarter. Effective January 1, 2010, annual escalators for labor and the producer price index on a number of multi-year contracts were neutral.

Marine Transportation Costs and Expenses

Costs and expenses for 2010 increased 7% compared with 2009, primarily reflecting higher costs and expenses associated with increased marine transportation volumes and the 29% increase in diesel fuel prices noted below. Unfavorable winter and spring weather operating conditions during the 2010 first and second quarters and numerous lock repairs during the third quarter, compared with more favorable conditions during 2009 comparable quarters, increased operating expenses.

Costs of sales and operating expenses for 2010 increased 9% compared with 2009, reflecting higher expenses associated with the increased demand and higher fuel costs, partially offset by the positive impact of cost savings initiatives.

During 2010, the Company consumed 43.3 million gallons of diesel fuel compared to 41.8 million gallons consumed during 2009. The average price per gallon of diesel fuel consumed during 2010 was $2.22, an increase of 29% compared with $1.72 per gallon for 2009. The higher gallons consumed during 2010 reflected higher overall demand levels and more normal weather conditions during the year that required additional horsepower, compared with lower overall demand levels and milder weather conditions during 2009. Fuel escalation and

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de-escalation clauses 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 2010 were flat with 2009. Higher salaries for 2010, the result of salary increases, higher 2010 incentive compensation accruals and a higher provision for doubtful accounts, were offset by the reduced number of administrative personnel resulting from the 2009 and 2010 first quarter early retirement incentives and staff reductions. The 2010 year included an early retirement and shore staff reduction charge of $2,724,000 compared to a charge of $6,050,000 in 2009.

Taxes, other than on income, for 2010 increased 15% compared with 2009, primarily the reflection of higher waterway user taxes from increased mileage associated with improved demand on taxable waterways and higher property taxes.

Depreciation and amortization for 2010 increased 1% compared with 2009. The increase reflected the net changes of asset lives on certain equipment with revised accelerated tank barge retirement schedules and increased capital expenditures, including new tank barges and towboats.

Marine Transportation Operating Income and Operating Margins

The marine transportation operating income for 2010 decreased 7% compared with 2009. The 2010 operating margin was 21.1% compared with 23.6% for 2009. Both the lower operating income and lower operating margin were a reflection of lower term contract and spot contract rates negotiated throughout 2009 and the 2010 first half due to recessionary pressure and resulting industry-wide lower demand, higher fuel costs, and increased delay days during 2010, partially offset by the cost reduction initiatives implemented during 2009 and 2010 and decreased charges for early retirements and staff reductions.

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 oilfield service equipment, including hydraulic fracturing equipment. 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 years ended December 31, 2011 (dollars in thousands):

	2011			2010			% Change 2010 to 2011			2009			% Change 2009 to 2010
Diesel engine services revenues	$	655,810		$	194,511			237	%	$	200,860			(3	)%
Costs and expenses:
Costs of sales and operating expenses		510,997			142,809			258			143,694			(1	)
Selling, general and administrative		63,764			26,131			144			30,440			(14	)
Taxes, other than on income		1,143			963			19			1,474			(35	)
Depreciation and amortization		11,801			4,055			191			4,247			(5	)
		587,705			173,958			238			179,855			(3	)
Operating income	$	68,105		$	20,553			231	%	$	21,005			(2	)%
Operating margins		10.4	%		10.6	%					10.5	%

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2011 Compared with 2010

Diesel Engine Services Revenues

Diesel engine services revenues for 2011 increased 237% compared with 2010, primarily attributable to the United acquisition on April 15, 2011. United generated 69% of the segment’s revenue for 2011, benefiting from the strong demand for the manufacture and service of hydraulic fracturing equipment to meet the increased North American shale formation drilling activity, as well as sale and service of transmissions and diesel engines, and manufacture of compression systems. In addition, the increase in 2011 diesel engine services revenues reflected a stronger medium-speed power generation market with engine-generator set upgrade projects and higher parts and engine sales, and an improved inland marine market. Partially offsetting the increased revenue were continued weak service levels and direct parts sales in the Gulf Coast oil services market as customers continued to defer major maintenance projects. The 2011 second quarter was negatively impacted by the closure of the segment’s Paducah, Kentucky facility due to the flooding of the Ohio River during portions of May and June 2011.

Diesel Engine Services Costs and Expenses

Costs and expenses for 2011 increased 238% compared with 2010. The significant increase in each cost and expense category was primarily attributable to the United acquisition. In addition, the increase in costs of sales and operating expenses reflected the improved inland marine market, higher power generation engine-generator set upgrade projects and higher parts and engine sales.

Diesel Engine Services Operating Income and Operating Margins

Operating income for the diesel engine services segment for 2011 increased 231% compared with 2010, primarily reflecting the earnings from the United acquisition and the strong power generation market noted above. The operating margin for 2011 was 10.4% compared with 10.6%. The 2011 operating margin reflected higher than historical operating margin for United, primarily the result of the higher volume leverage.

2010 Compared with 2009

Diesel Engine Services Revenues

Diesel engine services revenues for 2010 decreased 3% compared with 2009, primarily reflecting continued weak service levels and direct parts sales in both the medium-speed and high-speed Gulf Coast oil services market where customers continue to defer major maintenance projects. During the 2010 second, third and fourth quarters, the Gulf Coast oil services market was further weakened by the Gulf of Mexico deep water drilling moratorium, new safety regulations on Gulf Coast drilling operators and the delays in issuing offshore drilling permits. In addition, the segment continued to experience pricing pressure in the high-speed Gulf Coast oil services market. The segment somewhat benefited from required repair work for customers involved in the Gulf Coast oil spill cleanup effort in the 2010 second and third quarters. Partially offsetting the weak 2010 marine markets was a stronger medium-speed power generation market, benefitting from additional engine-generator set upgrade projects and higher parts and engine sales. Both the 2010 and 2009 first quarters benefited from seasonal work for Midwest and Great Lakes marine medium-speed customers, and the 2010 fourth quarter benefited from a higher level of service overhauls for Midwest marine customers. The medium-speed railroad market for 2010 was in line with 2009.

Diesel Engine Services Costs and Expenses

Costs and expenses for 2010 decreased 3% compared with 2009. The 2009 costs and expenses included $2,342,000 of charges for early retirements and staff reductions applicable to the diesel engine services segment.

Cost of sales and operating expenses for 2010 decreased 1% compared with 2009, reflecting the costs and expenses associated with the lower marine market service and direct parts sales activity and cost savings from the

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2009 staff reductions, partially offset by the increased cost of stronger power generation engine-generator set upgrade projects, engine sales and higher direct parts sales. The 2009 expenses included $795,000 of early retirements and staff reduction charges.

Selling, general and administrative expenses for 2010 decreased 14% compared with 2009, reflecting the cost savings from the 2009 staff reductions. The 2009 expenses included $1,547,000 of early retirements and staff reduction charges.

Diesel Engine Services Operating Income and Operating Margins

Operating income for the diesel engine services segment for 2010 decreased 2% compared with 2009. The operating margin for 2010 was 10.6% compared with 10.5% for 2009. The 2009 operating income included $2,342,000 of early retirements and staff reduction charges. The 2010 operating income reflected the continued weak medium-speed and high-speed Gulf Coast oil services and inland marine markets, and some downward pressure on pricing in the high-speed marine market, partially offset by a strong power generation market, as well as the cost reduction initiatives implemented during 2009. The 2010 operating margin reflected the lower service and direct parts sales, some pricing pressure in the high-speed marine market and lower labor utilization, partially offset by the positive impact of the 2009 cost reduction initiatives. The 2009 operating income and operating margin was negatively impacted by the charges for early retirements and staff reductions noted above.

General Corporate Expenses

General corporate expenses for 2011, 2010 and 2009 were $17,915,000, $13,189,000 and $12,239,000, respectively. The 36% increase for 2011 compared with 2010 included legal, investment banking and transaction expenditures associated with the 2011 acquisitions of United and K-Sea as disclosed above. The 2010 year included a $1,088,000 first quarter charge for retirements and staff reductions.

Impairment of Goodwill

During the 2009 fourth quarter, the Company took a $1,901,000 charge for the partial impairment of the goodwill recorded for Osprey. The partial impairment reflected the reduced profitability outlook of the container-on-barge operations due to the economic environment at that time.

Gain (Loss) on Disposition of Assets

The Company reported a net loss on disposition of assets of $40,000 in 2011 and $78,000 in 2010 compared with a net gain on disposition of assets of $1,079,000 in 2009. The net gains and loss were predominantly from the sale of retired marine equipment.

Other Income and Expenses

The following table sets forth equity in earnings of affiliates, other income (expense), noncontrolling interests and interest expense for the three years ended December 31, 2011 (dollars in thousands):

	2011			2010			% Change 2010 to 2011			2009			% Change 2009 to 2010
Equity in earnings of affiliates	$	347		$	283			23	%	$	874			(68	)%
Other income (expense)		(41	)		273			(115	)%		(266	)		203	%
Noncontrolling interests		(2,466	)		(1,133	)		118	%		(1,597	)		(29	)%
Interest expense		(17,902	)		(10,960	)		63	%		(11,080	)		(1	)%

Equity in Earnings of Affiliates

Equity in earnings of affiliates consisted of the Company’s 50% ownership of a barge fleeting operation.

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Noncontrolling Interests

Noncontrolling interests for 2011 increased 118% compared with 2010, primarily the result of the purchase in February 2011 of a 51% interest in Kinder Morgan’s shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel. Kinder Morgan retained the remaining 49% interest.

Interest Expense

Interest expense for 2011 increased 63% compared with 2010, primarily the result of borrowings under the revolving credit facility to finance the United acquisition and the $540,000,000 term loan to finance the K-Sea acquisition. During 2011, 2010 and 2009, the average debt and average interest rate, including the effect of interest rate swaps, were $518,303,000 and 3.4%, $200,194,000 and 5.5%, and $215,500,000 and 5.1%, respectively.

Financial Condition, Capital Resources and Liquidity

Balance Sheet

Total assets at December 31, 2011 were $2,960,411,000 compared with $1,794,937,000 at December 31, 2010 and $1,635,963,000 at December 31, 2009. The December 31, 2011 total assets reflected the acquisition in December 2011 of the Seaboats fleet for $42,745,000 in cash, the purchase in July 2011 of K-Sea for $603,427,000 in cash and the issuance of Company common stock, the purchase in April 2011 of United for $271,192,000 in cash plus an earnout provision payable in 2014 and the purchase in February 2011 of tank barges, towboats and tugboats from Enterprise for $53,200,000 in cash, all more fully described under Acquisitions above. The following table sets forth the significant components of the balance sheet as of December 31, 2011 compared with 2010 and 2010 compared with 2009 (dollars in thousands):

	2011		2010		% Change 2010 to 2011			2009		% Change 2009 to 2010
Assets:
Current assets	$	529,329	$	425,915		24	%	$	300,097		42	%
Property and equipment, net		1,822,173		1,118,161		63			1,085,057		2
Investment in affiliates		3,682		3,336		10			3,052		9
Goodwill, net		483,468		228,873		111			228,873		—
Other assets		121,759		18,652		553			18,884		(1	)
	$	2,960,411	$	1,794,937		65	%	$	1,635,963		10	%
Liabilities and stockholders’ equity:
Current liabilities	$	358,800	$	160,259		124	%	$	137,104		17	%
Long-term debt-less current portion		763,000		200,006		281			200,204		—
Deferred income taxes		292,355		231,775		26			200,397		16
Other long-term liabilities		92,098		43,758		110			42,163		4
Total equity		1,454,158		1,159,139		25			1,056,095		10
	$	2,960,411	$	1,794,937		65	%	$	1,635,963		10	%

2011 Compared with 2010

Current assets as of December 31, 2011 increased 24% compared with current assets as of December 31, 2010. Cash and cash equivalents decreased 92% compared with December 31, 2010, reflecting the use of existing cash for the purchase of the tank barges, towboats and tugboats from Enterprise and the use of cash for a portion of the purchase of United. Trade accounts receivable increased 107%, primarily reflecting the acquisitions of K-Sea and United, as well as higher revenues from the inland operations of the marine transportation segment, partially associated with the pass through to marine transportation customers of higher fuel costs as fuel is escalated and de-escalated through revenue adjustment clauses in customers’ term contracts, or the customer

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pays for the fuel. Inventory in the diesel engine services segment increased 235%, reflecting the inventory acquired with the United acquisition and building of inventories at United to meet current business activity levels, partially offset by lower inventory levels associated with the continued weak marine oil services market. Prepaid expenses and other current assets increased 97%, primarily attributable to an increase in prepaid fuel due to higher fuel prices for the marine transportation segment and an increase in prepaid insurance premiums primarily attributable to the United and K-Sea acquisitions. Deferred income taxes increased 121% primarily due to the acquisition of K-Sea and United.

Property and equipment, net of accumulated depreciation, at December 31, 2011 increased 63% compared with December 31, 2010. The increase reflected $226,238,000 of capital expenditures for 2011, more fully described under Capital Expenditures below, the fair value of the property and equipment acquired in acquisitions of $607,344,000, and the purchase of a towboat from Kinder Morgan for $1,250,000, less $118,276,000 of depreciation expense for 2011 and $12,544,000 of property disposals during 2011.

Goodwill as of December 31, 2011 increased 111% compared with December 31, 2010, predominately reflecting the goodwill recorded in the K-Sea, United, Enterprise and Kinder Morgan acquisitions.

Other assets as of December 31, 2011 increased 553% compared with December 31, 2010, primarily reflecting other assets acquired in acquisitions, including intangible assets other than goodwill.

Current liabilities as of December 31, 2011 increased 124% compared with December 31, 2010, primarily reflecting the current liabilities of K-Sea and United. The current portion of long-term debt at December 31, 2011 reflects the classification of $39,000,000 of the term loan as current. Accounts payable increased 123%, a reflection of the K-Sea and United acquisitions, as well as higher voyage and charter boat expenditures associated with higher business activity levels in the marine transportation segment. Accrued liabilities increased 58%, the majority of which was attributable to the K-Sea and United acquisitions. The 240% increase in deferred revenues primarily reflected the United and K-Sea acquisitions.

Long-term debt, less current portion, as of December 31, 2011 increased 281% compared with December 31, 2010, primarily reflecting the borrowings under the Company’s revolving credit facility in April 2011 to finance the United acquisition and the $540,000,000 term loan facility in July 2011 to finance the K-Sea acquisition, less payments on the revolving credit facility and the term loan.

Deferred income taxes as of December 31, 2011 increased 26% compared with December 31, 2010. The increase was primarily due to the 2011 deferred income tax provision of $70,004,000. The deferred tax provision was primarily due to bonus tax depreciation on qualifying expenditures due to the Tax Relief Act that provided 100% bonus tax depreciation for capital investments placed in service after September 8, 2010 through December 31, 2011.

Other long-term liabilities as of December 31, 2011 increased 110% compared with December 31, 2010, primarily reflecting the fair value of the earnout provision related to the United acquisition and pension plan accruals.

Total equity as of December 31, 2011 increased 25% compared with December 31, 2010. The increase was the result of $183,026,000 of net earnings attributable to Kirby for 2011, a $5,460,000 decrease in treasury stock, a $22,534,000 decrease in accumulated other comprehensive income (“OCI”), stock issued with a fair value of $113,019,000 in connection with the acquisition of K-Sea and a $8,593,000 increase in noncontrolling interests. The decrease in treasury stock was attributable to the exercise of stock options and the issuance of restricted stock. The decrease 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 increase in unrecognized losses related to the Company’s defined benefit plans. The increase in noncontrolling interests reflected the purchase in February 2011 of a 51% interest in a shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel from Kinder Morgan and a 50% interest in a coastal tank barge acquired as part of the K-Sea acquisition.

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2010 Compared with 2009

Current assets as of December 31, 2010 increased 42% compared with December 31, 2009, primarily reflecting a 100% increase in cash and cash equivalents. Trade accounts receivable increased 10%, primarily a reflection of higher 2010 fourth quarter marine transportation revenues when compared with the 2009 fourth quarter, partially associated with the pass through to customers of higher diesel fuel costs as fuel is escalated and de-escalated through revenue adjustment clauses in customers’ term contracts, or the customer pays for the fuel. Other accounts receivable increased 193%, predominately due to a federal income tax receivable as of December 31, 2010 of $11,138,000, the result of the late 2010 enactment of the Small Business Act that included a one-year extension of 50% bonus tax depreciation on qualified property. This extension was granted after the Company made three quarterly estimated tax payments based on the assumption that bonus tax depreciation would not be extended and, as a result, the Company overpaid its 2010 estimated federal income taxes. In addition, the Tax Relief Act that was signed on December 17, 2010 provides 100% bonus tax depreciation for capital investments placed in service after September 8, 2010 through December 31, 2011. For equipment placed in service after December 31, 2011 and through December 31, 2012, the bill provides for 50% bonus tax depreciation. Finished goods inventory decreased 2% due primarily to the continued reduction of diesel engine services inventory levels associated with the weaker business levels in the marine market. Prepaid expenses and other current assets increased 14%, primarily due to an increase in prepaid fuel due to higher fuel prices in the 2010 fourth quarter compared with the 2009 fourth quarter.

Property and equipment, net of accumulated depreciation, at December 31, 2010 increased 3% compared with December 31, 2009. The increase reflected $136,841,000 of capital expenditures for 2010, more fully described under Capital Expenditures below, less $93,299,000 of depreciation expense for 2010 and $10,438,000 of property disposals during 2010.

Current liabilities as of December 31, 2010 increased 17% compared with December 31, 2009. Accounts payable increased 37%, a reflection of the increased marine transportation and diesel engine services business activity levels during the 2010 fourth quarter and higher shipyard accruals. Accrued liabilities increased 10%, primarily from higher employee incentive compensation accruals and property tax accruals, partially offset by payment of severance accrued in the 2009 fourth quarter.

Long-term debt, less current portion, as of December 31, 2010 was in line with December 31, 2009, as the Company had no outstanding balance under its $250,000,000 revolving credit facility during 2010.

Deferred income taxes as of December 31, 2010 increased 16% compared with December 31, 2009. The increase was primarily due to the 2010 deferred tax provision of $34,439,000, which included bonus tax depreciation on qualifying expenditures due to the late 2010 enactments of the extensions of bonus tax depreciation as noted above.

Other long-term liabilities as of December 31, 2010 increased 4% compared with December 31, 2009, primarily reflecting increased pension plan accruals, and the recording of a $1,477,000 increased liability in the fair value of derivative instruments, more fully described under Fair Value of Derivative Instruments below.

Total equity as of December 31, 2010 increased 10% compared with December 31, 2009. The increase was the result of $116,249,000 of net earnings attributable to Kirby for 2010, a decrease of $3,174,000 in accumulated OCI and an increase in treasury stock of $16,729,000. The decrease in accumulated OCI primarily resulted from the net change in fair value of derivative instruments, net of taxes, more fully described under Fair Value of Derivative Instruments below and the increase in unrecognized losses related to the Company’s defined benefit plans. The increase in treasury stock was attributable to purchases during 2010 of $23,793,000 of Company common stock, partially offset by the exercise of stock options and the issuance of restricted stock during 2010.

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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 pension contribution for the 2011 and 2010 years were $27,500,000 and $11,900,000, respectively. The Company’s contribution of $27,500,000 in December 2011 resulted in funding 97% of the pension plan’s ABO at December 31, 2011. The fair value of plan assets was $174,223,000 and $152,696,000 at December 31, 2011 and December 31, 2010, respectively.

The Company’s investment strategy focuses on total return on invested assets (capital appreciation plus dividend and interest income). The primary objective in the investment management of assets is to achieve long-term growth of principal while avoiding excessive risk. Risk is managed through diversification of investments within and among asset classes, as well as by choosing securities that have an established trading and underlying operating history.

The Company makes various assumptions when determining defined benefit plan costs including, but not limited to, the current discount rate and the expected long-term return on plan assets. Discount rates are determined annually and are based on a yield curve that consists of a hypothetical portfolio of high quality corporate bonds with maturities matching the projected benefit cash flows. The Company assumed that plan assets would generate a long-term rate of return of 7.5% in 2011 and 2010. The Company developed its expected long-term rate of return assumption by evaluating input from investment consultants and comparing historical returns for various asset classes with its actual and targeted plan investments. The Company believes that long-term asset allocation, on average, will approximate the targeted allocation.

Long-Term Financing

On May 31, 2011, the Company entered into 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 was funded on July 1, 2011 to provide financing for the K-Sea acquisition. The Term Loan provided for a $540,000,000 five-year unsecured term loan facility with a variable interest rate based on the London Interbank Offered Rate (“LIBOR”) or an Alternate Base Rate calculated with reference to the agent bank’s prime rate, among other factors. 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 December 31, 2011, the Company was in compliance with all Term Loan covenants and had $507,000,000 outstanding under the Term Loan, $39,000,000 of which was classified as current portion of long-term debt.

The Company has a $250,000,000 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 Revolving Credit Facility allows for an increase in the commitments of the banks from $250,000,000 up to a maximum of $325,000,000, subject to the consent of each bank that elects to participate in the increased commitment. On May 31, 2011, the Revolving Credit Facility was amended to conform the interest rate spread to the spread provided in the Term Loan described above. The variable interest rate spread is currently 1.5% over LIBOR or 0.5% over the Alternate Base Rate. Prior to the May 31, 2011 amendment, the variable interest rate spread was 2.0% over LIBOR for LIBOR loans and 0.5% over the Alternate Base Rate for Alternate Base Rate loans. The commitment fee is currently 0.3%. The Revolving Credit Facility contains certain

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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 December 31, 2011, the Company was in compliance with all Revolving Credit Facility covenants and had $95,000,000 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 $2,440,000 as of December 31, 2011.

The Company has $200,000,000 of unsecured floating rate senior notes (“Senior Notes”) due February 28, 2013. The Senior Notes pay interest quarterly at a rate equal to LIBOR plus a margin of 0.5%. The Senior Notes are callable, at the Company’s option, at par. No principal payments are required until maturity in February 2013. The Company was in compliance with all Senior Notes covenants at December 31, 2011.

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 30, 2012. 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 did not have any borrowings outstanding under the Credit Line as of December 31, 2011. Outstanding letters of credit under the Credit Line were $4,093,000 as of December 31, 2011.

Interest Rate Risk Management

From time to time, the Company has utilized and expects to continue to utilize 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. Derivative financial instruments related to the Company’s interest rate risks are intended to reduce the Company’s exposure to increases in the benchmark interest rates underlying the Company’s floating rate senior notes, variable rate term loan and variable rate bank revolving credit facility.

From time to time, the Company hedges its exposure to fluctuations in short-term interest rates under its variable rate bank revolving credit facility and floating rate senior notes by entering into interest rate swap agreements. The interest rate swap agreements are designated as cash flow hedges, therefore, the changes in fair value, to the extent the swap agreements are effective, are recognized in OCI until the hedged interest expense is recognized in earnings. The current swap agreements effectively convert the Company’s interest rate obligation on the Company’s variable rate senior notes from quarterly floating rate payments based on LIBOR to quarterly fixed rate payments. As of December 31, 2011, the Company had a total notional amount of $200,000,000 of interest rate swaps designated as cash flow hedges for its variable rate senior notes as follows (dollars in thousands):

Notional Amount	Effective date	Termination date		Fixed pay rate			Receive rate
$100,000	March 2006		February 2013		5.45	%	Three-month LIBOR
$50,000	November 2008		February 2013		3.50	%	Three-month LIBOR
$50,000	May 2009		February 2013		3.795	%	Three-month LIBOR

Foreign Currency Risk Management

From time to time, the Company has utilized and expects to continue to utilize 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

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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 December 31, 2011, the Company had forward contracts with notional amounts aggregating $5,406,000 to hedge its exposure to foreign currency rate fluctuations in expected foreign currency transactions. These contracts expire on various dates beginning in the first quarter of 2012 and ending in the first quarter of 2014. These forward contracts are designated as cash flow hedges, therefore, the changes in fair value, to the extent the forward contracts are effective, are recognized in OCI until the forward contracts expire and are 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 December 31, 2011 and 2010 (in thousands):

Liability Derivatives	Balance Sheet Location	2011		2010
Derivatives designated as hedging instruments under ASC 815:
Foreign currency contracts	Other accrued liabilities	$	363	$	798
Foreign currency contracts	Other long-term liabilities		32		569
Interest rate contracts	Other long-term liabilities		9,202		16,209
Total derivatives designated as hedging instruments under ASC 815		$	9,597	$	17,576
Total liability derivatives		$	9,597	$	17,576

Fair value amounts were derived as of December 31, 2011 and 2010 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 in Note 4, 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 years ended December 31, 2011, 2010 and 2009 (in thousands):

Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)
		2011		2010			2009
Interest rate contracts	Interest expense	$	7,007	$	(908	)	$	5,701
Foreign exchange contracts	Cost of sales and operating expenses		929		(1,419	)		(51	)
Total		$	7,936	$	(2,327	)	$	5,650

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Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
		2011			2010			2009
Interest rate contracts	Interest expense	$	(8,586	)	$	(8,529	)	$	(7,356	)
Foreign exchange contracts	Cost of sales and operating expenses		(13	)		(411	)		—
Total		$	(8,599	)	$	(8,940	)	$	(7,356	)

The Company anticipates $4,781,000 of net losses on interest rate swap agreements included in accumulated OCI will be transferred into earnings over the next year based on current interest rates. Gains or losses on interest rate swap agreements offset increases or decreases in rates of the underlying debt, which results in a fixed rate for the underlying debt. The Company also expects $211,000 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.

Capital Expenditures

Capital expenditures for 2011 were $226,238,000 of which $114,703,000 was for construction of inland tank barges and towboats, $33,335,000 for progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units scheduled for completion in the fourth quarter of 2012, and $78,200,000 was primarily for upgrading of the existing inland and coastal marine transportation fleets. Capital expenditures for 2010 were $136,841,000 of which $74,265,000 was for construction of inland tank barges and towboats, and $62,576,000 was primarily for upgrading of the existing marine transportation fleet. Capital expenditures for 2009 were $192,660,000 of which $142,384,000 was for construction of inland tank barges and towboats, and $50,276,000 was primarily for upgrading of the existing marine transportation fleet. Financing of the construction of the inland tank barges and towboats and dry-bulk barges and tugboats was through operating cash flows and available credit under the Company’s Revolving Credit Facility.

During 2011, the Company took delivery of 40 inland tank barges with a total capacity of 1,100,000 barrels and one inland towboat. During 2011, the Company retired 66 inland tank barges, reducing its capacity by approximately 1,250,000 barrels.

The Company projects that capital expenditures for 2012 will be in the $255,000,000 to $265,000,000 range. Based on current commitments, steel prices and projected delivery schedules, the Company’s 2012 new construction capital expenditures of approximately $100,000,000 will consist of 55 new tank barges with a total capacity of 1,000,000 barrels and five inland towboats and approximately $70,000,000 in progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units for delivery in the 2012 fourth quarter with an estimated total cost of $52,000,000 for each unit. The balance of approximately $85,000,000 to $95,000,000 is primarily capital upgrades and improvements to existing marine equipment and marine transportation and diesel engine services facilities.

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 2011. During 2010, the Company purchased 618,000 shares of its common stock for $23,793,000, for an average price per share of $38.48. The common stock was purchased through a combination of discretionary purchases and purchases pursuant to a stock trading plan entered into with a brokerage firm pursuant to Rule 10b5-1 under the Securities and Exchange Act of 1934. The Company’s Board of Directors on July 27, 2010 authorized the repurchase of an additional 2,000,000 shares of its common stock. As of February 22, 2012, the Company had 1,685,000 shares available under its existing

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repurchase authorization. Historically, treasury stock purchases have been financed through operating cash flows and borrowings 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 $311,995,000, $245,246,000 and $319,885,000 for the years ended December 31, 2011, 2010 and 2009, respectively. The 2011 year experienced a net decrease in cash flows from changes in operating assets and liabilities of $79,618,000 primarily due to larger increases in trade accounts receivable and inventory from stronger business activity levels in 2011 versus 2010 and a pension contribution of $27,500,000 in December 2011. The 2010 year experienced a net decrease in cash flows from changes in operating assets and liabilities of $12,518,000, primarily due to increased receivables from stronger business activities levels and a federal income tax receivable as of December 31, 2010 of $11,138,000, the result of the Small Business Act that included a one-year extension of 50% bonus tax depreciation on qualified property. This extension was made after the Company made three quarterly 2010 estimated tax payments based on the assumption that bonus tax depreciation would not be extended and, as a result, the Company overpaid its 2010 estimated federal income taxes. In addition, the Tax Relief Act that was signed on December 17, 2010 provides 100% bonus tax depreciation for capital investments placed in service after September 8, 2010 through December 31, 2011. For equipment placed in service after December 31, 2011 and through December 31, 2012, the bill provides for 50% bonus tax depreciation. This compares with a net increase in cash flows from changes in operating assets and liabilities in the 2009 year of $47,360,000, primarily due to a decrease in receivables during 2009, the result of decreased revenues due to weaker business activity levels. Also impacting 2010 was a pension contribution of $11,900,000 versus none in 2009.

Funds generated 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 February 21, 2012, $175,953,000 under its Revolving Credit Facility and $5,837,000 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 $250,000,000 and expires November 9, 2015. As of December 31, 2011, the Company had $155,000,000 available under the Revolving Credit Facility. The Revolving Credit Facility also allows for an increase in the commitments from the banks from the current $250,000,000 level up to a maximum of $325,000,000, subject to the consent of each bank that elects to participate in the increased commitment. Based on current economic conditions and credit market volatility, there is no guarantee that the participating banks would elect to increase the commitment, and if they did, the terms may be less favorable than the current Revolving Credit Facility. The Senior Notes do not mature until February 2013 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. While the Company has no current plans to access the private placement bond market, should the Company decide to do so in the near term, the terms, size and cost of a new debt issue could be less favorable than our current debt agreements.

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Current market conditions also elevate the concern over counterparty risks related to the Company’s interest rate swap agreements used to hedge the Company’s exposure to fluctuating interest rates and the Company’s forward contracts used to hedge the Company’s exposure to fluctuating foreign currency rates. The counterparties to these contracts are large multinational banks. The Company may not realize the benefit of some of its hedges should one of these financial counterparties not perform.

There are numerous factors that may negatively impact the Company’s cash flow in 2012. For a list of significant risks and uncertainties that could impact cash flows, see Note 13, Contingencies and Commitments in the financial statements, and Item 1A — Risk Factors. 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 in Note 6, Long-Term Debt in the financial statements.

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 is $26,329,000 at December 31, 2011, including $9,260,000 in letters of credit and debt guarantees, and $17,069,000 in performance bonds. All of these instruments have an expiration date within three 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.

All 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.

Contractual Obligations

The contractual obligations of the Company and its subsidiaries at December 31, 2011 consisted of the following (in thousands):

	Payments Due By Period
	Total		Less Than 1 Year		1-3 Years		4-5 Years		After 5 Years
Long-term debt	$	802,005	$	39,005	$	356,000	$	407,000	$	—
Non-cancelable operating leases — barges		115,510		20,151		35,309		26,604		33,446
Non-cancelable operating leases — towing vessels		104,027		52,888		39,011		12,128		—
Non-cancelable operating leases — land, buildings and equipment		32,436		7,164		11,278		7,616		6,378
Barge and towing vessel construction contracts		164,775		164,775		—		—		—
	$	1,218,753	$	283,983	$	441,598	$	453,348	$	39,824

57

The majority of the towboat charter agreements are for terms of one year or less. The Company’s towboat rental agreements provide the Company with the option to terminate most agreements with notice ranging from seven to 90 days. The Company estimates that 80% of the charter rental cost is related to towboat crew costs, maintenance and insurance.

Accounting Standards

In September 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2011-08, “Testing Goodwill for Impairment.” ASU 2011-08 amends the guidance in ASC 350-20, “Intangibles — Goodwill and Other — Goodwill.” Under ASU 2011-08, entities have the option of performing a qualitative assessment before calculating the fair value of the reporting unit when testing goodwill for impairment. If the fair value of the reporting unit is determined, based on qualitative factors, to be more likely than not less than the carrying amount of the reporting unit, then entities are required to perform the two-step goodwill impairment test. This ASU is effective for goodwill impairment tests performed in interim and annual periods for fiscal years beginning after December 15, 2011, with early adoption permitted. The Company adopted the provisions of this ASU for its 2011 goodwill impairment testing with no impact on its consolidated financial statements.

In June 2011, the FASB issued ASU 2011-05, “Comprehensive Income (Topic 220): Presentation of Comprehensive Income.” ASU 2011-05 requires entities to present components of comprehensive income in either a single continuous statement of comprehensive income or two separate but consecutive statements that would include reclassification adjustments for items that are reclassified from OCI to net income on the face of the financial statements. This ASU is effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. The adoption of ASU 2011-05 will not have a material impact on the Company’s consolidated financial statements.

In December 2011, the FASB issued ASU 2011-12, “Comprehensive Income (Topic 220): Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05” (“ASU 2011-12”). The amendments to the Codification in ASU 2011-12 are effective at the same time as the amendments in ASU 2011-05, so that entities will not be required to comply with the presentation requirements in ASU 2011-05 that ASU 2011-12 is deferring. The amendments are being made to allow the FASB time to reevaluate whether to present on the face of the financial statements the effects of reclassifications out of accumulated OCI on the components of net income and OCI for all periods presented. ASU 2011-12 will be effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. The adoption of ASU 2011-12 will not have a material impact on the Company’s consolidated financial statements.

Item 7A. 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 2012 interest expense by $180,000 based on balances outstanding at December 31, 2011, and would change the fair value of the Company’s debt by less than 1%.

Interest Rate Risk Management

From time to time, the Company has utilized and expects to continue to utilize 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. Derivative financial instruments related to the Company’s interest rate risks are intended to reduce the Company’s exposure to increases in the benchmark interest rates underlying the Company’s floating rate senior notes, variable rate term loan and variable rate bank revolving credit facility.

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From time to time, the Company hedges its exposure to fluctuations in short-term interest rates under its variable rate bank revolving credit facility and floating rate senior notes by entering into interest rate swap agreements. The interest rate swap agreements are designated as cash flow hedges, therefore, the changes in fair value, to the extent the swap agreements are effective, are recognized in other OCI until the hedged interest expense is recognized in earnings. The current swap agreements effectively convert the Company’s interest rate obligation on the Company’s variable rate senior notes from quarterly floating rate payments based on LIBOR to quarterly fixed rate payments. As of December 31, 2011, the Company had a total notional amount of $200,000,000 of interest rate swaps designated as cash flow hedges for its variable rate senior notes as follows (dollars in thousands):

Notional Amount	Effective date	Termination date	Fixed pay rate			Receive rate
$100,000	March 2006	February 2013		5.45	%	Three-month LIBOR
$50,000	November 2008	February 2013		3.50	%	Three-month LIBOR
$50,000	May 2009	February 2013		3.795	%	Three-month LIBOR

Foreign Currency Risk Management

From time to time, the Company has utilized and expects to continue to utilize 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 December 31, 2011, the Company had forward contracts with notional amounts aggregating $5,406,000 to hedge its exposure to foreign currency rate fluctuations in expected foreign currency transactions. These contracts expire on various dates beginning in the first quarter of 2012 and ending in the first quarter of 2014. These forward contracts are designated as cash flow hedges, therefore, the changes in fair value, to the extent the forward contracts are effective, are recognized in OCI until the forward contracts expire and are 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 December 31, 2011 and 2010 (in thousands):

Liability Derivatives	Balance Sheet Location	2011		2010
Derivatives designated as hedging instruments under ASC 815:
Foreign currency contracts	Other accrued liabilities	$	363	$	798
Foreign currency contracts	Other long-term liabilities		32		569
Interest rate contracts	Other long-term liabilities		9,202		16,209
Total derivatives designated as hedging instruments under ASC 815		$	9,597	$	17,576
Total liability derivatives		$	9,597	$	17,576

Fair value amounts were derived as of December 31, 2011 and December 31, 2010 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 in Note 4, Fair Value Measurements.

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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 years ended December 31, 2011, 2010 and 2009 (in thousands):

Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	7,007		$	(908	)	$	5,701
Foreign exchange contracts		Cost of sales and operating expenses		929			(1,419	)		(51	)
Total			$	7,936		$	(2,327	)	$	5,650
Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	(8,586	)	$	(8,529	)	$	(7,356	)
Foreign exchange contracts		Cost of sales and operating expenses		(13	)		(411	)		—
Total			$	(8,599	)	$	(8,940	)	$	(7,356	)

The Company anticipates $4,781,000 of net losses on interest rate swap agreements included in accumulated OCI will be transferred into earnings over the next year based on current interest rates. Gains or losses on interest rate swap agreements offset increases or decreases in rates of the underlying debt, which results in a fixed rate for the underlying debt. The Company also expects $211,000 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.

Item 8. Financial Statements and Supplementary Data

The response to this item is submitted as a separate section of this report (see Item 15, page 100).

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

Not applicable.

Item 9A. Controls and Procedures

Disclosure 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 December 31, 2011. Based on that evaluation, the Chief Executive Officer and the Chief Financial Officer concluded that, as of December 31, 2011, 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.

60

Management’s Report on Internal Control Over Financial Reporting. Management of the Company is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act). The Company’s management, with the participation of the Chief Executive Officer and the Chief Financial Officer, evaluated the effectiveness of the Company’s internal control over financial reporting as of December 31, 2011 using the framework in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on that evaluation, management concluded that the Company’s internal control over financial reporting was effective as of December 31, 2011. KPMG LLP, the Company’s independent registered public accounting firm, has audited the Company’s internal control over financial reporting, as stated in their report which is included herein.

There were no changes in the Company’s internal control over financial reporting during the quarter ended December 31, 2011 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

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PART III

Items 10 Through 14.

The information for these items is incorporated by reference to the definitive proxy statement filed by the Company with the Commission pursuant to Regulation 14A within 120 days of the close of the fiscal year ended December 31, 2011, except for the information regarding executive officers which is provided under Item 1.

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Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders of Kirby Corporation:

We have audited Kirby Corporation and consolidated subsidiaries’ internal control over financial reporting as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Kirby Corporation’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, Kirby Corporation maintained, in all material respects, effective internal control over financial reporting as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Kirby Corporation and consolidated subsidiaries as of December 31, 2011 and 2010, and the related consolidated statements of earnings, stockholders’ equity and comprehensive income, and cash flows for each of the years in the three-year period ended December 31, 2011, and our report dated February 28, 2012 expressed an unqualified opinion on those consolidated financial statements.

KPMG LLP

Houston, Texas

February 28, 2012

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Report of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders of Kirby Corporation:

We have audited the accompanying consolidated balance sheets of Kirby Corporation and consolidated subsidiaries as of December 31, 2011 and 2010, and the related consolidated statements of earnings, stockholders’ equity and comprehensive income, and cash flows for each of the years in the three-year period ended December 31, 2011. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Kirby Corporation and consolidated subsidiaries as of December 31, 2011 and 2010, and the results of their operations and their cash flows for each of the years in the three-year period ended December 31, 2011, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Kirby Corporation’s internal control over financial reporting as of December 31, 2011, based on criteria established in Internal Control — Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 28, 2012 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

KPMG LLP

Houston, Texas

February 28, 2012

64

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

December 31, 2011 and 2010

	2011			2010
	($ in thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	16,249		$	195,600
Accounts receivable:
Trade — less allowance for doubtful accounts of $5,007 ($4,000 in 2010)		303,087			146,359
Other		32,060			21,612
Inventories — net, at lower of average cost or market		130,130			38,821
Prepaid expenses and other current assets		33,617			17,105
Deferred income taxes		14,186			6,418
Total current assets		529,329			425,915
Property and equipment:
Marine transportation equipment		2,466,506			1,748,488
Land, buildings and equipment		151,762			113,823
		2,618,268			1,862,311
Accumulated depreciation		796,095			744,150
Property and equipment — net		1,822,173			1,118,161
Investment in affiliates		3,682			3,336
Goodwill — net		483,468			228,873
Other assets		121,759			18,652
Total assets	$	2,960,411		$	1,794,937
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Current portion of long-term debt	$	39,005		$	128
Income taxes payable		4,124			3,065
Accounts payable		158,855			71,354
Accrued liabilities:
Interest		1,168			1,006
Insurance premiums and claims		45,817			24,416
Employee compensation		42,706			30,582
Taxes — other than on income		9,972			7,550
Other		17,599			10,525
Deferred revenues		39,554			11,633
Total current liabilities		358,800			160,259
Long-term debt — less current portion		763,000			200,006
Deferred income taxes		292,355			231,775
Other long-term liabilities		92,098			43,758
Total long-term liabilities		1,147,453			475,539
Contingencies and commitments		—			—
Equity:
Kirby stockholders’ equity:
Common stock, $.10 par value per share. Authorized 120,000,000 shares, issued 59,276,000 shares		5,928			5,734
Additional paid-in capital		357,294			237,014
Accumulated other comprehensive income — net		(56,176	)		(33,642	)
Retained earnings		1,229,641			1,046,615
Treasury stock — at cost, 3,532,000 shares in 2011 and 3,780,000 in 2010		(94,162	)		(99,622	)
Total Kirby stockholders’ equity		1,442,525			1,156,099
Noncontrolling interests		11,633			3,040
Total equity		1,454,158			1,159,139
Total liabilities and equity	$	2,960,411		$	1,794,937

See accompanying notes to consolidated financial statements.

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KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF EARNINGS

For the Years Ended December 31, 2011, 2010 and 2009

	2011			2010			2009
	($ in thousands, except per share amounts)
Revenues:
Marine transportation	$	1,194,607		$	915,046		$	881,298
Diesel engine services		655,810			194,511			200,860
Total revenues		1,850,417			1,109,557			1,082,158
Costs and expenses:
Costs of sales and operating expenses		1,228,440			683,236			637,833
Selling, general and administrative		170,386			117,694			121,401
Taxes, other than on income		13,179			13,209			12,104
Depreciation and amortization		126,029			95,296			93,968
Impairment of goodwill		—			—			1,901
Loss (gain) on disposition of assets		40			78			(1,079	)
Total costs and expenses		1,538,074			909,513			866,128
Operating income		312,343			200,044			216,030
Equity in earnings of affiliates		347			283			874
Other income (expense)		(41	)		273			(266	)
Interest expense		(17,902	)		(10,960	)		(11,080	)
Earnings before taxes on income		294,747			189,640			205,558
Provision for taxes on income		(109,255	)		(72,258	)		(78,020	)
Net earnings		185,492			117,382			127,538
Less: Net earnings attributable to noncontrolling interests		(2,466	)		(1,133	)		(1,597	)
Net earnings attributable to Kirby	$	183,026		$	116,249		$	125,941
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.35		$	2.16		$	2.34
Diluted	$	3.33		$	2.15		$	2.34

See accompanying notes to consolidated financial statements.

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KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY AND

COMPREHENSIVE INCOME

For the Years Ended December 31, 2011, 2010 and 2009

	2011			2010			2009
	($ in thousands)
Common stock:
Balance at beginning of year	$	5,734		$	5,734		$	5,734
Issuance of shares in acquisition		194			—			—
Balance at end of year	$	5,928		$	5,734		$	5,734
Additional paid-in capital:
Balance at beginning of year	$	237,014		$	229,724		$	225,718
Issuance of shares in acquisition		112,825			—			—
Excess (deficit) of proceeds received upon exercise of stock options and issuance of restricted stock over cost of treasury stock issued		4,359			3,140			(349	)
Tax benefit realized from equity compensation plans		1,348			373			1,013
Issuance of restricted stock, net of forfeitures		(7,480	)		(7,090	)		(6,513	)
Amortization of unearned compensation		9,228			10,867			9,855
Balance at end of year	$	357,294		$	237,014		$	229,724
Accumulated other comprehensive income:
Balance at beginning of year	$	(33,642	)	$	(30,468	)	$	(55,047	)
Change in defined benefit plans’ minimum liabilities, net of taxes ($16,994 in 2011, $1,028 in 2010 and $(12,962) in 2009)		(27,383	)		(1,654	)		20,903
Change in fair value of derivative financial instruments, net of taxes (($2,915) in 2011, $986 in 2010 and $(1,974) in 2009)		5,199			(1,520	)		3,676
Foreign currency translation loss		(350	)		—			—
Balance at end of year	$	(56,176	)	$	(33,642	)	$	(30,468	)
Retained earnings:
Balance at beginning of year	$	1,046,615		$	930,366		$	804,425
Net earnings attributable to Kirby for the year		183,026			116,249			125,941
Balance at end of year	$	1,229,641		$	1,046,615		$	930,366
Treasury stock:
Balance at beginning of year	$	(99,622	)	$	(82,893	)	$	(90,777	)
Purchase of treasury stock (618,000 in 2010 and 20,000 shares in 2009)		—			(23,793	)		(657	)
Cost of treasury stock issued upon exercise of stock options and issuance of restricted stock (248,000 in 2011, 338,000 in 2010 and 368,000 in 2009)		5,460			7,064			8,541
Balance at end of year	$	(94,162	)	$	(99,622	)	$	(82,893	)
Noncontrolling interests:
Balance at beginning of year	$	3,040		$	3,632		$	3,502
Net earnings attributable to noncontrolling interests		2,466			1,133			1,597
Return of investment to noncontrolling interests		(2,115	)		(1,794	)		(1,782	)
Proceeds from noncontrolling interest investments		268			69			315
Acquisition of noncontrolling interests		7,974			—			—
Balance at the end of year	$	11,633		$	3,040		$	3,632
Comprehensive income:
Net earnings	$	185,492		$	117,382		$	127,538
Other comprehensive income (loss), net of taxes ($14,079 in 2011, $2,013 in 2010 and $(14,936) in 2009)		(22,534	)		(3,174	)		24,579
Total comprehensive income	$	162,958		$	114,208		$	152,117

See accompanying notes to consolidated financial statements.

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KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

For the Years Ended December 31, 2011, 2010 and 2009

	2011			2010			2009
	($ in thousands)
Cash flows from operating activities:
Net earnings	$	185,492		$	117,382		$	127,538
Adjustments to reconcile net earnings to net cash provided by operations:
Depreciation and amortization		126,029			95,296			93,968
Provision (credit) for doubtful accounts		266			(15	)		(1,104	)
Provision for deferred income taxes		70,004			34,439			42,424
Loss (gain) on disposition of assets		40			78			(1,079	)
Equity in earnings of affiliates		(347	)		(283	)		(874	)
Amortization of unearned share-based compensation		9,228			10,867			9,855
Impairment of goodwill		—			—			1,901
Other		901			—			(104	)
Increase (decrease) in cash flows resulting from changes in:
Accounts receivable		(58,351	)		(17,563	)		59,083
Inventory		(26,355	)		973			8,724
Other assets		(7,247	)		(2,511	)		(1,585	)
Income taxes payable		3,026			(13,284	)		3,557
Accounts payable		21,492			19,262			(25,929	)
Accrued and other liabilities		(12,183	)		605			3,510
Net cash provided by operating activities		311,995			245,246			319,885
Cash flows from investing activities:
Capital expenditures		(226,238	)		(136,841	)		(192,660	)
Acquisitions of businesses and marine equipment, net of cash acquired		(859,512	)		—			—
Proceeds from disposition of assets		11,821			9,725			7,388
Retirement of interest rate swaps assumed in acquisition		(14,803	)		—			—
Net cash used in investing activities		(1,088,732	)		(127,116	)		(185,272	)
Cash flows from financing activities:
Borrowings on long-term debt		531,646			—			—
Borrowings (payments) on bank credit facilities, net		95,000			—			(46,000	)
Payments on long-term debt, net		(33,128	)		(105	)		(1,087	)
Return of investment to noncontrolling interests		(2,115	)		(1,794	)		(1,782	)
Proceeds from noncontrolling interest investments		268			69			315
Proceeds from exercise of stock options		4,367			4,884			2,774
Purchase of treasury stock		—			(23,793	)		(657	)
Excess tax benefit from equity compensation plans		1,348			373			1,013
Net cash provided by (used in) financing activities		597,386			(20,366	)		(45,424	)
Increase (decrease) in cash and cash equivalents		(179,351	)		97,764			89,189
Cash and cash equivalents, beginning of year		195,600			97,836			8,647
Cash and cash equivalents, end of year	$	16,249		$	195,600		$	97,836
Supplemental disclosures of cash flow information:
Cash paid during the year:
Interest	$	16,455		$	10,604		$	10,899
Income taxes	$	34,926		$	50,743		$	31,005
Noncash investing activity:
Stock issued in acquisition	$	113,019		$	—		$	—
Cash acquired in acquisition	$	4,044		$	—		$	—
Disposition of assets for receivables	$	682		$	1,569		$	934

See accompanying notes to consolidated financial statements.

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KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(1) Summary of Significant Accounting Policies

Principles of Consolidation. The consolidated financial statements include the accounts of Kirby Corporation and all majority-owned subsidiaries (“the Company”). Two affiliated limited partnerships, in which the Company owns a 50% interest, is the general partner and has effective control and whose activities are an integral part of the operations of the Company, are consolidated. All other investments in which the Company owns 20% to 50% and exercises significant influence over operating and financial policies are accounted for using the equity method. All material intercompany accounts and transactions have been eliminated in consolidation. Certain reclassifications have been made to reflect the current presentation of financial information.

Accounting Policies

Cash Equivalents. Cash equivalents consist of all short-term, highly liquid investments with maturities of three months or less at date of purchase.

Accounts Receivable. In the normal course of business, the Company extends credit to its customers. The Company regularly reviews the accounts and makes adequate provisions for probable uncollectible balances. It is the Company’s opinion that the accounts have no impairment, other than that for which provisions have been made. Included in accounts receivable as of December 31, 2011 and 2010 were $53,083,000 and $24,626,000, respectively, of accruals for revenues earned which have not been invoiced as of the end of each year.

The Company’s marine transportation and diesel engine services operations are subject to hazards associated with such businesses. The Company maintains insurance coverage against these hazards with insurance companies. Included in accounts receivable as of December 31, 2011 and 2010 were $15,530,000 and $3,453,000, respectively, of receivables from insurance companies to cover claims in excess of the Company’s deductible.

Concentrations of Credit Risk. Financial instruments which potentially subject the Company to concentrations of credit risk are primarily trade accounts receivables. The Company’s marine transportation customers include the major oil refining and petrochemical companies. The diesel engine services customers are oil and gas service companies, marine transportation companies, commercial fishing companies, power generation companies, and the United States government. The Company regularly reviews its accounts and estimates the amount of uncollectible receivables each period and establishes an allowance for uncollectible amounts. The amount of the allowance is based on the age of unpaid amounts, information about the current financial strength of customers, and other relevant information. Estimates of uncollectible amounts are revised each period, and changes are recorded in the period they become known.

Fair Value of Financial Instruments. Cash, accounts receivable, accounts payable and accrued liabilities have carrying values that approximate fair value due to the short-term maturity of these financial instruments. The fair value of the Company’s debt instruments is more fully described in Note 6, Long-Term Debt.

Property, Maintenance and Repairs. Property is recorded at cost. Improvements and betterments are capitalized as incurred. Depreciation is recorded on the straight-line method over the estimated useful lives of the individual assets as follows: marine transportation equipment, 5-40 years; buildings, 10-40 years; other equipment, 2-10 years; and leasehold improvements, term of lease. When property items are retired, sold or otherwise disposed of, the related cost and accumulated depreciation are removed from the accounts with any gain or loss on the disposition included in the statement of earnings. Maintenance and repairs on vessels built for use on the inland waterways are charged to operating expense as incurred and includes the costs incurred in United States Coast Guard (“USCG”) inspections unless the shipyard extends the life or improves the operating capacity of the vessel which results in the costs being capitalized.

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Drydocking on Ocean-Going Vessels. The Company’s ocean-going vessels are subject to regulatory drydocking requirements after certain periods of time to be inspected, have planned major maintenance performed and be recertified by the American Bureau of Shipping (“ABS”). These recertifications generally occur twice in a five year period. The Company defers the drydocking expenditures incurred on its ocean-going vessels due to regulatory marine inspections by the ABS and amortizes the costs of the shipyard over the period between drydockings, generally 30 months, unless the drydocking extends the life or improves the operating capability of the vessels which results in the costs being capitalized. Routine repairs and maintenance on ocean-going vessels are expensed as incurred.

Environmental Liabilities. The Company expenses costs related to environmental events as they are incurred or when a loss is considered probable and estimable.

Goodwill. The excess of the purchase price over the fair value of identifiable net assets acquired in transactions accounted for as a purchase is included in goodwill. The Company conducted its annual goodwill impairment test at November 30, 2011 and 2010. For 2011 and 2010, the Company noted no impairment of goodwill. The Company will continue to conduct goodwill impairment tests as of November 30 of subsequent years, or whenever events or circumstances indicate that interim impairment testing is necessary. The gross carrying value of goodwill at December 31, 2011 and 2010 was $500,935,000 and $246,340,000, respectively, and accumulated amortization at December 31, 2011 and 2010 was $15,566,000. Accumulated impairment losses were $1,901,000 at December 31, 2011 and 2010.

Net goodwill for the marine transportation segment was $276,163,000 and $153,870,000 at December 31, 2011 and 2010, respectively. Net goodwill for the diesel engine services segment was $207,305,000 and $75,003,000 at December 31, 2011 and 2010, respectively.

Revenue Recognition. The majority of marine transportation revenue is derived from term contracts, ranging from one to five years, some of which have renewal options, and the remainder is from spot market movements. The majority of the term contracts are for terms of one year. The Company is a provider of marine transportation services for its customers and, in almost all cases, does not assume ownership of the products it transports. A term contract is an agreement with a specific customer to transport cargo from a designated origin to a designated destination at a set rate or at a daily rate. The rate may or may not escalate during the term of the contract, however, the base rate generally remains constant and contracts often include escalation provisions to recover changes in specific costs such as fuel. A spot contract is an agreement with a customer to move cargo from a specific origin to a designated destination for a rate negotiated at the time the cargo movement takes place. Spot contract rates are at the current “market” rate, including fuel, and are subject to market volatility. The Company uses a voyage accounting method of revenue recognition for its marine transportation revenues which allocates voyage revenue based on the percent of the voyage completed during the period. There is no difference in the recognition of revenue between a term contract and a spot contract.

Diesel engine service products and services are generally sold based upon purchase orders or preferential service agreements with the customer that include fixed or determinable prices and that do not include right of return or significant post delivery performance obligations. Diesel engine parts sales are recognized when title passes upon shipment to customers or when customer-specific acceptance requirements are met. Service revenue is recognized as the service is provided. Diesel manufacturing and assembly projects revenue is reported on the percentage of completion method of accounting using measurements of progress towards completion appropriate for the work performed.

Stock-Based Compensation. The Company has share-based compensation plans covering selected officers and other key employees as well as the Company’s Board of Directors. Stock-based grants made under the Company’s stock plans are recorded at fair value on the date of the grant and the cost is recognized ratably over the vesting period of the stock option or restricted stock. Stock option grants are valued at the date of grant as calculated under the Black-Scholes option pricing model. The Company’s stock-based compensation plans are more fully described in Note 9, Stock Award Plans.

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Taxes on Income. The Company follows the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

Accrued Insurance. Accrued insurance liabilities include estimates based on individual incurred claims outstanding and an estimated amount for losses incurred but not reported (“IBNR”) or fully developed based on past experience. Insurance premiums, IBNR losses and incurred claim losses, up to the Company’s deductible, for 2011, 2010 and 2009 were $18,673,000, $13,461,000 and $12,786,000, respectively.

Noncontrolling Interests. The Company has a majority interest in and is the general partner in several affiliated entities. In situations where losses applicable to the minority interest in the affiliated entities exceed the limited partners’ equity capital, such excess and any further loss attributable to the minority interest is charged against the Company’s interest in the affiliated entities. If future earnings materialize in the respective affiliated entities, the Company’s interest would be credited to the extent of any losses previously absorbed.

Treasury Stock. The Company follows the average cost method of accounting for treasury stock transactions.

Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of. The Company reviews long-lived assets and certain identifiable intangibles for impairment by vessel class whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable.

Recoverability on marine transportation assets is assessed based on vessel classes, not on individual assets, because identifiable cash flows for individual marine transportation assets are not available. Projecting customer contract volumes allows estimation of future cash flows by projecting pricing and utilization by vessel class but it is not practical to project which individual marine transportation asset will be utilized for any given contract. Because customers do not specify which particular vessel is used, prices are quoted based on vessel classes not individual assets. Nominations of vessels for specific jobs are determined on a day by day basis and are a function of the equipment class required and the geographic position of vessels within that class at that particular time as vessels within a class are interchangeable and provide the same service. The Company’s vessels are mobile assets and equipped to operate in geographic regions throughout the United States and the Company has in the past and expects to continue to move vessels from one region to another when it is necessary due to changing markets and it is economical to do so. Barge vessel classes are based on similar capacities, hull type, and type of product and towing vessels are based on similar hull type and horsepower. Recoverability of the vessel classes is measured by a comparison of the carrying amount of the assets to future net cash flows expected to be generated by the assets. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs to sell.

Accounting Standards

In September 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2011-08, “Testing Goodwill for Impairment.” ASU 2011-08 amends the guidance in ASC 350-20, “Intangibles – Goodwill and Other – Goodwill.” Under ASU 2011-08, entities have the option of performing a qualitative assessment before calculating the fair value of the reporting unit when testing goodwill for impairment. If the fair value of the reporting unit is determined, based on qualitative factors, to be more likely than not less than the carrying amount of the reporting unit, then entities are required to perform the two-step goodwill impairment test. This ASU is effective for goodwill impairment tests performed in interim and annual periods for fiscal years

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beginning after December 15, 2011, with early adoption permitted. The Company adopted the provisions of this ASU for its 2011 goodwill impairment testing with no impact on its consolidated financial statements.

In June 2011, the FASB issued ASU 2011-05, “Comprehensive Income (Topic 220): Presentation of Comprehensive Income.” ASU 2011-05 requires entities to present components of comprehensive income in either a single continuous statement of comprehensive income or two separate but consecutive statements that would include reclassification adjustments for items that are reclassified from other comprehensive income (“OCI”) to net income on the face of the financial statements. This ASU is effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. The adoption of ASU 2011-05 will not have a material impact on the Company’s consolidated financial statements.

In December 2011, the FASB issued ASU 2011-12, “Comprehensive Income (Topic 220): Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05” (“ASU 2011-12”). The amendments to the Codification in ASU 2011-12 are effective at the same time as the amendments in ASU 2011-05, so that entities will not be required to comply with the presentation requirements in ASU 2011-05 that ASU 2011-12 is deferring. The amendments are being made to allow the FASB time to reevaluate whether to present on the face of the financial statements the effects of reclassifications out of accumulated OCI on the components of net income and OCI for all periods presented. ASU 2011-12 will be effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. The adoption of ASU 2011-12 will not have a material impact on the Company’s consolidated financial statements.

(2) Acquisitions

On December 15, 2011, the Company completed the purchase of the coastal tank barge fleet of Seaboats, Inc. and affiliated companies (“Seaboats”) consisting of three 80,000 barrel coastal tank barges and tugboats for $42,745,000 in cash. The three coastal tank barges and tugboats currently operate along the United States East Coast and have an average age of five years.

On July 1, 2011, the Company completed the acquisition of K-Sea Transportation Partners L.P. (“K-Sea”), an operator of tank barges and tugboats participating in the coastal transportation primarily of refined petroleum products in the United States. The total value of the transaction was $603,427,000, excluding transaction fees, consisting of $227,617,000 of cash paid to K-Sea common and preferred unit holders and the general partner, $262,791,000 of cash to retire K-Sea’s outstanding debt, and $113,019,000 through the issuance of 1,939,234 shares of Company common stock valued at $58.28 per share, the Company’s closing share price on July 1, 2011.

On the acquisition date, K-Sea’s fleet, comprised of 57 coastal tank barges with a capacity of 3.8 million barrels and 63 tugboats, operated along the East Coast, West Coast and Gulf Coast of the United States, as well as in Alaska and Hawaii. K-Sea’s tank barge fleet, 54 of which were double hulled and had an average age of approximately nine years, is one of the youngest fleets in the coastal trade. K-Sea’s customers include major oil companies and refiners, many of which are current Company customers for inland tank barge services. K-Sea has operating facilities in New York, Philadelphia, Seattle and Honolulu.

The Company considers K-Sea to be a natural extension of the current marine transportation segment, expanding into the coastal marine transportation business from the predominately inland based marine transportation business.

Total consideration transferred was as follows (in thousands):

Cash consideration paid	$	227,617
Cash to retire K-Sea’s outstanding debt		262,791
Stock consideration through issuance of Company common stock		113,019
Fair value of consideration transferred	$	603,427

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The fair values of the assets acquired and liabilities assumed recorded at the acquisition date were as follows (in thousands):

Assets:
Cash	$	4,044
Accounts receivable		40,013
Other current assets		8,881
Property and equipment		495,312
Goodwill		113,973
Deferred income taxes		3,439
Other assets		26,126
Total assets	$	691,788
Liabilities:
Accounts payable	$	27,279
Accrued liabilities		40,675
Deferred revenues		8,224
Other long-term liabilities		8,100
Non-controlling interests		4,083
Total liabilities	$	88,361
Net assets acquired	$	603,427

The analysis of the K-Sea fair values above is substantially complete but all fair values have not been finalized pending obtaining the information necessary to complete the analysis. Companies have one year after an acquisition to finalize acquisition accounting under current accounting rules.

As a result of the acquisition, the Company recorded $113,973,000 of goodwill and $11,400,000 of net intangibles. The net intangibles have a weighted average amortization period of approximately 11 years. The Company expects substantially all of the goodwill will be deductible for tax purposes. Acquisition and integration related costs of $5,353,000, consisting primarily of legal, audit and other professional fees plus other expenses, were expensed as incurred to selling, general and administrative expense in 2011.

On April 15, 2011, the Company purchased United Holdings LLC (“United”), a distributor and service provider of engine and transmission related products for the oil and gas services, power generation and on-highway transportation industries, and manufacturer of oilfield service equipment. The purchase price was $271,192,000 in cash, plus a three-year earnout provision for up to an additional $50,000,000 payable in 2014, dependent on achieving certain financial targets. United, headquartered in Oklahoma City, Oklahoma with 21 locations across seven states, distributes and services equipment and parts for Allison Transmission (“Allison”), MTU Detroit Diesel (“MTU”), Daimler Trucks NA (“Daimler”), and other diesel and natural gas engines. United also manufactures oilfield service equipment, including hydraulic fracturing equipment. United’s principal customers are oilfield service companies, oil and gas operators and producers, compression companies and on-highway transportation companies.

The Company considers United to be a natural extension of the current diesel engine services segment, expanding into the land-based diesel engines and transmissions service business, especially the pressure pumping and oilfield services market.

Total consideration transferred was as follows (in thousands):

Cash consideration paid	$	271,192
Fair value of contingent earnout provision payable in 2014		16,300
Fair value of consideration transferred	$	287,492

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The fair values of the assets acquired and liabilities assumed recorded at the acquisition date were as follows (in thousands):

Assets:
Accounts receivable	$	71,427
Inventories		64,680
Other current assets		1,246
Property and equipment		16,629
Goodwill		132,302
Other assets		75,864
Total assets	$	362,148
Liabilities:
Accounts payable	$	39,809
Accrued liabilities		7,202
Deferred revenues		27,331
Deferred income taxes		314
Total liabilities	$	74,656
Net assets acquired	$	287,492

The analysis of the United fair values above is substantially complete but all fair values have not been finalized pending obtaining the information necessary to complete the analysis. Companies have one year after an acquisition to finalize acquisition accounting under current accounting rules.

As a result of the acquisition, the Company recorded $132,302,000 of goodwill and $75,697,000 of intangibles. The intangibles have a weighted average amortization period of approximately 16 years. The Company expects substantially all of the goodwill will be deductible for tax purposes. Acquisition related costs of $760,000, consisting primarily of legal and audit fees and other expenses, were expensed as incurred to selling, general and administrative expense in 2011.

On February 24, 2011, the Company purchased 21 inland and offshore tank barges and 15 inland towboats and offshore tugboats from Enterprise Marine Services LLC (“Enterprise”) for $53,200,000 in cash. Enterprise provided transportation and delivery services for ship bunkers (engine fuel) to cruise ships, container ships and freighters primarily in the Miami, Port Everglades and Cape Canaveral, Florida area, the three largest cruise ship ports in the United States, as well as Tampa, Florida, Mobile, Alabama and Houston, Texas.

On February 9, 2011, the Company purchased from Kinder Morgan Petcoke, L.P. (“Kinder Morgan”) for $4,050,000 in cash a 51% interest in Kinder Morgan’s shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel. Kinder Morgan retained the remaining 49% interest and the Company will manage the operation. In addition, the Company purchased a towboat from Kinder Morgan for $1,250,000 in cash.

The following unaudited pro forma results present consolidated information as if the United and K-Sea acquisitions had been completed as of January 1, 2009. The pro forma results do not include the acquisitions of Seaboats, Enterprise and Kinder Morgan described above as the effect of these acquisitions would not be materially different from the Company’s actual results.

The pro forma results include the amortization associated with the acquired intangible assets, interest expense associated with the debt used to fund a portion of the acquisitions, the impact of the additional shares issued in connection with the K-Sea acquisition, the impact of certain fair value adjustments such as depreciation adjustments related to adjustments to property and equipment, elimination of K-Sea’s goodwill impairment charge in the second quarter of 2010, and standardization of accounting policies. The pro forma results do not include any cost savings or

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potential synergies related to the acquisitions nor any integration costs. The pro forma results should not be considered indicative of the results of operations or financial position of the combined companies had the acquisitions had been consummated as of January 1, 2009 and are not necessarily indicative of results of future operations of the Company.

The following table sets forth the Company’s pro forma revenues, net earnings attributable to Kirby, basic net earnings per share and fully diluted net earnings per share attributable to Kirby common stockholders for the years ended December 31, 2011, 2010 and 2009 (unaudited and in thousands, except per share amounts):

	2011 Pro forma		2010 Pro forma		2009 Pro forma
Revenues	$	2,105,904	$	1,685,173	$	1,554,806
Net earnings attributable to Kirby	$	172,426	$	123,981	$	138,726
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.10	$	2.22	$	2.49
Diluted	$	3.09	$	2.22	$	2.49

(3) Inventories

The following table presents the details of inventories as of December 31, 2011 and 2010 (in thousands):

	December 31, 2011		December 31, 2010
Finished goods	$	111,931	$	35,719
Work in process		18,199		3,102
	$	130,130	$	38,821

(4) 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 at December 31, 2011 and 2010 (in thousands):

	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
December 31, 2011:
Assets:
Derivatives	$	—	$	—	$	—	$	—
Liabilities:
Derivatives	$	—	$	9,597	$	—	$	9,597
Contingent earnout liability		—		—		22,600		22,600
	$	—	$	9,597	$	22,600	$	32,197

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	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
December 31, 2010:
Assets:
Derivatives	$	—	$	—	$	—	$	—
Liabilities:
Derivatives	$	—	$	17,576	$	—	$	17,576

The fair value of the Company’s derivative instruments is more fully described below in Note 5, Derivative Instruments.

In connection with the acquisition of 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 increase in the fair value of the earnout liability of $6,300,000 for 2011 was charged to selling, general and administrative expense. As of December 31, 2011, the Company had recorded an earnout liability of $22,600,000.

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. The Company is of the opinion that amounts included in the consolidated financial statements for outstanding debt materially represent the fair value of such debt due to their variable interest rates.

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 years ended December 31, 2011 and 2010, there was no indication that the Company’s long-lived assets were impaired, and accordingly, measurement at fair value was not required.

(5) 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. Special accounting for derivatives qualifying as fair value hedges allows a derivative’s gains and losses to offset related results on the hedged item in the statement of earnings. 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 and expects to continue to utilize 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. Derivative financial instruments related to the Company’s interest rate risks are intended to reduce the Company’s exposure to increases in the benchmark interest rates underlying the Company’s floating rate senior notes, variable rate term loan and variable rate bank revolving credit facility.

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From time to time, the Company hedges its exposure to fluctuations in short-term interest rates under its variable rate bank revolving credit facility and floating rate senior notes by entering into interest rate swap agreements. The interest rate swap agreements are designated as cash flow hedges, therefore, the changes in fair value, to the extent the swap agreements are effective, are recognized in OCI until the hedged interest expense is recognized in earnings. The current swap agreements effectively convert the Company’s interest rate obligation on the Company’s variable rate senior notes from quarterly floating rate payments based on the London Interbank Offered Rate (“LIBOR”) to quarterly fixed rate payments. As of December 31, 2011, the Company had a total notional amount of $200,000,000 of interest rate swaps designated as cash flow hedges for its variable rate senior notes as follows (dollars in thousands):

Notional Amount	Effective date	Termination date	Fixed pay rate			Receive rate
$100,000	March 2006	February 2013		5.45	%	Three-month LIBOR
$50,000	November 2008	February 2013		3.50	%	Three-month LIBOR
$50,000	May 2009	February 2013		3.795	%	Three-month LIBOR

Foreign Currency Risk Management

From time to time, the Company has utilized and expects to continue to utilize 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 December 31, 2011, the Company had forward contracts with notional amounts aggregating $5,406,000 to hedge its exposure to foreign currency rate fluctuations in expected foreign currency transactions. These contracts expire on various dates beginning in the first quarter of 2012 and ending in the first quarter of 2014. These forward contracts are designated as cash flow hedges, therefore, the changes in fair value, to the extent the forward contracts are effective, are recognized in OCI until the forward contracts expire and are 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 December 31, 2011 and 2010 (in thousands):

Liability Derivatives	Balance Sheet Location	2011		2010
Derivatives designated as hedging instruments under ASC 815:
Foreign currency contracts	Other accrued liabilities	$	363	$	798
Foreign currency contracts	Other long-term liabilities		32		569
Interest rate contracts	Other long-term liabilities		9,202		16,209
Total derivatives designated as hedging instruments under ASC 815		$	9,597	$	17,576
Total liability derivatives		$	9,597	$	17,576

Fair value amounts were derived as of December 31, 2011 and 2010 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 4, Fair Value Measurements.

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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 years ended December 31, 2011, 2010 and 2009 (in thousands):

Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	7,007		$	(908	)	$	5,701
Foreign exchange contracts		Cost of sales and operating expenses		929			(1,419	)		(51	)
Total			$	7,936		$	(2,327	)	$	5,650
Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	(8,586	)	$	(8,529	)	$	(7,356	)
Foreign exchange contracts		Cost of sales and operating expenses		(13	)		(411	)		—
Total			$	(8,599	)	$	(8,940	)	$	(7,356	)

The Company anticipates $4,781,000 of net losses on interest rate swap agreements included in accumulated OCI will be transferred into earnings over the next year based on current interest rates. Gains or losses on interest rate swap agreements offset increases or decreases in rates of the underlying debt, which results in a fixed rate for the underlying debt. The Company also expects $211,000 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.

(6) Long-Term Debt

Long-term debt at December 31, 2011 and 2010 consisted of the following (in thousands):

	2011		2010
Long-term debt, including current portion:
$540,000,000 term loan due May 31, 2016	$	507,000	$	—
$250,000,000 revolving credit facility due November 9, 2015		95,000		—
Senior notes due February 28, 2013		200,000		200,000
Other long-term debt		5		134
	$	802,005	$	200,134

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The aggregate payments due on the long-term debt in each of the next five years were as follows (in thousands):

2012	$	39,005
2013		265,000
2014		91,000
2015		199,000
2016		208,000
Thereafter		—
	$	802,005

On May 31, 2011, the Company entered into 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 a base rate calculated with reference to the agent bank’s prime rate, among other factors (the “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. The primary purpose of the Term Loan was to provide financing for the Company’s acquisition of K-Sea. The acquisition of K-Sea was completed and the Term Loan funded on July 1, 2011. As of December 31, 2011, the Company was in compliance with all Term Loan covenants and had $507,000,000 outstanding under the Term Loan, $39,000,000 of which was classified as current portion of long-term debt. The Term Loan’s average interest rate for 2011 was 1.8%, computed by dividing the interest expense under the Term Loan by the average Term Loan borrowings.

The Company has an 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 Revolving Credit Facility allows for an increase in the commitments of the banks from $250,000,000 up to a maximum of $325,000,000, subject to the consent of each bank that elects to participate in the increased commitment. On May 31, 2011, the Revolving Credit Facility was amended to conform the interest rate spread to the spread provided in the Term Loan described above. The unsecured Revolving Credit Facility has a variable interest rate based on LIBOR or an Alternate Base Rate. The variable interest rate spread varies with the Company’s senior debt rating. The variable interest rate spread is currently 1.5% over LIBOR for LIBOR loans and 0.5% over the Alternate Base Rate for Alternate Base Rate loans. 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 December 31, 2011, the Company was in compliance with all Revolving Credit Facility covenants and had $95,000,000 outstanding under the Revolving Credit Facility. The average borrowing under the Revolving Credit Facility during 2011 was $59,608,000, computed by averaging the daily balance, and the weighted average interest rate was 1.9%, computed by dividing the interest expense under the Revolving Credit Facility by the average Revolving Credit Facility borrowing. 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 $2,440,000 as of December 31, 2011.

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The Company has $200,000,000 of unsecured floating rate senior notes (“Senior Notes”) due February 28, 2013. The Senior Notes pay interest quarterly at a rate equal to LIBOR plus a margin of 0.5%. The Senior Notes are callable, at the Company’s option, at par. No principal payments are required until maturity in February 2013. As of December 31, 2011, $200,000,000 was outstanding under the Senior Notes and the 2011 average interest rate was 0.8%, computed by dividing the interest expense under the Senior Notes by the average Senior Notes borrowings of $200,000,000. The Company was in compliance with all Senior Notes covenants at December 31, 2011.

The Company has a $10,000,000 line of credit (“Credit Line”) with Bank of America, N.A. (“Bank of America”) for short-term liquidity needs and letters of credit with a maturity date of June 30, 2012. 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 did not have any borrowings outstanding under the Credit Line as of December 31, 2011. Outstanding letters of credit under the Credit Line were $4,093,000 as of December 31, 2011.

The Company is of the opinion that the amounts included in the consolidated financial statements for outstanding debt materially represent the fair value of such debt at December 31, 2011 and 2010 due to their variable interest rates.

(7) Taxes on Income

Earnings before taxes on income and details of the provision for taxes on income for the years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	2011		2010		2009
Earnings before taxes on income — United States	$	294,747	$	189,640	$	205,558
Provision for taxes on income:
Federal:
Current	$	33,640	$	33,014	$	30,443
Deferred		65,451		30,643		38,404
State and local		10,164		8,601		9,173
	$	109,255	$	72,258	$	78,020

During the three years ended December 31, 2011, 2010 and 2009, tax benefits related to the exercise of stock options and the issuance of restricted stock that were allocated directly to additional paid-in capital were $1,348,000, $373,000 and $1,013,000, respectively.

The Company’s provision for taxes on income varied from the statutory federal income tax rate for the years ended December 31, 2011, 2010 and 2009 due to the following:

	2011			2010			2009
United States income tax statutory rate		35.0	%		35.0	%		35.0	%
State and local taxes, net of federal benefit		2.2			2.9			2.9
Other – net		(.1	)		.2			.1
		37.1	%		38.1	%		38.0	%

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The tax effects of temporary differences that give rise to significant portions of the current deferred tax assets and non-current deferred tax assets and liabilities at December 31, 2011 and 2010 were as follows (in thousands):

	2011			2010
Current deferred tax assets:
Compensated absences	$	695		$	518
Allowance for doubtful accounts		1,752			1,400
Insurance accruals		4,150			2,319
Other		7,589			2,181
	$	14,186		$	6,418
Non-current deferred tax assets and liabilities:
Deferred tax assets:
Postretirement health care benefits	$	3,422		$	3,548
Insurance accruals		1,420			876
Deferred compensation		8,290			7,456
Unrealized loss on derivative financial instruments		3,384			6,162
Unrealized loss on defined benefit plans		28,114			12,582
Operating loss carryforwards		1,305			1,023
Other		9,047			9,177
		54,982			40,824
Deferred tax liabilities:
Property		(298,335	)		(234,732	)
Deferred state taxes		(25,738	)		(22,571	)
Pension benefits		(15,376	)		(8,738	)
Goodwill and other intangibles		(6,563	)		(5,538	)
Other		(1,325	)		(1,020	)
		(347,337	)		(272,599	)
	$	(292,355	)	$	(231,775	)

The Company has determined that it is more likely than not that all deferred tax assets at December 31, 2011 will be realized, including its operating loss carryforwards of $1,305,000 that expire in various amounts through 2030.

The Company or one of its subsidiaries files income tax returns in the United States federal jurisdiction and various state jurisdictions. The Company is currently open to audit under the statute of limitations by the Internal Revenue Service for the 2008 through 2010 tax years. With few exceptions, the Company and its subsidiaries’ state income tax returns are open to audit under the statute of limitations for the 2005 through 2010 tax years.

As of December 31, 2011, the Company has provided a liability of $2,509,000 for unrecognized tax benefits related to various income tax issues which includes interest and penalties. The amount that would impact the Company’s effective tax rate, if recognized, is $1,775,000, with the difference between the total amount of unrecognized tax benefits and the amount that would impact the effective tax rate being primarily related to the federal tax benefit of state income tax items. It is not reasonably possible to determine if the liability for unrecognized tax benefits will significantly change prior to December 31, 2012 due to the uncertainty of possible examination results.

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A reconciliation of the beginning and ending amount of the liability for unrecognized tax benefits for the years ended December 31, 2011, 2010 and 2009, is as follows (in thousands):

	2011			2010			2009
Balance at beginning of year	$	2,088		$	2,290		$	2,451
Additions based on tax positions related to the current year		602			279			417
Additions for tax positions of prior years		402			84			87
Reductions for tax positions of prior years		(738	)		(443	)		(665	)
Settlements		(822	)		(122	)		—
Balance at end of year	$	1,532		$	2,088		$	2,290

The Company accounts for interest and penalties related to uncertain tax positions as part of its provision for federal and state income taxes. The Company recognized net expense (income) of $16,000, $43,000 and $(221,000) in interest and penalties for the years ended December 31, 2011, 2010 and 2009, respectively. The Company had $977,000, $993,000 and $964,000 of accrued liabilities for the payment of interest and penalties at December 31, 2011, 2010 and 2009, respectively.

(8) Leases

The Company and its subsidiaries currently lease various facilities and equipment under a number of cancelable and noncancelable operating leases. Lease agreements for barges have terms from one to 10 years expiring at various dates through 2021. Lease agreements for towing vessels chartered by the Company have terms from 30 days to five years expiring at various dates through 2016; however, the majority of the towing vessel charter agreements are for terms of one year or less. Total rental expense for the years ended December 31, 2011, 2010 and 2009 was as follows (in thousands):

	2011		2010		2009
Rental expense:
Marine equipment — barges	$	16,396	$	9,075	$	9,489
Marine equipment — towing vessels		91,796		79,016		81,453
Other buildings and equipment		8,156		5,334		5,240
Rental expense	$	116,348	$	93,425	$	96,182

Future minimum lease payments under operating leases that have initial or remaining noncancelable lease terms in excess of one year at December 31, 2011 were as follows (in thousands):

	Land, Buildings and Equipment		Marine Equipment
			Barges		Towing Vessels		Total
2012	$	7,164	$	20,151	$	52,888	$	80,203
2013		6,168		18,587		23,020		47,775
2014		5,110		16,722		15,991		37,823
2015		4,857		15,065		9,094		29,016
2016		2,759		11,539		3,034		17,332
Thereafter		6,378		33,446		—		39,824
	$	32,436	$	115,510	$	104,027	$	251,973

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(9) 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 years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	2011		2010		2009
Compensation cost	$	9,228	$	10,867	$	9,855
Income tax benefit	$	3,534	$	4,162	$	3,775

The Company has two employee stock award plans for selected officers and other key employees which provide for the issuance of stock options and restricted stock. For both of the plans, 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 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. At December 31, 2011, 1,214,718 shares were available for future grants under the employee plans and no outstanding stock options under the employee plans were issued with stock appreciation rights.

The following is a summary of the stock option activity under the employee plans described above for the years ended December 31, 2011, 2010 and 2009:

	Outstanding Non-Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2008		514,181		$	35.28
Granted		228,246		$	23.98
Exercised		(101,944	)	$	21.86
Canceled or expired		—		$	—
Outstanding at December 31, 2009		640,483		$	33.39
Granted		103,999		$	32.60
Exercised		(228,543	)	$	28.36
Canceled or expired		(81,492	)	$	45.73
Outstanding at December 31, 2010		434,447		$	33.53
Granted		103,021		$	47.01
Exercised		(91,794	)	$	32.75
Canceled or expired		—		$	—
Outstanding at December 31, 2011		445,674		$	36.81

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Under the employee plans, stock options exercisable were 226,900, 200,210 and 262,488 at December 31, 2011, 2010 and 2009, respectively.

The following table summarizes information about the Company’s outstanding and exercisable stock options under the employee plans at December 31, 2011:

	Options Outstanding								Options Exercisable
Range of Exercise Prices	Number Outstanding		Weighted Average Remaining Contractual Life in Years		Weighted Average Exercise Price		Aggregated Intrinsic Value		Number Exercisable		Weighted Average Exercise Price		Aggregated Intrinsic Value
$23.98 — $32.56		226,450		3.4	$	27.72				113,364	$	26.47
$34.40 — $36.35		24,000		2.4	$	34.73				21,333	$	34.52
$46.74 — $58.28		195,224		3.7	$	47.61				92,203	$	48.28
$23.98 — $58.28		445,674		3.5	$	36.81	$	12,937,000		226,900	$	36.09	$	6,750,000

The following is a summary of the restricted stock award activity under the employee plans described above for the years ended December 31, 2011, 2010 and 2009:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2008		502,818		$	33.64
Granted		263,579		$	24.70
Vested		(207,106	)	$	36.60
Forfeited		(16,612	)	$	32.70
Nonvested balance at December 31, 2009		542,679		$	30.70
Granted		197,994		$	33.42
Vested		(234,831	)	$	39.34
Forfeited		(6,507	)	$	32.00
Nonvested balance at December 31, 2010		499,335		$	31.98
Granted		150,612		$	46.50
Vested		(163,480	)	$	33.27
Forfeited		(10,835	)	$	38.90
Nonvested balance at December 31, 2011		475,632		$	36.43

The Company has two director stock award plans for nonemployee directors of the Company which provide for the issuance of stock options and restricted stock. No additional options can be granted under one of the plans. The 2000 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 2000 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 plans 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 when first elected a director 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 December 31, 2011, 252,224 shares were available for future grants under the 2000 Director Plan. The director stock award plans are intended as an incentive to attract and retain qualified and competent independent directors.

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The following is a summary of the stock option activity under the director plans described above for the years ended December 31, 2011, 2010 and 2009:

	Outstanding Non-Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2008		309,572		$	30.94
Granted		50,433		$	29.60
Exercised		(46,068	)	$	11.85
Forfeited		(12,000	)	$	35.99
Outstanding at December 31, 2009		301,937		$	33.43
Granted		57,492		$	41.24
Exercised		(3,000	)	$	10.67
Outstanding at December 31, 2010		356,429		$	34.88
Granted		60,552		$	56.42
Exercised		(63,356	)	$	32.17
Outstanding at December 31, 2011		353,625		$	39.05

Under the director plans, options exercisable were 352,987, 355,555 and 301,328 at December 31, 2011, 2010 and 2009, respectively.

The following table summarizes information about the Company’s outstanding and exercisable stock options under the director plans at December 31, 2011:

	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
$12.69 — $17.88		45,814		1.4	$	15.78				45,814	$	15.78
$20.28 — $29.60		56,433		6.1	$	26.63				56,433	$	26.63
$35.17 — $36.82		86,036		4.7	$	35.88				86,036	$	35.88
$41.24 — $56.45		165,342		8.1	$	51.39				164,704	$	51.37
$12.69 — $56.45		353,625		6.1	$	39.05	$	9,473,000		352,987	$	39.02	$	9,467,000

The following is a summary of the restricted stock award activity under the director plan described above for the years ended December 31, 2011, 2010 and 2009:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2008		390		$	56.00
Granted		10,919		$	29.77
Vested		(10,577	)	$	30.74
Nonvested balance at December 31, 2009		732		$	29.77
Granted		11,097		$	41.33
Vested		(11,304	)	$	40.58
Nonvested balance at December 31, 2010		525		$	41.33
Granted		11,990		$	56.85
Vested		(10,767	)	$	55.90
Nonvested balance at December 31, 2011		1,748		$	58.07

85

The total intrinsic value of all stock options exercised under all of the Company’s plans was $4,072,000, $2,835,000 and $1,859,000 for the years ended December 31, 2011, 2010 and 2009, respectively. The actual tax benefit realized for tax deductions from stock option exercises was $1,560,000, $1,086,000 and $712,000 for the years ended December 31, 2011, 2010 and 2009, respectively.

The total intrinsic value of all the restricted stock vestings under all of the Company’s plans was $7,921,000, $8,809,000 and $5,931,000 for the years ended December 31, 2011, 2010 and 2009, respectively. The actual tax benefit realized for tax deductions from restricted stock vestings was $3,034,000, $3,374,000 and $2,271,000 for the years ended December 31, 2011, 2010 and 2009, respectively.

As of December 31, 2011, there was $1,695,000 of unrecognized compensation cost related to nonvested stock options and $12,038,000 related to restricted stock. The stock options are expected to be recognized over a weighted average period of approximately 1.4 years and restricted stock over approximately 2.7 years. The total fair value of stock options vested was $2,618,000, $3,491,000 and $2,763,000 during the years ended December 31, 2011, 2010 and 2009, respectively. The fair value of the restricted stock vested was $7,921,000, $8,809,000 and $5,931,000 for the years ended December 31, 2011, 2010 and 2009, respectively.

The weighted average per share fair value of stock options granted during the years ended December 31, 2011, 2010 and 2009 was $18.84, $13.81 and $8.15, respectively. The fair value of the stock options granted during the years ended December 31, 2011, 2010 and 2009 was $3,081,000, $2,231,000 and $2,271,000, 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 stock options during the years ended December 31, 2011, 2010 and 2009 were as follows:

	2011			2010			2009
Dividend yield		None			None			None
Average risk-free interest rate		2.4	%		3.1	%		1.9	%
Stock price volatility		33	%		33	%		33	%
Estimated option term		Six years or seven years			Six years or seven years			Four years or eight years

(10) 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 fair value of plan assets was $174,223,000 and $152,696,000 at December 31, 2011 and 2010, respectively. As of December 31, 2011 and 2010, these assets were allocated among asset categories as follows:

Asset Category	2011			2010			Current Minimum, Target and Maximum Allocation Policy
U.S. equity securities		43	%		50	%	30% — 50% — 70%
International equity securities		16	%		20	%	0% — 20% — 30%
Debt securities		25	%		29	%	15% — 30% — 55%
Cash and cash equivalents		16	%		1	%	0% — 0% — 5%
		100	%		100	%

The cash and cash equivalents asset category exceeded the maximum percentage allocation in 2011 due to the 2011 pension plan contribution of $27,500,000 being funded on the last day of 2011 which resulted in insufficient time to properly allocate the contribution among the asset categories. The Company allocated the contribution among the appropriate asset categories in January 2012.

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The plan assets are invested entirely in common collective trusts. These instruments are public investment vehicles valued using the net asset value provided by the administrator of the fund. The net asset value is classified within Level 2 of the valuation hierarchy as set forth in the accounting guidance for fair value measurements because the net asset value price is quoted on an inactive private market although the underlying investments are traded on an active market.

The Company’s investment strategy focuses on total return on invested assets (capital appreciation plus dividend and interest income). The primary objective in the investment management of assets is to achieve long-term growth of principal while avoiding excessive risk. Risk is managed through diversification of investments within and among asset classes, as well as by choosing securities that have an established trading and underlying operating history.

The Company makes various assumptions when determining defined benefit plan costs including, but not limited to, the current discount rate and the expected long-term return on plan assets. Discount rates are determined annually and are based on a yield curve that consists of a hypothetical portfolio of high quality corporate bonds with maturities matching the projected benefit cash flows. The Company assumed that plan assets would generate a long-term rate of return of 7.5% in 2011 and 2010. The Company developed its expected long-term rate of return assumption by evaluating input from investment consultants comparing historical returns for various asset classes with its actual and targeted plan investments. The Company believes that its long-term asset allocation, on average, will approximate the targeted allocation.

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. The Company’s contribution of $27,500,000 in December 2011 resulted in funding 97% of the pension plan’s ABO at December 31. 2011.

The Company sponsors an unfunded defined benefit health care plan that provides limited postretirement medical benefits to employees who met 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.

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The following table presents the change in benefit obligation and plan assets for the Company’s defined benefit plans and postretirement benefit plan (in thousands):

													Other Postretirement Benefits
	Pension Benefits												Postretirement Welfare Plan
	Pension Plan						SERP
	2011			2010			2011			2010			2011			2010
Change in benefit obligation
Benefit obligation at beginning of year	$	170,742		$	141,338		$	1,511		$	1,429		$	2,790		$	5,459
Service cost		7,303			6,883			—			—			—			—
Interest cost		9,693			9,399			80			84			164			154
Actuarial loss (gain)		33,662			17,124			157			101			182			(3,108	)
Plan amendments		—			—			—			—			—			519
Gross benefits paid		(4,474	)		(4,002	)		(103	)		(103	)		(122	)		(234	)
Benefit obligation at end of year	$	216,926		$	170,742		$	1,645		$	1,511		$	3,014		$	2,790
Accumulated benefit obligation at end of year	$	179,190		$	141,666		$	1,645		$	1,511		$	—		$	—
Weighted-average assumption used to determine benefit obligation at end of year
Discount rate		4.6	%		5.5	%		4.6	%		5.5	%		4.6	%		5.5	%
Rate of compensation increase		4.25	%		4.25	%		—			—			—			—
Health care cost trend rate
Initial rate		—			—			—			—			7.5	%		8.0	%
Ultimate rate		—			—			—			—			5.0	%		5.0	%
Years to ultimate		—			—			—			—			2017			2017
Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation
Increase	$	—		$	—		$	—		$	—		$	285		$	223
Decrease		—			—			—			—			(250	)		(196	)
Change in plan assets
Fair value of plan assets at beginning of year	$	152,696		$	126,490		$	—		$	—		$	—		$	—
Actual return on plan assets		(1,499	)		18,308			—			—			—			—
Employer contribution		27,500			11,900			103			103			122			234
Gross benefits paid		(4,474	)		(4,002	)		(103	)		(103	)		(122	)		(234	)
Fair value of plan assets at end of year	$	174,223		$	152,696		$	—		$	—		$	—		$	—

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The following table presents the funded status and amounts recognized in the Company’s consolidated balance sheet for the Company’s defined benefit plans and postretirement benefit plan at December 31, 2011 and 2010 (in thousands):

													Other Postretirement Benefits
	Pension Benefits												Postretirement
	Pension Plan						SERP						Welfare Plan
	2011			2010			2011			2010			2011			2010
Funded status at end of year
Fair value of plan assets	$	174,223		$	152,696		$	—		$	—		$	—		$	—
Benefit obligations		216,926			170,742			1,645			1,511			3,014			2,790
Funded status and amount recognized at end of year	$	(42,703	)	$	(18,046	)	$	(1,645	)	$	(1,511	)	$	(3,014	)	$	(2,790	)
Amounts recognized in the consolidated balance sheets
Current liability	$	—		$	—		$	(102	)	$	(102	)	$	(256	)	$	(246	)
Long-term liability		(42,703	)		(18,046	)		(1,543	)		(1,409	)		(2,758	)		(2,544	)
Amounts recognized in accumulated other comprehensive income
Net actuarial loss (gain)	$	86,633		$	43,048		$	442		$	293		$	(6,751	)	$	(7,523	)
Prior service cost (credit)		—			(38	)		—			—			—			158
Accumulated other compensation income	$	86,633		$	43,010		$	442		$	293		$	(6,751	)	$	(7,365	)

The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets at December 31, 2011 and 2010 were as follows (in thousands):

	Pension Benefits
	Pension Plan				SERP
	2011		2010		2011		2010
Projected benefit obligation in excess of plan assets
Projected benefit obligation at end of year	$	216,926	$	170,742	$	1,645	$	1,511
Fair value of plan assets at end of year		174,223		152,696		—		—

The projected benefit obligation, accumulated benefit obligation and fair value of plan assets for pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2011 and 2010 were as follows (in thousands):

	Pension Benefits
	Pension Plan				SERP
	2011		2010		2011		2010
Accumulated benefit obligation in excess of plan assets
Projected benefit obligation at end of year	$	216,926	$	—	$	1,645	$	1,511
Accumulated benefit obligation at end of year		179,190		—		1,645		1,511
Fair value of plan assets at end of year		174,223		—		—		—

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The following tables presents the expected cash flows for the Company’s defined benefit plans and postretirement benefit plan at December 31, 2011 and 2010 (in thousands):

									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011			2010
Expected employer contributions
First year	$	11,800	$	—	$	102	$	102	$	256		$	246
									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011			2010
Expected benefit payments (gross)
Year one	$	5,142	$	4,639	$	102	$	102	$	271		$	262
Year two		5,590		5,058		100		100		264			261
Year three		6,113		5,480		98		99		268			253
Year four		6,649		5,997		97		97		271			257
Year five		7,252		6,524		105		95		271			258
Next five years		47,701		42,703		597		558		1,343			1,274
									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011			2010
Expected federal subsidy
Year one	$	—	$	—	$	—	$	—	$	(15	)	$	(16	)
Year two		—		—		—		—		(15	)		(16	)
Year three		—		—		—		—		(15	)		(16	)
Year four		—		—		—		—		(15	)		(16	)
Year five		—		—		—		—		(15	)		(16	)
Next five years		—		—		—		—		(67	)		(74	)

The components of net periodic benefit cost and other changes in plan assets and benefit obligations recognized in other comprehensive income for the Company’s defined benefit plans for the years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	Pension Benefits
	Pension Plan									SERP
	2011			2010			2009			2011			2010			2009
Components of net periodic benefit cost
Service cost	$	7,303		$	6,883		$	6,523		$	—		$	—		$	—
Interest cost		9,693			9,399			8,486			80			84			84
Expected return on plan assets		(11,283	)		(9,329	)		(7,333	)		—			—			—
Amortization:
Actuarial loss		2,859			3,162			5,666			7			2			2
Prior service credit		(38	)		(89	)		(88	)		—			—			—
Net periodic benefit cost		8,534			10,026			13,254			87			86			86
Other changes in plan assets and benefit obligations recognized in other comprehensive income
Current year actuarial loss (gain)		46,444			8,145			(28,443	)		156			102			14
Recognition of actuarial loss		(2,859	)		(3,162	)		(5,666	)		(7	)		(2	)		(2	)
Recognition of prior service credit		38			89			88			—			—			—
Total recognized in other comprehensive income		43,623			5,072			(34,021	)		149			100			12
Total recognized in net periodic benefit cost and other comprehensive income	$	52,157		$	15,098		$	(20,767	)	$	236		$	186		$	98

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	Pension Benefits
	Pension Plan									SERP
	2011			2010			2009			2011			2010			2009
Weighted average assumptions used to determine net periodic benefit cost
Discount rate		5.5	%		6.1	%		6.1	%		5.5	%		6.1	%		6.1	%
Expected long-term rate of return on plan assets		7.5	%		7.5	%		7.5	%		—			—			—
Rate of compensation increase		4.25	%		4.0	%		4.0	%		—			—			—

The estimated amounts that will be amortized from accumulated other comprehensive income into net periodic benefit cost in 2012 are as follows (in thousands):

	Pension Benefits
	Pension Plan		SERP
Actuarial loss	$	7,007	$	14
Prior service credit		—		—
	$	7,007	$	14

The components of net periodic benefit cost and other changes in benefit obligations recognized in other comprehensive income for the Company’s postretirement benefit plan for the years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	Other Postretirement Benefits
	Postretirement Welfare Plan
	2011			2010			2009
Components of net periodic benefit cost
Service cost	$	—		$	—		$	246
Interest cost		164			154			322
Curtailment loss		119			—			—
Amortization:
Actuarial gain		(593	)		(660	)		(325	)
Prior service cost		40			560			40
Net periodic benefit cost		(270	)		54			283
Other changes in benefit obligations recognized in other comprehensive income
Current year actuarial gain		182			(3,109	)		(141	)
Recognition of actuarial gain		593			660			325
Recognition of prior service cost		(158	)		(40	)		(40	)
Adjustment for actual Medicare Part D reimbursement		(3	)		(10	)		—
Total recognized in other comprehensive income		614			(2,499	)		144
Total recognized in net periodic benefit cost and other comprehensive income	$	344		$	(2,445	)	$	427
Weighted average assumptions used to determine net periodic benefit cost
Discount rate		5.5	%		6.1	%		6.1	%
Health care cost trend rate:
Initial rate		8.0	%		7.5	%		8.0	%
Ultimate rate		5.0	%		5.0	%		5.0	%
Years to ultimate		2017			2015			2015
Effect of one-percentage-point change in assumed health care cost trend rate on aggregate service and interest cost
Increase	$	16		$	14		$	12
Decrease		(14	)		(12	)		(11	)

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The estimated amounts that will be amortized from accumulated other comprehensive income into net periodic benefit cost in 2012 are as follows (in thousands):

	Other Postretirement Benefits
	Postretirement Welfare Plan
Actuarial gain	$	(616	)
Prior service cost		—
	$	(616	)

In addition to the defined benefit plan, the Company sponsors various defined contribution plans for substantially all employees. The aggregate contributions to the plans were $13,793,000, $11,614,000 and $13,682,000 in 2011, 2010 and 2009, respectively.

(11) Earnings Per Share

The following table presents the components of basic and diluted earnings per share for the years ended December 31, 2011, 2010 and 2009 (in thousands, except per share amounts):

	2011			2010			2009
Net earnings attributable to Kirby	$	183,026		$	116,249		$	125,941
Undistributed earnings allocated to restricted shares		(1,613	)		(1,125	)		(1,403	)
Income available to Kirby common stockholders — basic		181,413			115,124			124,538
Undistributed earnings allocated to restricted shares		1,613			1,125			1,403
Undistributed earnings reallocated to restricted shares		(1,606	)		(1,122	)		(1,400	)
Income available to Kirby common stockholders — diluted	$	181,420		$	115,127		$	124,541
Shares outstanding:
Weighted average common stock issued and outstanding		54,673			53,852			53,791
Weighted average unvested restricted stock		(482	)		(521	)		(599	)
Weighted average common stock outstanding — basic		54,191			53,331			53,192
Dilutive effect of stock options		222			135			121
Weighted average common stock outstanding — diluted		54,413			53,466			53,313
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.35		$	2.16		$	2.34
Diluted	$	3.33		$	2.15		$	2.34

Certain outstanding options to purchase approximately 2,000, 114,000 and 248,000 shares of common stock were excluded in the computation of diluted earnings per share as of December 31, 2011, 2010 and 2009, respectively, as such stock options would have been antidilutive.

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(12) Quarterly Results (Unaudited)

The unaudited quarterly results for the year ended December 31, 2011 were as follows (in thousands, except per share amounts):

	Three Months Ended
	March 31, 2011			June 30, 2011			September 30, 2011			December 31, 2011
Revenues	$	299,359		$	437,331		$	563,582		$	550,145
Costs and expenses		243,650			365,892			471,371			457,121
Gain (loss) on disposition of assets		(66	)		40			97			(111	)
Operating income		55,643			71,479			92,308			92,913
Other income (expense)		51			78			(6	)		183
Interest expense		(2,833	)		(3,278	)		(5,974	)		(5,817	)
Earnings before taxes on income		52,861			68,279			86,328			87,279
Provision for taxes on income		(19,961	)		(26,050	)		(32,734	)		(30,510	)
Net earnings		32,900			42,229			53,594			56,769
Less: Net earnings attributable to noncontrolling interests		(470	)		(537	)		(860	)		(599	)
Net earnings attributable to Kirby	$	32,430		$	41,692		$	52,734		$	56,170
Net earnings per share attributable to Kirby common stockholders:
Basic	$	.60		$	.78		$	.95		$	1.01
Diluted	$	.60		$	.77		$	.94		$	1.00

The unaudited quarterly results for the year ended December 31, 2010 were as follows (in thousands, except per share amounts):

	Three Months Ended
	March 31, 2010			June 30, 2010			September 30, 2010			December 31, 2010
Revenues	$	268,253		$	273,669		$	281,317		$	286,318
Costs and expenses		225,196			223,018			228,590			232,631
Gain (loss) on disposition of assets		(44	)		(19	)		8			(23	)
Operating income		43,013			50,632			52,735			53,664
Other income		12			30			131			383
Interest expense		(2,668	)		(2,697	)		(2,750	)		(2,845	)
Earnings before taxes on income		40,357			47,965			50,116			51,202
Provision for taxes on income		(15,446	)		(18,322	)		(19,211	)		(19,279	)
Net earnings		24,911			29,643			30,905			31,923
Less: Net earnings attributable to noncontrolling interests		(237	)		(375	)		(218	)		(303	)
Net earnings attributable to Kirby	$	24,674		$	29,268		$	30,687		$	31,620
Net earnings per share attributable to Kirby common stockholders:
Basic	$	.46		$	.54		$	.57		$	.59
Diluted	$	.46		$	.54		$	.57		$	.59

Quarterly basic and diluted earnings per share may not total to the full year per share amounts, as the weighted average number of shares outstanding for each quarter fluctuates as a result of the assumed exercise of stock options.

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(13) Contingencies and Commitments

In June 2011, the Company as well as three other companies received correspondence from United States Environmental Protection Agency (“EPA”) concerning ongoing cleanup and restoration activities under the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) with respect to a Superfund site, the Gulfco Marine Maintenance Site (“Gulfco”), located in Freeport, Texas. In prior years, various subsidiaries of the Company utilized a successor to Gulfco to perform tank barge cleaning services, sand blasting and repair on certain Company vessels. The EPA continues to investigate activities at the site to assess additional Potentially Responsible Parties (“PRPs”). Since 2005, four named PRPs have participated in the investigation, cleanup and restoration of the site under an administrative order from EPA. Information received to date indicates that approximately $3,500,000 has been incurred in connection with the cleanup effort in addition to EPA’s oversight costs of approximately $1,800,000. To date, neither the EPA nor the named PRPs have performed an allocation of potential liability in connection with the site nor have they provided requested cost and expenses supporting documentation related to the site. The Company is investigating its activities at the site in order to assess what, if any, liability it has in connection with the site.

In 2009, the Company was named a PRP in addition to a group of approximately 250 named PRPs under CERCLA with respect to a Superfund site, the Portland Harbor Superfund site (“Portland Harbor”) in Portland, Oregon. The site was declared a Superfund site in December 2000 as a result of historical heavily industrialized use due to manufacturing, shipbuilding, petroleum storage and distribution, metals salvaging, and electrical power generation activities which led to contamination of Portland Harbor, an urban and industrial reach of the lower Willamette River located immediately downstream of downtown Portland. The Company’s involvement arises from four spills at the site after it was declared a Superfund site, as a result of predecessor entities’ actions in the area. To date, there is no information suggesting the extent of the costs or damages to be claimed from the 250 noticed PRPs. Based on the nature of the involvement at the Portland Harbor site, the Company believes its potential contribution is de minimis; however, to date neither the EPA nor the named PRPs have performed an allocation of potential liability in connection with the site nor have they provided costs and expenses in connection with the site.

In 2000, the Company and a group of approximately 45 other companies were notified that they are PRPs under the CERCLA with respect to a Superfund site, the Palmer Barge Line Superfund Site (“Palmer”), located in Port Arthur, Texas. In prior years, Palmer had provided tank barge cleaning services to various subsidiaries of the Company. The Company and three other PRPs entered into an agreement with the EPA to perform a remedial investigation and feasibility study and, subsequently, a limited remediation was performed and is now complete. During the 2007 third quarter, five new PRPs entered into an agreement with the EPA related to the Palmer site. In July 2008, the EPA sent a letter to approximately 30 PRPs for the Palmer site, including the Company, indicating that it intends to pursue recovery of $2,949,000 of costs it incurred in relation to the site. The Company and the other PRPs continue to discuss suggested pro rata allocations of costs to all PRPs with the EPA and the U.S. Department of Justice (“DOJ”) in order to resolve the EPA’s past costs claim.

In 2000, the Company and approximately 50 other companies were notified that they are PRPs under the CERCLA with respect to a Superfund site, the State Marine of Port Arthur Superfund Site (“State Marine”), located in Port Arthur, Texas. In the past, State Marine performed tank barge cleaning and services for various subsidiaries of the Company. In March 2010, the DOJ and EPA issued a letter to seven PRPs, which include the former owners/operator of the site and others, including the Company, indicating their intent to pursue reimbursement of its past costs of approximately $2,977,000 in connection with clean-up activities in relation to the site. The Company and the other PRPs will continue to pursue documentation concerning the site activities related to all PRPs in order to determine appropriate allocation of past costs relative to activities at the site to develop suggested pro rata sharing to resolve the EPA’s past cost claim.

With respect to the above sites, the Company has recorded reserves, if applicable, for its estimated potential liability for its portion of the EPA’s past costs claim based on information developed to date including various factors such as the Company’s liability in proportion to other responsible parties and the extent to which such costs are recoverable from third parties.

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On July 25, 2011, a subsidiary of the Company was named as a defendant in the U.S. District Court for the Southern District of Texas - Galveston Division, in a complaint styled Figgs. v. Kirby Inland Marine, et al., which alleges that the plaintiff individually as a vessel tankerman, and on behalf of other current and former similarly situated vessel tankerman employed with the Company, is entitled to overtime pay under the Fair Labor Standards Act. Plaintiffs assert that vessel tankerman are not seaman who are expressly exempt from overtime pay provisions under the law. The case was conditionally certified as a collective action on December 22, 2011 at which time the Court prescribed a notice period for current and former employees to voluntarily participate as a plaintiff. The notice period closes on February 27, 2012 after which time discovery will be conducted with respect to the merits of the case. Plaintiff seeks to maintain a collective action, compensatory damages in the form of back pay, attorneys fees, cost and liquidated damages. As discovery as to the merits of the case has not been conducted to date, the Company is unable to assess the liability at this time. Accordingly, the Company is not able to estimate any amount of loss or range of loss.

On January 30, 2012 in the U.S. District Court for the District of New Jersey and styled Rescue Mission of El Paso., Inc., et al. v. John J. Nicola, et al., the Company, its subsidiary, 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 conditions, 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 seeks class certification, compensatory damages, attorneys fees and costs. The Company believes that this suit is without merit and intends to vigorously defend itself in this matter based on the information available to the Company at this time. The Company does not expect the outcome of this matter to have a material adverse effect on its consolidated financial statements; however, there can be no assurance as to the ultimate outcome of this matter.

In addition, 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.

Certain Significant Risks and Uncertainties. The preparation of financial statements in conformity with United States generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. However, in the opinion of management, the amounts would be immaterial.

The customer base of the marine transportation segment includes the major industrial petrochemical and chemical manufacturers, agricultural chemical manufacturers and refining companies operating in the United States. During 2011, approximately 75% of marine transportation’s inland revenues were from movements of such products under term contracts, ranging from one year to five years, with renewal options. During the second half of 2011, approximately 60% of the marine transportation’s coastal revenues were under term contracts. While the manufacturing and refining companies have generally been customers of the Company for numerous years (some as long as 40 years) and management anticipates a continuing relationship, there is no assurance that any individual contract will be renewed. No single customer of the marine transportation segment accounted for more than 10% of the Company’s revenues in 2011. The Dow Chemical Company accounted for 12% of the Company’s revenues in 2010 and 11% in 2009. SeaRiver Maritime, Inc., the United States transportation affiliate of Exxon Mobil Corporation, accounted for 11% of the Company’s revenues in 2010 and 10% in 2009.

Major customers of the diesel engine services segment include inland and offshore barge operators, oilfield service companies, oil and gas operators and producers, compression companies offshore fishing companies, marine and on-highway transportation companies, the USCG and United States Navy, and power generation,

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nuclear and industrial companies. The segment operates as an authorized distributor in 17 eastern states and the Caribbean, and as non-exclusive authorized service centers for Electro-Motive Diesel, Inc. (“EMD”) throughout the rest of the United States for marine and power generation applications. The diesel engine services segment’s relationship with EMD has been maintained for 46 years. The segment also operates factory-authorized full service marine dealerships for Cummins, Detroit Diesel and John Deere high-speed diesel engines and Allison transmissions and gears in the Gulf Coast region, as well as an authorized marine dealer for Caterpillar in Alabama, Kentucky and Louisiana.

United has maintained continuous exclusive distribution rights for MTU and Allison since 1946. United is one of MTU’s top five distributors of MTU off-highway engines in North America with exclusive distribution rights in Oklahoma, Arkansas, Louisiana and Mississippi. In addition, as a distributor of Allison transmission products, United has distribution rights in Oklahoma, Arkansas and Louisiana. Finally, United is also the exclusive distributor for Daimler engines and related equipment, in Oklahoma, Arkansas and Louisiana.

The results of the diesel engine services segment are largely tied to the industries it serves and, therefore, can be influenced by the cycles of such industries. No single customer of the diesel engine services segment accounted for more than 10% of the Company’s revenues in 2011, 2010 and 2009.

Weather can be a major factor in the day-to-day operations of the marine transportation segment. Adverse weather conditions, such as high or low water, tropical storms, hurricanes, tsunamis, fog and ice, can impair the operating efficiencies of the marine fleet. Shipments of products can be delayed or postponed by weather conditions, which are totally beyond the control of the Company. Adverse water conditions are also factors which impair the efficiency of the fleet and can result in delays, diversions and limitations on night passages, and dictate horsepower requirements and size of tows. Additionally, much of the inland waterway system is controlled by a series of locks and dams designed to provide flood control, maintain pool levels of water in certain areas of the country and facilitate navigation on the inland river system. Maintenance and operation of the navigable inland waterway infrastructure is a government function handled by the Army Corps of Engineers with costs shared by industry. Significant changes in governmental policies or appropriations with respect to maintenance and operation of the infrastructure could adversely affect the Company.

The Company’s marine transportation segment is subject to regulation by the USCG, federal laws, state laws and certain international conventions, as well as numerous environmental regulations. The Company believes that additional safety, environmental and occupational health regulations may be imposed on the marine industry. There can be no assurance that any such new regulations or requirements, or any discharge of pollutants by the Company, will not have an adverse effect on the Company.

The Company’s marine transportation segment competes principally in markets subject to the Jones Act, a federal cabotage law that restricts domestic marine transportation in the United States to vessels built and registered in the United States, and manned and owned by United States citizens. The Jones Act cabotage provisions occasionally come under attack by interests seeking to facilitate foreign flag competition in trades reserved for domestic companies and vessels under the Jones Act. The Company believes that continued efforts will be made to modify or eliminate the cabotage provisions of the Jones Act. If such efforts are successful, certain elements could have an adverse effect on the Company.

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 is $26,329,000 at December 31, 2011, including $9,260,000 in letters of credit and debt guarantees, and $17,069,000 in performance bonds. All of these instruments have an expiration date within three 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.

96

(14) Segment Data

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

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

Diesel Engine Services — Overhaul and repair of medium-speed and high-speed diesel engines, reduction gear repair, and sale of related parts and accessories for customers in the marine and power generation applications, and distribution and service of high-speed diesel engines, transmissions, including the manufacture and remanufacture of hydraulic fracturing equipment for 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’s accounting policies for the business segments are the same as those described in Note 1, Summary of Significant Accounting Policies. The Company evaluates the performance of its segments based on the contributions to operating income of the respective segments, and before income taxes, interest, gains or losses on disposition of assets, other nonoperating income, noncontrolling interests, accounting changes, and nonrecurring items. Intersegment sales for 2011, 2010 and 2009 were not significant.

The following table sets forth by reportable segment the revenues, profit or loss, total assets, depreciation and amortization, and capital expenditures attributable to the principal activities of the Company for the years ended December 31, 2011, 2010 and 2009 (in thousands):

	2011			2010			2009
Revenues:
Marine transportation	$	1,194,607		$	915,046		$	881,298
Diesel engine services		655,810			194,511			200,860
	$	1,850,417		$	1,109,557		$	1,082,158
Segment profit (loss):
Marine transportation	$	262,193		$	192,758		$	208,086
Diesel engine services		68,105			20,553			21,005
Other		(35,551	)		(23,671	)		(23,533	)
	$	294,747		$	189,640		$	205,558
Total assets:
Marine transportation	$	2,307,821		$	1,383,252		$	1,336,358
Diesel engine services		608,886			185,824			185,573
Other		43,704			225,861			114,032
	$	2,960,411		$	1,794,937		$	1,635,963

97

	2011		2010		2009
Depreciation and amortization:
Marine transportation	$	111,292	$	88,710	$	87,589
Diesel engine services		11,801		4,055		4,247
Other		2,936		2,531		2,132
	$	126,029	$	95,296	$	93,968
Capital expenditures:
Marine transportation	$	218,777	$	132,744	$	188,479
Diesel engine services		5,576		920		1,768
Other		1,885		3,177		2,413
	$	226,238	$	136,841	$	192,660

The following table presents the details of “Other” segment profit (loss) for the years ended December 31, 2011, 2010 and 2009 (in thousands):

	2011			2010			2009
General corporate expenses	$	(17,915	)	$	(13,189	)	$	(12,239	)
Impairment of goodwill		—			—			(1,901	)
Interest expense		(17,902	)		(10,960	)		(11,080	)
Gain (loss) on disposition of assets		(40	)		(78	)		1,079
Other income		306			556			608
	$	(35,551	)	$	(23,671	)	$	(23,533	)

The following table presents the details of “Other” total assets as of December 31, 2011, 2010 and 2009 (in thousands):

	2011		2010		2009
General corporate assets	$	40,022	$	222,525	$	110,980
Investment in affiliates		3,682		3,336		3,052
	$	43,704	$	225,861	$	114,032

(15) Related Party Transactions

During 2011, the Company and its subsidiaries paid 55 Waugh, LP, a partnership 60% owned by C. Berdon Lawrence, the former Chairman of the Board and current director of the Company, and his family, $1,491,000 for the rental of office space in a building owned by 55 Waugh, LP. The Company’s headquarters are located in the building under a lease that was signed in 2005, prior to the purchase of the building by 55 Waugh, LP, and expires at the end of 2015.

The Company is a 50% owner of The Hollywood Camp, L.L.C. (“The Hollywood Camp”), a company that owns and operates a hunting and fishing facility used by the Company and L3 Partners, LLC (“L3P”), a company owned by Mr. Lawrence, which is also a 50% owner. The Company uses The Hollywood Camp primarily for customer entertainment. L3P acts as manager of The Hollywood Camp. The Hollywood Camp allocates lease and lodging expenses to its members based on their usage of the facilities. During 2011, the Company paid $2,121,000 to The Hollywood Camp for its share of facility expenses.

Richard J. Alario, a current director of the Company, is the Chairman of the Board, President and Chief Executive Officer of Key Energy Services, Inc. (“Key Energy”). In 2011, Key Energy paid the Company $7,978,000 for oilfield service equipment and for parts and service. Such sales and service were in the ordinary course of business of the Company.

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The husband of Amy D. Husted, Vice President — Legal of the Company, is a partner in the law firm of Strasburger & Price, LLP. In 2011, the Company paid the law firm $483,000 for legal services in connection with matters in the ordinary course of business of the Company.

The brother-in-law of Ronald A. Dragg, Vice President and Controller of the Company, is a 50% owner of MB Western Industrial Contracting Company (“MB Western”). In 2011, the Company paid MB Western $1,160,000 for shoreside facilities construction services. Such services were completed in the ordinary course of business of the Company.

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PART IV

Item 15. Exhibits and Financial Statement Schedules

1. Financial Statements

Included in Part III of this report:

Report of Independent Registered Public Accounting Firm.

Report of Independent Registered Public Accounting Firm.

Consolidated Balance Sheets, December 31, 2011 and 2010.

Consolidated Statements of Earnings, for the years ended December 31, 2011, 2010 and 2009.

Consolidated Statements of Stockholders’ Equity and Comprehensive Income, for the years ended December 31, 2011, 2010 and 2009.

Consolidated Statements of Cash Flows, for the years ended December 31, 2011, 2010 and 2009.

Notes to Consolidated Financial Statements, for the years ended December 31, 2011, 2010 and 2009.

2. Financial Statement Schedules

All schedules are omitted as the required information is inapplicable or the information is presented in the consolidated financial statements or related notes.

3. Exhibits

Exhibit Number	Description of Exhibit
2.1	—   Purchase and Sale Agreement dated as of February 21, 2011 between United Engine Holding Company, LLC and Kirby Engine Systems, Inc. (incorporated by reference to Exhibit 2.1 of Registrant’s Current Report on Form 8-K filed with the Commission on February 25, 2011).
2.2	—   Agreement and Plan of Merger, dated as of March 13, 2011, by and among Kirby Corporation, KSP Merger Sub, LLC, KSP Holding Sub, LLC, KSP LP Sub, LLC, K- Sea Transportation Partners L.P., K-Sea General Partner L.P., K-Sea IDR Holdings LLC, and K-Sea General Partner GP LLC (incorporated by reference to Exhibit 2.1 of Registrant’s Current Report on Form 8-K filed with the Commission on March 16, 2011).
3.1	—   Restated Articles of Incorporation filed June 16, 1976, with all amendments to date (incorporated by reference to Exhibit 3.1 of the Registrant’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2006).
3.2	—   Bylaws of the Company, as amended (incorporated by reference to Exhibit 3.1 of the Registrant’s Current Report on Form 8-K filed with the Commission on April 30, 2010).
4.1	—   Master Note Purchase Agreement dated as of February 15, 2003 among the Company and the Purchasers named therein (incorporated by reference to Exhibit 4.3 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2002).
4.2	—   First Supplement to Note Purchase Agreement dated as of May 31, 2005 among Kirby Corporation and the Purchasers named therein (incorporated by reference to Exhibit 4.2 of the Registrant’s Current Report on Form 8-K filed with the Commission on June 2, 2005).

100

Exhibit Number	Description of Exhibit
10.1	—   Second Amended and Restated Credit Agreement, dated November 9, 2010 among Kirby Corporation, JPMorgan Chase Bank, N.A. as Administrative Agent, and the banks named therein (incorporated by reference to Exhibit 10.1 of Registrant’s Current Report on Form 8-K filed with the Commission on November 12, 2010).
10.2	—   First Amendment to Credit Agreement dated as of May 31, 2011 among Kirby Corporation, JPMorgan Chase Bank, N.A., as Administrative Agent, and the banks named therein (incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K filed with the Commission on June 3, 2011).
10.3	—   Credit Agreement dated as of May 31, 2011 among Kirby Corporation, Wells Fargo Bank National Association, as administrative agent, and the banks named therein (incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Commission on June 3, 2011).
10.4	—   Indemnification Agreement, dated April 29, 1986, between the Company and each of its Directors and certain key employees (incorporated by reference to Exhibit 10.11 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 1986).
10.5†	—   Deferred Compensation Agreement dated August 12, 1985 between Dixie Carriers, Inc., and J. H. Pyne (incorporated by reference to Exhibit 10.19 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 1992).
10.6†	—   1994 Nonemployee Director Stock Option Plan for Kirby Corporation (incorporated by reference to Exhibit 10.22 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 1993).
10.7†	—   Deferred Compensation Plan for Key Employees (incorporated by reference to Exhibit 10.7 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2005).
10.8†	—   2002 Stock and Incentive Plan (incorporated by reference to Exhibit 10.13 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2006).
10.9†*	—   Annual Incentive Plan Guidelines for 2011.
10.10†*	—   Annual Incentive Plan Guidelines for 2012.
10.11†	—   2000 Nonemployee Director Stock Plan (incorporated by reference to Exhibit 10.1 to the Registrant’s Form 10-Q for the quarter ended June 30, 2011).
10.12†	—   2005 Stock and Incentive Plan (incorporated by reference to Exhibit 10.8 of the Registrant’s Annual Report on Form 10-K for the year ended December 31, 2010).
10.13†	—   Form of Nonincentive Stock Option Agreement (incorporated by reference to Exhibit 10.2 to the Registrant’s Current Report on Form 8-K filed with the Commission on April 29, 2005, File No. 001-07615).
10.14†	—   Form of Incentive Stock Option Agreement (incorporated by reference to Exhibit 10.3 to the Registrant’s Current Report on Form 8-K filed with the Commission on April 29, 2005, File No. 001-07615).
10.15†	—   Form of Restricted Stock Agreement (incorporated by reference to Exhibit 10.4 to the Registrant’s Current Report on Form 8-K filed with the Commission on April 29, 2005, File No. 001-07615).
10.16†	—   Nonemployee Director Compensation Program (incorporated by reference to Exhibit 10.2 of the Registrant’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2011).
21.1*	—   Principal Subsidiaries of the Registrant.
23.1*	—   Consent of Independent Registered Public Accounting Firm.

101

Exhibit Number	Description of Exhibit
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 (As adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002).
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 Definitions Linkbase Document
101.LAB**	—   XBRL Taxonomy Extension Label Linkbase Document
101.PRE**	—   XBRL Taxonomy Extension Presentation Linkbase Document

* Filed herewith.

** These exhibits are furnished herewith. In accordance with Rule 406T of Regulations 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.

† Management contract, compensatory plan or arrangement.

102

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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: February 28, 2012

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Signature	Capacity	Date
/s/    JOSEPH H. PYNE Joseph H. Pyne	Chairman of the Board and Chief Executive Officer (Principal Executive Officer)	February 28, 2012
/s/    DAVID W. GRZEBINSKI David W. Grzebinski	Executive Vice President and Chief Financial Officer (Principal Financial Officer)	February 28, 2012
/s/    RONALD A. DRAGG Ronald A. Dragg	Vice President and Controller (Principal Accounting Officer)	February 28, 2012
/s/    RICHARD J. ALARIO Richard J. Alario	Director	February 28, 2012
/s/    C. SEAN DAY C. Sean Day	Director	February 28, 2012
/s/    BOB G. GOWER Bob G. Gower	Director	February 28, 2012
/s/    WILLIAM M. LAMONT, JR. William M. Lamont, Jr.	Director	February 28, 2012
/s/    C. BERDON LAWRENCE C. Berdon Lawrence	Director	February 28, 2012
/s/    DAVID L. LEMMON David L. Lemmon	Director	February 28, 2012
/s/    MONTE J. MILLER Monte J. Miller	Director	February 28, 2012
/s/    GEORGE A. PETERKIN, JR. George A. Peterkin, Jr.	Director	February 28, 2012
/s/    RICHARD R. STEWART Richard R. Stewart	Director	February 28, 2012

103

EXHIBIT INDEX

Exhibit Number	Description of Exhibit
10.9†*	—   Annual Incentive Plan Guidelines for 2011.
10.10†*	—   Annual Incentive Plan Guidelines for 2012.
21.1*	—  Principal Subsidiaries of the Registrant.
23.1*	—   Consent of Independent Registered Public Accounting Firm.
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 (As adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002).
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 Definitions Linkbase Document
101.LAB**	—   XBRL Taxonomy Extension Label Linkbase Document
101.PRE**	—   XBRL Taxonomy Extension Presentation Linkbase Document

* Filed herewith

** 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.

† Management contract, compensatory plan or arrangement.

104

EX-10.9

Exhibit 10.9

ANNUAL INCENTIVE PLAN

2011 Plan Year

Guidelines

KIRBY CORPORATION

January 2011

TABLE OF CONTENTS

Introduction	2
The Annual Incentive Plan	3
Performance Measurement Period	3
Eligibility	3
Plan Objectives	4
Performance Measures	4
Corporate and Business Group Weighting	6
Individual Bonus Targets	7
Annual Incentive Plan Concept	7
Performance Measures and Weighting	8
Performance Standards and Award Opportunities	8
Example Award Calculation	9
Administration	10

1

Introduction

Kirby Corporation established this 2011 Annual Incentive Plan (the “Plan”) to focus employees on identifying and achieving business strategies that will grow the business and lead to an increase in stockholder value. The Plan is also intended to reward superior performance by employees, for their contributions toward achieving Kirby’s objectives. This program may be offered, in whole or in part, to wholly owned subsidiaries of the Company, at the Company’s discretion.

Certain aspects of this Plan are complex. Although these guidelines establish rules for Plan operation, those rules may not work in all cases. Therefore, the Compensation Committee of the Kirby Board of Directors shall have the discretionary authority to interpret these guidelines to insure that the awards are consistent with the Plan’s purposes and the Company’s interests. All decisions by the Compensation Committee shall be final and binding.

Unless resolutions of the Compensation Committee expressly provide otherwise, awards granted under the Plan shall constitute performance awards granted under Article IV of the Kirby Corporation 2005 Stock and Incentive Plan (as amended from time to time, the “Stock Plan”), and as such, shall be subject to the terms and provisions of the Stock Plan that apply to such performance awards.

This Plan, or any part thereof, may be amended, modified, or terminated at any time, without prior notice, by written authorization of (i) the Compensation Committee or (ii) the Chief Executive Officer of the Company; provided that the Plan may not be amended or modified in a manner that would cause an award that is intended to satisfy the performance-based compensation exception under Section 162(m) of the Internal Revenue Code of 1986, as amended (“Section 162(m)”), to fail to satisfy the exception.

2

The Annual Incentive Plan

Each award granted under the Plan is an award for total Company performance, and for the performance of our two plan designated Business Groups: Kirby Inland Marine and Kirby Engine Systems. Plan Awards for Kirby Ocean Transport Company and Osprey Line, LLC are determined by the performance of the Kirby Inland Marine business group, as the plan participants of these operating companies are managed within the Kirby Inland Marine organizational structure. Awards are formula-driven and are based on achieving Company, Business Group and individual performance objectives. At the discretion of the Compensation Committee (or to the extent provided in the Plan, the Chief Executive Officer of the Company), an award may be decreased by up to 25% based on individual performance (“negative discretion”).

Performance Measurement Period

Performance is measured on a calendar year basis for the Plan. The Performance Period begins on January 1, 2011 and ends on December 31, 2011.

Eligibility

• Generally, shore staff managerial employees in salary grades 15 and above, and Kirby Inland Marine Wheelhouse employees classified as Captain, Relief Captain or Pilot, are eligible for participation. Selection for participation in the Plan is based upon each position’s ability to impact long-term financial results of the Company and designation by management. Consequently, some employees in positions at salary grades 15 and above might not be included in the Plan, and some employees in positions below salary grade 15 might be included.

• In order to be eligible to receive an award, participants must be employed on the last day of the Performance Period, and on the date bonuses are actually paid for the Performance Period, unless their earlier termination is due to death, normal retirement¹ or disability¹. If a participant’s employment is terminated after the

¹  Normal retirement or disability as defined for shore based employees in the Company’s Profit Sharing Plan, and as defined for wheelhouse employees in the Vessel Pension Plan

3

last day of the Performance Period, but prior to the date of payment, for any reason other than death, normal retirement¹ or disability¹, the participant’s bonus is distributed among others eligible for the bonus. A “covered employee” as defined for purposes of Section 162(m) (a “Covered Employee”) is not eligible for the reallocated amounts.

• Participation in the Plan in one year does not guarantee participation in similar plans in future years. Participants in the Plan or in similar plans in future years will be notified annually of their selection for participation.

Plan Objectives

The Plan has five key objectives:

• Provide an annual incentive plan that drives performance toward objectives critical to creating shareholder value.

• Offer competitive cash compensation opportunities to key Kirby employees.

• Award outstanding achievement among employees who can directly affect Kirby’s results.

• Assist Kirby in attracting and retaining high quality employees.

• Reflect both quantitative and qualitative performance factors in actual bonus payouts.

Performance Measures

The performance measures for the Plan are:

• EBITDA

• Return on Total Capital

• Earnings per share

4

Annual performance targets will be established for each measure based on Kirby’s projected budget, and individual bonus payments will be based on a combination of Company performance and individual performance.

The maximum amount that may be paid under an award is based on Company performance in achieving the three performance measures, although an award may be decreased by up to 25% based on an assessment of individual performance for the year.

Each of the performance measures will have equal weight in calculating the bonus payout pool.

5

Corporate and Business Group Weighting

The Plan bonus is calculated at the end of the year based on the performance of Kirby and the performance of our Marine transportation, including Kirby Inland Marine, Kirby Ocean Transport Company, Osprey Line, and Kirby Engine Systems, relative to objectives established at the beginning of the year.

The award for Business Group employees will be primarily tied to Business Group performance, with a defined portion tied to Company performance.

The award for Corporate employees will be tied entirely to total Kirby performance.

Annual Incentive Plan Calculation
	Incentive Bonus Calculation %
	Kirby (Company)			Business Group
All Corporate Employees		100	%		0	%
Business Group Employees (Inland Marine and Engine Systems)		30	%		70	%
Inland & Engine Systems Presidents		50	%		50	%

6

Individual Bonus Targets

Each participant will be assigned a bonus level which is based on competitive market practices, as well as the employee’s ability to impact long-term Company performance. Market practices will be determined using data from either general industry, the marine transportation industry, or the diesel repair industry, depending upon the individual position being considered. The Company’s intent is that salary plus target annual bonus will be positioned to provide a competitive market opportunity for target performance.

Annual Incentive Plan Concept

7

Performance Measures and Weighting

Measure	Weight
n EBITDA (Earnings Before Interest, Taxes, Depreciation and Amortization)		33-1/3	%
n Return on Total Capital (Earnings before interest and taxes divided by average beginning and ending stockholders’ equity plus long-term debt)		33-1/3	%
n Earnings per Share		33-1/3	%
		100	%

Performance Standards and Award Opportunities

Performance Level	Definition	Relationship to Budget	% of Target Earned
Threshold	Minimal acceptable performance for payout	80% of Budget	50%
Target	Expected performance at a stretch level	100% of Budget	100%
Maximum	Outstanding performance	120% of Budget	200%

Performance must be at least to Threshold to earn a bonus payment.

8

Example Award Calculation

	Performance Standards												Example Calculation
Performance Objectives	Below Threshold			Threshold			Target			Maximum			Assumed Actual Results (% Budget Achieved)			Percent of Target Award Earned			Objective Weight			Weighted Percent of Target Award Earned
Percent of Target Award Earned:		0	%		50	%		100	%		200	%
EBITDA (% Budget Achieved)		<80	%		80	%		100	%		120	%		90	%		75	%		33-1/3	%		25	%
Return on Total Capital (% Budget Achieved)		<80	%		80	%		100	%		120	%		110	%		150	%		33-1/3	%		50	%
Earnings per Share (% Budget Achieved)		<80	%		80	%		100	%		120	%		100	%		100	%		33-1/3	%		33.3	%
					Total Percent of Target Awards Earned for Bonus Pool:																		108.3	%

n As shown in the exhibit, actual performance on each objective results in a corresponding percent of target award earned.

n The percents of target award earned for each objective are then multiplied by the weight for the objective, producing a weighted percent of target award earned for each objective.

n The weighted percents of target award earned for all objectives are summed to produce a total percent of target awards earned. This factor, when multiplied by the sum of target bonuses for plan participants, equals the bonus funding pool.

n The total pool is paid to participants pro-rata, based on their individual bonus level and their applicable base salary for the period, except that each individual award may be decreased by up to 25% based on individual performance.

9

Administration

Award Payout

A participant’s Final Award is paid out in cash within 90 days following the end of the Company’s fiscal year, based on audited financials. No payment shall be made to a participant who is a Covered Employee until the Compensation Committee certifies that the performance objectives that result in such payment have been achieved.

Eligibility Limitation

Unless otherwise provided for in the Plan, participants must be employed by the Company on the last day of the Performance Period, and on the date bonuses are actually paid for the Performance Period, in order to be eligible to receive a bonus award.

Special Circumstances

Listed below are guidelines addressing payment of awards upon termination and other events. The Committee will have the sole authority to resolve disputes related to Plan administration. Decisions made by the Committee will be final and binding on all participants.

New Employees. New employees hired after the beginning of a Performance Period who are selected for participation in the Plan, will receive prorated awards for the then current Performance Period, subject to the Termination of Employment restrictions.

Termination of Employment. If employment terminates before the end of the full Performance Period, or before the date bonuses are actually paid for the Performance Period, as a result of death, normal retirement², or disability², the participant (or the participant’s heirs) will be entitled to receive a prorated award at the end of the Performance Period, based upon actual performance and base wages earned while employed during the Performance Period.

If employment terminates prior to the last day of the Performance Period, or prior to the date bonuses are actually paid for the respective Performance Period, for any reason other then death, normal retirement², or disability², the participant will be ineligible to receive an award.

²  Normal retirement or disability as defined for shore based employees in the Company’s Profit Sharing Plan, and as defined for wheelhouse employees in the Vessel Pension Plan.

10

Transfer. A participant who is transferred between business units of the Company will be entitled to receive a weighted award based upon the time spent at each of the units. The weighted award is calculated by adding (1) the participant’s prorated award for time spent at the first business unit, to (2) the participant’s prorated award for time spent at the second business unit³.

Promotions. A participant who is promoted or reassigned during any Performance Period, and whose bonus target is subsequently increased or decreased, will be eligible to receive a weighted award. The award is calculated by adding (1) the prorated award for service before the promotion or reassignment, to (2) the prorated award for service after the promotion or reassignment³.

Compensation Committee

The Compensation Committee has the responsibility for the overall governance and administration of the Plan. In fulfilling its duties, the Committee will be responsible for interpreting the Plan and will rely on these guidelines in making all determinations that are necessary or advisable for administration of the Plan.

In administering the Plan the Committee will, on an annual basis:

• Approve the designation of Business Groups within the Company

• Approve the Performance Measures and the Threshold, Target and Maximum budget performance levels for all participants

• Approve linkage for participants to Company and Business Group performance

• Approve the Bonus Levels for all participants whose salaries are at or above $100,000

• Determine in its discretion whether a participant’s award will be decreased

• Certify whether the performance objectives for a Covered Employee have been satisfied prior to payment of an award to a Covered Employee.

The Compensation Committee may deviate from the guidelines for the Plan, but in no event may it increase the amount payable to a Covered Employee upon attaining the performance objectives. The performance objectives of Covered Employees may only be adjusted as permitted under Section 162(m) or the regulations thereunder. In addition, the exercise of negative discretion with respect to any participant is not permitted to result in an increase in the amount payable to another participant who is a Covered Employee.

³ Company and Business Group performance factors are calculated using performance for the entire Performance Period.

11

Chief Executive Officer (“CEO”)

The CEO will have primary responsibility for recommending Plan guidelines to the Committee, and for carrying out the administrative duties associated with annual award calculations. In addition, the Compensation Committee may delegate additional administrative duties to the CEO or any Company officer. The CEO may determine, in his discretion, whether the award to any participant who is not an executive officer of the Company will be decreased (up to a maximum of 25% of the award) based on individual performance. The CEO may recommend, subject to Compensation Committee approval, that the award to any executive officer of the Company be similarly decreased based on individual performance.

12

Chief Financial Officer (“CFO”)

The CFO will be responsible for calculating performance under the Plan and recommending adjustments to the performance objectives. In this capacity, the CFO will:

• Provide annual reports to the Compensation Committee and the CEO on each Business Group’s performance at the end of the Company’s fiscal year

• Maintain a financial information system that reports results on an estimated quarterly and annual basis

• Coordinate with the Company’s auditors to properly recognize any accounting expense associated with awards under the Plan

• Provide the VP of Human Resources with the performance results of each Business Group as well as overall Company performance

• Calculate new Threshold, Target and Maximum performance objectives as required by the Plan

VP of Human Resources

The VP of Human Resources will have primary responsibility for the day-to-day administration of the Plan. In this capacity, the VP of Human Resources will:

• Develop and recommend Target Award Guidelines and eligible participants for each new Performance Period to the CEO for approval

• Coordinate communications with participants, including materials to facilitate understanding the Plan’s objectives and goals

• Provide quarterly performance updates to Plan participants

• Calculate participants’ awards, using the performance factors provided by the CFO

• Process paperwork approving individual award payments

Business Group Presidents and Vice Presidents

Business Group Presidents and Vice Presidents will:

• Recommend participants for each Performance Period

• Coordinate with the CFO to determine any significant changes in business conditions for purposes of reviewing the Threshold, Target and Maximum performance objectives

• Insure that participants are informed of the actual award earned for each Performance Period

13

EX-10.10

Exhibit 10.10

ANNUAL INCENTIVE PLAN

2012 Plan Year

Guidelines

KIRBY CORPORATION

January 2012

TABLE OF CONTENTS

Introduction	2
The Annual Incentive Plan	3
Plan Objectives	3
Performance Period	3
Eligibility	3
Individual Bonus Targets	4
Bonus Pool	4
Performance Goal; Maximum Awards	4
Additional Performance Measures	5
Business Group Designations and Weighting	5
Performance Standards for Recommended Awards	6
Example Calculation of Recommended Award	7
Administration	8

1

Introduction

Kirby Corporation (the “Company”) established this 2012 Annual Incentive Plan (the “Plan”) to focus employees on identifying and achieving business strategies that will grow the business and lead to an increase in stockholder value. The Plan is also intended to reward superior performance by employees and their contributions toward achieving Kirby’s objectives. This program may be offered, in whole or in part, to wholly owned subsidiaries of the Company, at the Company’s discretion.

Certain aspects of this Plan are complex. Although these guidelines establish rules for Plan operation, those rules may not work in all cases. Therefore, the Compensation Committee of the Kirby Board of Directors shall have the discretionary authority to interpret these guidelines to insure that the awards are consistent with the Plan’s purposes and the Company’s interests. All decisions by the Compensation Committee shall be final and binding.

Unless resolutions of the Compensation Committee expressly provide otherwise, awards granted under the Plan shall constitute performance awards granted under Article IV of the Kirby Corporation 2005 Stock and Incentive Plan (as amended from time to time, the “Stock Plan”), and as such, shall be subject to the terms and provisions of the Stock Plan that apply to such performance awards.

This Plan, or any part thereof, may be amended, modified, or terminated at any time, without prior notice, by written authorization of (i) the Compensation Committee or (ii) the Chief Executive Officer of the Company; provided that the Plan may not be amended or modified in a manner that would cause an award that is intended to satisfy the performance-based compensation exception under Section 162(m) of the Internal Revenue Code of 1986, as amended (“Section 162(m)”), to fail to satisfy the exception.

2

The Annual Incentive Plan

Each award granted under the Plan is an award for total Company and designated Business Group performance. Awards are generally based on achieving the Company Performance Goal as well as additional Company, Business Group and individual performance objectives. Once the Performance Goal is reached, participants in the Plan become eligible for a bonus. The Bonus Pool is calculated as provided in the Plan. The Compensation Committee may decrease the Maximum Award to any participant based on the recommended award amounts determined as provided in the Plan and/or on individual performance.

Plan Objectives

The Plan has five key objectives:

• Provide an annual incentive plan that drives performance toward objectives critical to creating stockholder value.

• Offer competitive cash compensation opportunities to key Kirby employees.

• Award outstanding achievement by employees who can directly affect Kirby’s results.

• Assist Kirby in attracting and retaining high quality employees.

• Reflect both quantitative and qualitative performance factors in actual bonus payouts.

Performance Period

Performance is measured on a calendar year basis for the Plan. The Performance Period begins on January 1, 2012 and ends on December 31, 2012.

Eligibility

• Generally, managerial employees in salary grades 15 and above, and Kirby Inland Marine Wheelhouse employees classified as Captain, Relief Captain or Pilot, are eligible for participation. Selection for participation in the Plan is based upon each position’s ability to impact long-term financial results of the Company and designation by management. Consequently, some employees in positions at salary grades 15 and above might not be included in the Plan, and some employees in positions below salary grade 15 might be included.

• In order to be eligible to receive an award, participants must be employed on the last day of the Performance Period, and on the date bonuses are actually paid for the Performance Period, unless their earlier termination is due to

3

death, normal retirement¹ or disability¹. If a participant’s employment is terminated after the last day of the Performance Period, but prior to the date of payment, for any reason other than death, normal retirement¹ or disability¹, the bonus the participant may otherwise have received will be distributed among other participants receiving annual incentive awards under the Plan. A “covered employee” as defined for purposes of Section 162(m) (a “Covered Employee”) is not eligible for the reallocated amounts.

• Participation in the Plan in one year does not guarantee participation in similar plans in future years. Participants in the Plan or in similar plans in future years will be notified annually of their selection for participation.

Individual Bonus Targets

Each participant will be assigned a target bonus level defined as a percentage of base salary earned during the Performance Period. This bonus target is based on competitive market practices, as well as the employee’s ability to impact long-term Company performance. Market practices will be determined using data from either general industry, the marine transportation industry, or the diesel engine services industry, depending upon the individual position being considered. The Company’s intent is that salary plus target annual bonus will provide competitive market compensation for target performance.

Bonus Pool

The aggregate bonus pool for the Performance Period (the “Bonus Pool”) will be equal to the sum of the recommended bonus amounts determined for each individual participant based on the achievement by the Company of the three additional performance measures as provided in the Plan. The Company will be obligated to pay out the full amount of the Bonus Pool to eligible participants, subject to the discretion of the Compensation Committee with respect to the allocation of the Bonus Pool among individual participants. The obligation of the Company to pay out the full amount of the Bonus Pool becomes fixed on the last day of the Performance Period. The Compensation Committee may determine the amount of the bonus paid to any participant based on the additional performance measures described in the Plan or any other criteria the Compensation Committee deems appropriate in its discretion, provided that in no event will a bonus paid pursuant to the Plan exceed the Maximum Award for any Covered Employee.

Performance Goal; Maximum Awards

The performance goal (the “Performance Goal”) that must be attained in order for any Plan participants to receive a bonus under the Plan is the achievement by the Company of net earnings for 2012 (as shown in Kirby’s audited Consolidated Statement of Earnings for 2012) greater than $1,000,000. If the Company achieves the Performance Goal, the maximum bonus that each participant may receive

¹  Normal retirement or disability as defined for shore based employees in the Company’s Profit Sharing Plan, and as defined for wheelhouse employees in the Vessel Pension Plan

4

under the Plan will be equal to 200% of the individual bonus target established for such participant (for each participant, the “Maximum Award”). The Compensation Committee in its discretion may reduce the bonus paid to any participant to an amount less than the Maximum Award.

Additional Performance Measures

In addition to the Performance Goal, the additional performance measures under the plan are:

• EBITDA

• Return on Total Capital

• Earnings per share

Annual performance targets will be established for each measure based on Kirby’s projected budget, and each of the performance measures will have equal weight in calculating the recommended bonus payout for each participant.

Measure	Weight
n        EBITDA (Earnings Before Interest, Taxes, Depreciation and Amortization)	33-1/3 %
n        Return on Total Capital (Earnings before interest and taxes divided by average beginning and ending  stockholders’ equity plus long-term debt)	33-1/3 %
n        Earnings per Share	33-1/3 %
	100%

Business Group Designations and Weightings

The following business groups are designated for purposes of the Plan:

• Kirby Inland Marine

• Kirby Engine Systems

• United Holdings

• K-Sea Transportation

Kirby Ocean Transport Company and Osprey Line, LLC are considered part of the Kirby Inland Marine business group for purposes of the Plan.

5

In calculating actual versus target performance against the additional performance measures, the recommended award for Business Group employees will be primarily based on Business Group performance, with a defined portion based on Company performance. The award for Corporate employees will be based on total Kirby performance. Specific weightings are defined in the following table.

Calculation of Recommended Awards
	Incentive Bonus Calculation %
	Kirby (Company)	Business Group
All Corporate Employees	100%	0%
Business Group Employees	30%	70%
Business Group Presidents (Kirby Inland Marine, Kirby Engine Systems, United Holdings, K-Sea Transportation)	50%	50%
Corporate Executive Vice President, Engine Systems	30%	35%/35%*
*  For EVP, Engine systems, the weightings are 30% Company, 35% Kirby Engine Systems, 35% United Holdings

Performance Standards for Recommended Awards

Performance Level	Definition	Relationship to Budget	% of Target Earned
Threshold	Minimal acceptable performance for payout	80% of Budget	50%
Target	Expected performance at a stretch level	100% of Budget	100%
Maximum	Outstanding performance	120% of Budget	200%

6

Example Calculation of Recommended Award

	Performance Standards												Example Calculation
Performance Objectives	Below Threshold			Threshold			Target			Maximum			Assumed Actual Results (% Budget Achieved)			Percent of Target Award Earned			Objective Weight			Weighted Percent of Target Award Earned
Percent of Target Award Earned:		0	%		50	%		100	%		200	%
EBITDA (% Budget Achieved)		< 80	%		80	%		100	%		120	%		90	%		75	%		33-1/3	%		25	%
Return on Total Capital (% Budget Achieved)		< 80	%		80	%		100	%		120	%		110	%		150	%		33-1/3	%		50	%
Earnings per Share (% Budget Achieved)		< 80	%		80	%		100	%		120	%		100	%		100	%		33-1/3	%		33.3	%
					Recommended Award as a Percent of Target Award																		108.3	%

n As shown in the table, actual performance on each objective results in a corresponding percent of target award earned.

n The percents of target award earned for each objective are then multiplied by the weight for the objective, producing a weighted percent of target award earned for each objective.

n The weighted percents of target award earned for all three additional performance measures are summed to produce a total percent of target award earned for purposes of calculating the recommended awards for a participant.

n The Compensation Committee shall allocate the Bonus Pool among eligible participants. In allocating the Bonus Pool, the Compensation Committee shall consider, but shall not be bound by, the recommended award for each participant.

n The Compensation Committee has discretion to modify the additional performance measures or adjust the calculation of the recommended awards to adjust for acquisitions, divestures, and other material business events.

7

Administration

Award Payout

A participant’s final award is paid out in cash within 90 days following the end of the Company’s fiscal year, based on audited financials. No payment shall be made to a participant who is a Covered Employee until the Compensation Committee certifies that the performance objectives that result in such payment have been achieved.

Eligibility Limitation

Unless otherwise provided for in the Plan, participants must be employed by the Company on the last day of the Performance Period, and on the date bonuses are actually paid for the Performance Period, in order to be eligible to receive a bonus award.

Special Circumstances

Listed below are guidelines addressing payment of awards upon termination and other events. The Compensation Committee will have the sole authority to resolve disputes related to Plan administration. Decisions made by the Compensation Committee will be final and binding on all participants.

New Employees. New employees hired after the beginning of a Performance Period who are selected for participation in the Plan, will receive prorated awards for the then current Performance Period, subject to the Termination of Employment restrictions.

Termination of Employment. If employment terminates before the end of the full Performance Period, or before the date bonuses are actually paid for the Performance Period, as a result of death, normal retirement², or disability², the participant (or the participant’s heirs) will be entitled to receive a prorated award at the end of the Performance Period, based upon actual performance and base wages earned while employed during the Performance Period.

If employment terminates prior to the last day of the Performance Period, or prior to the date bonuses are actually paid for the respective Performance Period, for any reason other then death, normal retirement², or disability², the participant will be ineligible to receive an award.

Transfer. A participant who is transferred between business units of the Company will be entitled to receive a weighted award based upon the time spent at each of the units. The weighted award is based on a recommended award calculated by adding (1) the participant’s prorated recommended award for time spent at the first business unit, to (2) the participant’s prorated recommended award for time spent at the second business unit³.

Promotions. A participant who is promoted or reassigned during any Performance Period, and whose bonus target is subsequently increased or decreased, will be eligible to receive a weighted award. The weighted award will be based on a recommended award calculated by adding (1) the prorated recommended award for service before the promotion or reassignment, to (2) the prorated recommended award for service after the promotion or reassignment³.

8

Compensation Committee

The Compensation Committee has the responsibility for the overall governance and administration of the Plan. In fulfilling its duties, the Compensation Committee will be responsible for interpreting the Plan and will rely on these guidelines in making all determinations that are necessary or advisable for administration of the Plan.

In administering the Plan the Compensation Committee will, on an annual basis:

• Approve the designation of Business Groups within the Company

• Approve the Performance Goal

• Approve the additional performance measures and the Threshold, Target and Maximum budget performance levels for all participants for purposes of calculating recommended awards

• Approve linkage for participants to Company and Business Group performance

• Approve the individual bonus targets for all participants whose salaries are at or above $100,000

• Determine at its discretion reductions to the Maximum Awards for participants

• Approve the final bonuses to be paid to all participants in the Plan

• Certify whether the Performance Goal has been satisfied prior to payment of an award to a Covered Employee.

The Compensation Committee may deviate from the guidelines for the Plan, but in no event will a bonus paid pursuant to the Plan exceed the Maximum Award for any Covered Employee. The Compensation Committee may decrease the bonus payable to any participant below the Maximum Award based on such objective or subjective criteria as the Compensation Committee deems appropriate in its discretion. The total amount of the bonuses paid to participants pursuant to the Plan may not exceed the amount of the Bonus Pool. The performance objectives of Covered Employees may only be adjusted as permitted under Section 162(m) or the regulations thereunder.

²  Normal retirement or disability as defined for shore based employees in the Company’s Profit Sharing Plan, and as defined for wheelhouse employees in the Vessel Pension Plan.

³ Company and Business Group performance factors are calculated using performance for the entire Performance Period.

9

Chief Executive Officer (“CEO”)

The CEO will have primary responsibility for recommending Plan guidelines to the Committee, and for carrying out the administrative duties associated with annual award calculations. In addition, the Compensation Committee may delegate additional administrative duties to the CEO or any Company officer. The CEO may make recommendations, subject to Compensation Committee approval, with respect to the award to any participant in the Plan .

Chief Financial Officer (“CFO”)

The CFO will be responsible for calculating performance under the Plan and recommending adjustments to the performance objectives. In this capacity, the CFO will:

• Provide annual reports to the Compensation Committee and the CEO on each Business Group’s performance at the end of the Company’s fiscal year

• Maintain a financial information system that reports results on an estimated quarterly and annual basis

• Coordinate with the Company’s auditors to properly recognize any accounting expense associated with awards under the Plan

• Provide the VP of Human Resources with the performance results of each Business Group as well as overall Company performance

• Calculate new Threshold, Target and Maximum performance objectives as required by the Plan for purposes of determining recommended awards

VP of Human Resources

The VP of Human Resources will have primary responsibility for the day-to-day administration of the Plan. In this capacity, the VP of Human Resources will:

• Develop and recommend Target Award Guidelines and eligible participants for each new Performance Period to the CEO for approval

• Coordinate communications with participants, including materials to facilitate understanding the Plan’s objectives and goals

• Provide quarterly performance updates to Plan participants

• Calculate participants’ recommended awards, using the performance factors provided by the CFO

• Process paperwork approving individual award payments

10

Business Group Presidents and Vice Presidents

Business Group Presidents and Vice Presidents will:

• Recommend participants for each Performance Period

• Coordinate with the CFO to determine any significant changes in business conditions for purposes of reviewing the Threshold, Target and Maximum performance objectives for purposes of calculating recommended awards

• Insure that participants are informed of the actual award earned for each Performance Period

11

EX-21.1

EXHIBIT 21.1

KIRBY CORPORATION

PRINCIPAL SUBSIDIARIES OF THE REGISTRANT

	Domicile of Incorporation
KIRBY CORPORATION — PARENT AND REGISTRANT	Nevada
SUBSIDIARIES OF THE PARENT AND REGISTRANT
Kirby Corporate Services, LLC(1)	Delaware
KIM Holdings, Inc.(1)	Delaware
Kirby Terminals, Inc.(1)	Texas
Sabine Transportation Company(1)	Delaware
AFRAM Carriers, Inc.(1)	Delaware
Kirby Engine Systems, Inc.(1)	Delaware
Kirby Tankships, Inc.(1)	Delaware
Kirby Ocean Transport Company(1)	Delaware
K-Sea Transportation Partners LLC(1)	Delaware
CONTROLLED CORPORATIONS
KIM Partners, LLC (Subsidiary of KIM Holdings, Inc.)(1)	Louisiana
Kirby Inland Marine, LP (KIM Holdings, Inc. 1% General Partner, KIM Partners, LLC 99% Limited Partner)(1)	Delaware
Greens Bayou Fleeting, LLC (51%)(1)	Texas
Dixie Carriers, Inc. (subsidiary of Kirby Inland Marine, LP)(1)	Texas
Marine Systems, Inc. (subsidiary of Kirby Engine Systems, Inc.)(1)	Louisiana
Rail Systems, Inc. (subsidiary of Kirby Engine Systems, Inc.)(1)	Delaware
Engine Systems, Inc. (subsidiary of Kirby Engine Systems, Inc.)(1)	Delaware
Osprey Line, L.L.C. (66 2/3%)(1)	Texas
Marine Highways, LLC (40%)(1)	Delaware
United Holdings LLC (subsidiary of Kirby Engine Systems, Inc.)(1)	Delaware
United Engines LLC (subsidiary of United Holdings LLC)(1)	Colorado
Universal Engine Services LLC (subsidiary of United Holdings LLC)(1)	Texas
UE Powertrain GP LLC (subsidiary of United Holdings LLC)(1)	Texas
UE Manufacturing LLC (subsidiary of United Holdings LLC)(1)	Colorado
UE Compression LLC (subsidiary of United Holdings LLC)(1)	Colorado
Thermo King of Houston, LP (subsidiary of United Holdings LLC)(1)	Texas
San Antonio Thermo King, Inc. (subsidiary of Thermo King of Houston, LP)(1)	Texas
UE Powertrain LP (subsidiary of United Holdings LLC and UE Powertrain GP LLC)(1)	Texas
K-Sea Operating LLC (subsidiary of K-Sea Transportation Partners LLC)(1)	Delaware
Smith Maritime LLC (subsidiary of K-Sea Operating LLC)(1)	Delaware
K-Sea Transportation LLC (subsidiary of K-Sea Operating LLC)(1)	Delaware
K-Sea Transportation, Inc. (subsidiary of K-Sea Operating LLC)(1)	Delaware
Inversiones Kara Sea SRL (subsidiary of K-Sea Operating LLC)(1)	Venezuela
K-Sea Canada Holdings, Inc. (subsidiary of K-Sea Transportation, Inc.)(1)	Delaware
K-Sea Hawaii, Inc. (subsidiary of K-Sea Transportation, Inc.(1)	Delaware
Norfork Environmental Services, Inc. (subsidiary of K-Sea Transportation, Inc.)(1)	Delaware
K-Sea Canada Corp. (subsidiary of K-Sea Canada Holdings, Inc.)(1)	Nova Scotia

(1) Included in the consolidated financial statements.

EX-23.1

EXHIBIT 23.1

Consent of Independent Registered Public Accounting Firm

The Board of Directors and Stockholders

Kirby Corporation:

We consent to the incorporation by reference in the registration statements (No. 333-57625, No. 333-72592, No. 333-129290, No. 333-129333, No. 333-152565, and No. 333-152566) on Form S-8 of Kirby Corporation and consolidated subsidiaries of our reports dated February 28, 2012, with respect to the consolidated balance sheets of Kirby Corporation and consolidated subsidiaries as of December 31, 2011 and 2010, and the related consolidated statements of earnings, stockholders’ equity and comprehensive income, and cash flows for each of the years in the three-year period ended December 31, 2011, and the effectiveness of internal control over financial reporting as of December 31, 2011, which reports appear in the December 31, 2011 annual report on Form 10-K of Kirby Corporation and consolidated subsidiaries.

KPMG LLP

Houston, Texas

February 28, 2012

EX-31.1

EXHIBIT 31.1

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

In connection with the filing of the report on Form 10-K for the year ended December 31, 2011 by Kirby Corporation, Joseph H. Pyne certifies that:

1. I have reviewed this report on Form 10-K of Kirby Corporation (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    JOSEPH H. PYNE

Joseph H. Pyne

Chairman of the Board and

Chief Executive Officer

Dated: February 28, 2012

EX-31.2

EXHIBIT 31.2

CERTIFICATION OF CHIEF FINANCIAL OFFICER

In connection with the filing of the report on Form 10-K for the year ended December 31, 2011 by Kirby Corporation, David W. Grzebinski certifies that:

1. I have reviewed this report on Form 10-K of Kirby Corporation (the “registrant”);

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    DAVID W. GRZEBINSKI

David W. Grzebinski

Executive Vice President and
Chief Financial Officer

Dated: February 28, 2012

EX-32

EXHIBIT 32

Certification Pursuant to Section 18 U.S.C. Section 1350

(As adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002)

In connection with the filing of the Annual Report on Form 10-K for the year ended December 31, 2011(the “Report”) by Kirby Corporation (the “Company”), each of the undersigned hereby certifies that:

1. The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/    JOSEPH H. PYNE

Joseph H. Pyne

Chairman of the Board and

Chief Executive Officer

/s/    DAVID W. GRZEBINSKI

David W. Grzebinski

Executive Vice President and

Chief Financial Officer

Dated: February 28, 2012

XML

Acquisitions (Total Consideration Transferred For United Holdings LLC) (Details) (United Holdings LLC [Member], USD $)	Apr. 15, 2011
United Holdings LLC [Member]
Business Acquisition [Line Items]
Cash consideration paid	$ 271,192,000
Fair value of contingent earnout provision payable in 2014	16,300,000
Fair value of consideration transferred	$ 287,492,000

XML

Taxes On Income (Schedule Of Effective Income Tax Rate Reconciliation) (Details)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Taxes On Income [Abstract]
United States income tax statutory rate	35.00%	35.00%	35.00%
State and local taxes, net of federal benefit	2.20%	2.90%	2.90%
Other - net	(0.10%)	0.20%	0.10%
Effective income tax rate	37.10%	38.10%	38.00%

XML

Derivative Instruments (Cash Flow Hedges) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	$ 7,936	$ (2,327)	$ 5,650
Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(8,599)	(8,940)	(7,356)
Interest Rate Contracts [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	7,007	(908)	5,701
Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	(8,586)	(8,529)	(7,356)
Foreign Exchange Contracts [Member] | Cost Of Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)	929	(1,419)	(51)
Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)	$ (13)	$ (411)

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Retirement Plans (Summary Of Asset Allocation) (Details)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	100.00%	100.00%
U.S. Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations, Equity securities	43.00%	50.00%
Target allocation, Equity securities minimum	30.00%
Target allocation, Equity securities	50.00%
Target allocation, Equity securities maximum	70.00%
International Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations, Equity securities	16.00%	20.00%
Target allocation, Equity securities minimum	0.00%
Target allocation, Equity securities	20.00%
Target allocation, Equity securities maximum	30.00%
Debt Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations, Debt securities	25.00%	29.00%
Target allocation, Debt securities minimum	15.00%
Target allocation, Debt securities	30.00%
Target allocation, Debt securities maximum	55.00%
Cash And Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations, Other	16.00%	1.00%
Target allocation, Other minimum	0.00%
Target allocation, Other	0.00%
Target allocation, Other maximum	5.00%

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Taxes On Income (Schedule Of Deferred Tax Assets And Liabilities) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Taxes On Income [Abstract]
Compensated absences	$ 695	$ 518
Allowance for doubtful accounts	1,752	1,400
Insurance accruals	4,150	2,319
Other	7,589	2,181
Deferred tax assets, net, current, total	14,186	6,418
Postretirement health care benefits	3,422	3,548
Insurance accruals	1,420	876
Deferred compensation	8,290	7,456
Unrealized loss on derivative financial instruments	3,384	6,162
Unrealized loss on defined benefit plans	28,114	12,582
Operating loss carryforwards	1,305	1,023
Other	9,047	9,177
Deferred tax assets	54,982	40,824
Property	(298,335)	(234,732)
Deferred state taxes	(25,738)	(22,571)
Pension benefits	(15,376)	(8,738)
Goodwill and other intangibles	(6,563)	(5,538)
Other	(1,325)	(1,020)
Deferred tax liabilities	(347,337)	(272,599)
Deferred tax assets (liabilities)	$ (292,355)	$ (231,775)

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Retirement Plans (Projected Benefit Obligation In Excess Of Plan Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at end of year	$ 216,926	$ 170,742
Fair value of plan assets at end of year	174,223	152,696
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at end of year	$ 1,645	$ 1,511

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Derivative Instruments (Interest Rate Risk Management) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011
Fixed Pay Rate 5.45% [Member]
Derivative [Line Items]
Notional Amount	$ 100,000
Effective date	Mar. 01, 2006
Termination date	Feb. 01, 2013
Fixed pay rate	5.45%
Receive rate	Three-month LIBOR
Fixed Pay Rate 3.50% [Member]
Derivative [Line Items]
Notional Amount	50,000
Effective date	Nov. 01, 2008
Termination date	Feb. 01, 2013
Fixed pay rate	3.50%
Receive rate	Three-month LIBOR
Fixed Pay Rate 3.795% [Member]
Derivative [Line Items]
Notional Amount	$ 50,000
Effective date	May 01, 2009
Termination date	Feb. 01, 2013
Fixed pay rate	3.795%
Receive rate	Three-month LIBOR

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Earnings Per Share (Tables)

12 Months Ended

Dec. 31, 2011

Earnings Per Share [Abstract]

Earnings Per Share

	2011			2010			2009
Net earnings attributable to Kirby	$	183,026		$	116,249		$	125,941
Undistributed earnings allocated to restricted shares		(1,613	)		(1,125	)		(1,403	)
Income available to Kirby common stockholders — basic		181,413			115,124			124,538
Undistributed earnings allocated to restricted shares		1,613			1,125			1,403
Undistributed earnings reallocated to restricted shares		(1,606	)		(1,122	)		(1,400	)
Income available to Kirby common stockholders — diluted	$	181,420		$	115,127		$	124,541
Shares outstanding:
Weighted average common stock issued and outstanding		54,673			53,852			53,791
Weighted average unvested restricted stock		(482	)		(521	)		(599	)
Weighted average common stock outstanding — basic		54,191			53,331			53,192
Dilutive effect of stock options		222			135			121
Weighted average common stock outstanding — diluted		54,413			53,466			53,313
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.35		$	2.16		$	2.34
Diluted	$	3.33		$	2.15		$	2.34

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Retirement Plans (Accumulated Benefit Obligation In Excess Of Plan Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at end of year	$ 216,926
Accumulated benefit obligation at end of year	179,190
Fair value of plan assets at end of year	174,223
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at end of year	1,645	1,511
Accumulated benefit obligation at end of year	$ 1,645	$ 1,511

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Retirement Plans (Effect Of One-Percentage-Point Change In Assumed Health Care Cost Trend Rate) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation, Increase
Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation, Decrease
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation, Increase
Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation, Decrease
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation, Increase	285	223
Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation, Decrease	(250)	(196)
Effect of one-percentage-point change in assumed health care cost trend rate on aggregate service and interest cost, Increase	16	14	12
Effect of one-percentage-point change in assumed health care cost trend rate on aggregate service and interest cost, Decrease	$ (14)	$ (12)	$ (11)

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Contingencies And Commitments (Details) (USD $)	1 Months Ended	3 Months Ended	12 Months Ended			12 Months Ended		1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended
	Mar. 31, 2010	Sep. 30, 2007	Dec. 31, 2011 years	Dec. 31, 2000	Jul. 31, 2008	Dec. 31, 2011 Performance Bonds [Member]	Dec. 31, 2011 Letters Of Credit And Debt Guarantees [Member]	Jul. 31, 2008 Palmer Barge Line Superfund Site [Member]	Dec. 31, 2000 Palmer Barge Line Superfund Site [Member]	Mar. 31, 2010 State Marine Of Port Arthur Superfund Site [Member]	Dec. 31, 2000 State Marine Of Port Arthur Superfund Site [Member]	Dec. 31, 2009 LWG Superfund Site [Member]	Dec. 31, 2011 Marine Transportation's [Member]	Dec. 31, 2011 Maximum [Member]	Dec. 31, 2011 Minimum [Member]	Dec. 31, 2011 The Dow Chemical Company [Member]	Dec. 31, 2010 The Dow Chemical Company [Member]	Dec. 31, 2009 The Dow Chemical Company [Member]	Dec. 31, 2010 SeaRiver Maritime Inc [Member]	Dec. 31, 2009 SeaRiver Maritime Inc [Member]
Summary of Investments, Other than Investments in Related Parties, Reportable Data [Line Items]
Cleanup expense			$ 3,500,000
EPA oversight costs			1,800,000
Number of companies named as PRPs												250
Other companies									45		50
Number of potentially responsible party letters								30		7
Number of spills												4
Additional number of companies entered into EPA agreement		5		3
Costs incurred in relation to the site					2,949,000
Reimbursement of costs in connection with clean-up activities	2,977,000
Notional value of debt instruments			$ 26,329,000			$ 17,069,000	$ 9,260,000
Maturity date of debt instruments, maximum (years)			3
Percentage of inland revenue													75.00%
Percentage of coastwise and local revenue													60.00%
Range of renewal options under term contracts														five	one
Percentage of customers revenue																10.00%	12.00%	11.00%	11.00%	10.00%
Segment operates authorized distributors			17
Diesel engine services segment's relationship (years)			46

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Leases (Narrative) (Details)	12 Months Ended
	Dec. 31, 2011 years
Minimum [Member] | Tank Barges [Member]
Operating Leased Assets [Line Items]
Lease agreements expiring terms	1
Minimum [Member] | Towing Vessels [Member]
Operating Leased Assets [Line Items]
Lease agreements expiring terms	30
Maximum [Member] | Tank Barges [Member]
Operating Leased Assets [Line Items]
Lease agreements expiring terms	10
Maximum [Member] | Towing Vessels [Member]
Operating Leased Assets [Line Items]
Lease agreements expiring terms	5

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Retirement Plans (Amounts Recognized In The Consolidated Balance Sheets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term liability	$ (42,703)	$ (18,046)
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Current liability	(102)	(102)
Long-term liability	(1,543)	(1,409)
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Current liability	(256)	(246)
Long-term liability	$ (2,758)	$ (2,544)

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Earnings Per Share (Narrative) (Details)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Earnings Per Share [Abstract]
Antidilutive securities excluded from computation of earnings per share	2,000	114,000	248,000

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Retirement Plans (Expected Benefit Payments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Year one	$ 5,142	$ 4,639
Year two	5,590	5,058
Year three	6,113	5,480
Year four	6,649	5,997
Year five	7,252	6,524
Next five years	47,701	42,703
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Year one	102	102
Year two	100	100
Year three	98	99
Year four	97	97
Year five	105	95
Next five years	597	558
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Year one	271	262
Year two	264	261
Year three	268	253
Year four	271	257
Year five	271	258
Next five years	$ 1,343	$ 1,274

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Earnings Per Share (Earnings Per Share) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Earnings Per Share [Abstract]
Net earnings attributable to Kirby	$ 56,170	$ 52,734	$ 41,692	$ 32,430	$ 31,620	$ 30,687	$ 29,268	$ 24,674	$ 183,026	$ 116,249	$ 125,941
Undistributed earnings allocated to restricted shares									(1,613)	(1,125)	(1,403)
Income available to Kirby common stockholders - basic									181,413	115,124	124,538
Undistributed earnings allocated to restricted shares									1,613	1,125	1,403
Undistributed earnings reallocated to restricted shares									(1,606)	(1,122)	(1,400)
Income available to Kirby common stockholders - diluted									$ 181,420	$ 115,127	$ 124,541
Weighted average common stock issued and outstanding									54,673	53,852	53,791
Weighted average unvested restricted stock									(482)	(521)	(599)
Weighted average common stock outstanding - basic									54,191	53,331	53,192
Dilutive effect of stock options									222	135	121
Weighted average common stock outstanding - diluted									54,413	53,466	53,313
Basic	$ 1.01	$ 0.95	$ 0.78	$ 0.60	$ 0.59	$ 0.57	$ 0.54	$ 0.46	$ 3.35	$ 2.16	$ 2.34
Diluted	$ 1.00	$ 0.94	$ 0.77	$ 0.60	$ 0.59	$ 0.57	$ 0.54	$ 0.46	$ 3.33	$ 2.15	$ 2.34

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Retirement Plans (Amounts Recognized In Accumulated Other Comprehensive Income) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss (gain)	$ 86,633	$ 43,048
Prior service cost (credit)		(38)
Accumulated other compensation income	86,633	43,010
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss (gain)	442	293
Accumulated other compensation income	442	293
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net actuarial loss (gain)	(6,751)	(7,523)
Prior service cost (credit)		158
Accumulated other compensation income	$ (6,751)	$ (7,365)

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Retirement Plans (Schedule Of Change In Benefit Obligation) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year	$ 170,742	$ 141,338
Service cost	7,303	6,883	6,523
Interest cost	9,693	9,399	8,486
Actuarial loss (gain)	33,662	17,124
Gross benefits paid	(4,474)	(4,002)
Benefit obligation at end of year	216,926	170,742	141,338
Accumulated benefit obligation at end of year	179,190	141,666
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year	1,511	1,429
Interest cost	80	84	84
Actuarial loss (gain)	157	101
Gross benefits paid	(103)	(103)
Benefit obligation at end of year	1,645	1,511	1,429
Accumulated benefit obligation at end of year	1,645	1,511
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of year	2,790	5,459
Service cost			246
Interest cost	164	154	322
Actuarial loss (gain)	182	(3,108)
Plan amendments		519
Gross benefits paid	(122)	(234)
Benefit obligation at end of year	$ 3,014	$ 2,790	$ 5,459

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Inventories (Tables)

12 Months Ended

Dec. 31, 2011

Inventories [Abstract]

Schedule Of Inventories

	December 31, 2011		December 31, 2010
Finished goods	$	111,931	$	35,719
Work in process		18,199		3,102
	$	130,130	$	38,821

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Long-Term Debt (Schedule Of Long-Term Debt) (Details) (USD $)			12 Months Ended				12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2011 Term Loan Due May 31, 2016 [Member]	Dec. 31, 2011 Revolving Credit Facility Due November 9, 2015 [Member]	Dec. 31, 2011 Term Loan [Member]	May 31, 2011 Term Loan [Member]	Dec. 31, 2011 Revolving Credit Facility [Member]	Dec. 31, 2011 Senior Notes [Member]	Dec. 31, 2011 Senior Notes Due February 28, 2013 [Member]	Dec. 31, 2010 Senior Notes Due February 28, 2013 [Member]
Debt Instrument [Line Items]
Credit facility, amount outstanding			$ 507,000,000	$ 95,000,000	$ 507,000,000		$ 95,000,000
Senior notes due February 28, 2013									200,000,000	200,000,000
Other long-term debt	5,000	134,000
Long-term Debt	802,005,000	200,134,000
Credit facility, expiration date			May 31, 2016	November 9, 2015	July 1, 2016		November 9, 2015	February 28, 2013
Line of Credit Facility, Maximum Borrowing Capacity					$ 540,000,000	$ 540,000,000	$ 250,000,000

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Inventories (Schedule Of Inventories) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Inventories [Abstract]
Finished goods	$ 111,931	$ 35,719
Work in process	18,199	3,102
Inventories - net	$ 130,130	$ 38,821

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Retirement Plans (Summary Of Funded Status At End Of Year) (Details) (USD $)	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 174,223,000	$ 152,696,000
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	174,223,000	152,696,000	126,490,000
Benefit obligations	216,926,000	170,742,000	141,338,000
Funded status and amount recognized at end of year	(42,703,000)	(18,046,000)
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligations	1,645,000	1,511,000	1,429,000
Funded status and amount recognized at end of year	(1,645,000)	(1,511,000)
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligations	3,014,000	2,790,000	5,459,000
Funded status and amount recognized at end of year	$ (3,014,000)	$ (2,790,000)

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Acquisitions (Narrative) (Details) (USD $)	1 Months Ended			0 Months Ended				1 Months Ended	12 Months Ended	1 Months Ended		0 Months Ended		12 Months Ended
	Jul. 31, 2011 years	Apr. 30, 2011 years	Feb. 09, 2011	Dec. 15, 2011 Seaboats, Inc. [Member] years	Apr. 15, 2011 United Holdings LLC [Member]	Feb. 24, 2011 Enterprise Marine Services LLC [Member]	Feb. 09, 2011 Kinder Morgan Petcoke, L.P. [Member]	Jul. 31, 2011 K-Sea Transportation Partners L.P. [Member]	Dec. 31, 2011 K-Sea Transportation Partners L.P. [Member] MMbls years	Jul. 31, 2011 K-Sea Transportation Partners L.P. [Member] Common Stock [Member]	Dec. 31, 2011 Tank Barges [Member]	Dec. 15, 2011 Tank Barges [Member] Seaboats, Inc. [Member] bbl	Feb. 24, 2011 Tank Barges [Member] Enterprise Marine Services LLC [Member]	Dec. 31, 2011 Tank Barges [Member] K-Sea Transportation Partners L.P. [Member]	Dec. 31, 2011 Tugboats [Member] K-Sea Transportation Partners L.P. [Member]	Feb. 24, 2011 Towboat [Member] Enterprise Marine Services LLC [Member]
Business Acquisition [Line Items]
Purchase of assets								$ 603,427,000
Cash consideration paid				42,745,000	271,192,000	53,200,000	4,050,000	227,617,000
Cash to retire K-Sea's outstanding debt								262,791,000
Stock consideration through issuance of Company common stock								113,019,000
Issue of common stock								1,939,234
Shares issued per share										$ 58.28
Number of productive assets purchased											3		21	57	63	15
Capacity, in barrels, of purchased productive assets									3.8			80,000
Number of doubled hulled tank barges														54
Useful life of purchased productive assets, years				5					9
Number of operational locations					21
Number of operational states					7
Goodwill	113,973,000	132,302,000			132,302,000			113,973,000
Net intangibles	11,400,000	75,697,000
Weighted average amortization period, in years	11	16
Acquisition and integration related costs	5,353,000	760,000
Earnout provisional for payment to additional payables					50,000,000
Percentage of ownership acquired			51.00%
Noncontrolling interest attributable to parent							49.00%
Purchase price of towboat			$ 1,250,000

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Taxes On Income (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Taxes On Income [Abstract]
Tax benefit realized from equity compensation plans	$ 1,348,000	$ 373,000	$ 1,013,000
Operating loss carryforwards	1,305,000	1,023,000
Expiration dates, operating loss carryforwards	2030
Unrecognized tax benefits includes interest and penalties	2,509,000
Unrecognized tax benefits impact on effective tax rate	1,775,000
Expense (income) in interest and penalties	16,000	43,000	(221,000)
Accrued liabilities for payment of interest and penalties	$ 977,000	$ 993,000	$ 964,000

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Stock Award Plans (Summary Of Restricted Stock Award Activity, Director) (Details) (Director Plans [Member], USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Director Plans [Member]
Unvested Restricted Stock Award Shares
Beginning balance	525	732	390
Granted, Unvested Restricted Stock Award Shares	11,990	11,097	10,919
Vested, Unvested Restricted Stock Award Shares	(10,767)	(11,304)	(10,577)
Ending balance	1,748	525	732
Weighted Average Grant Date Fair Value Per Share
Beginning balance	$ 41.33	$ 29.77	$ 56.00
Granted, Weighted Average Grant Date Fair Value Per Share	$ 56.85	$ 41.33	$ 29.77
Vested, Weighted Average Grant Date Fair Value Per Share	$ 55.90	$ 40.58	$ 30.74
Ending balance	$ 58.07	$ 41.33	$ 29.77

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Stock Award Plans (Compensation Cost Breakdown In Statement Of Earnings) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Stock Award Plans [Abstract]
Compensation cost	$ 9,228	$ 10,867	$ 9,855
Income tax benefit	$ 3,534	$ 4,162	$ 3,775

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Derivative Instruments (Fair Value Of Derivative Instruments) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Derivatives, Fair Value [Line Items]
Total derivatives designated as hedging instruments under ASC 815	$ 9,597	$ 17,576
Total liability derivatives	9,597	17,576
Other Accrued Liabilities [Member]
Derivatives, Fair Value [Line Items]
Foreign currency contracts, liability, fair value disclosure	363	798
Other Long-Term Liabilities [Member]
Derivatives, Fair Value [Line Items]
Foreign currency contracts, liability, fair value disclosure	32	569
Interest rate fair value hedge liability at fair value	$ 9,202	$ 16,209

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Acquisitions

12 Months Ended

Dec. 31, 2011

Acquisitions [Abstract]

Acquisitions

(2) Acquisitions

On December 15, 2011, the Company completed the purchase of the coastal tank barge fleet of Seaboats, Inc. and affiliated companies ("Seaboats") consisting of three 80,000 barrel coastal tank barges and tugboats for $42,745,000 in cash. The three coastal tank barges and tugboats currently operate along the United States East Coast and have an average age of five years.

On July 1, 2011, the Company completed the acquisition of K-Sea Transportation Partners L.P. ("K-Sea"), an operator of tank barges and tugboats participating in the coastal transportation primarily of refined petroleum products in the United States. The total value of the transaction was $603,427,000, excluding transaction fees, consisting of $227,617,000 of cash paid to K-Sea common and preferred unit holders and the general partner, $262,791,000 of cash to retire K-Sea's outstanding debt, and $113,019,000 through the issuance of 1,939,234 shares of Company common stock valued at $58.28 per share, the Company's closing share price on July 1, 2011.

On the acquisition date, K-Sea's fleet, comprised of 57 coastal tank barges with a capacity of 3.8 million barrels and 63 tugboats, operated along the East Coast, West Coast and Gulf Coast of the United States, as well as in Alaska and Hawaii. K-Sea's tank barge fleet, 54 of which were double hulled and had an average age of approximately nine years, is one of the youngest fleets in the coastal trade. K-Sea's customers include major oil companies and refiners, many of which are current Company customers for inland tank barge services. K-Sea has operating facilities in New York, Philadelphia, Seattle and Honolulu.

The Company considers K-Sea to be a natural extension of the current marine transportation segment, expanding into the coastal marine transportation business from the predominately inland based marine transportation business.

Total consideration transferred was as follows (in thousands):

Cash consideration paid	$	227,617
Cash to retire K-Sea's outstanding debt		262,791
Stock consideration through issuance of Company common stock		113,019
Fair value of consideration transferred	$	603,427

The fair values of the assets acquired and liabilities assumed recorded at the acquisition date were as follows (in thousands):

Assets:
Cash	$	4,044
Accounts receivable		40,013
Other current assets		8,881
Property and equipment		495,312
Goodwill		113,973
Deferred income taxes		3,439
Other assets		26,126
Total assets	$	691,788
Liabilities:
Accounts payable	$	27,279
Accrued liabilities		40,675
Deferred revenues		8,224
Other long-term liabilities		8,100
Non-controlling interests		4,083
Total liabilities	$	88,361
Net assets acquired	$	603,427

The analysis of the K-Sea fair values above is substantially complete but all fair values have not been finalized pending obtaining the information necessary to complete the analysis. Companies have one year after an acquisition to finalize acquisition accounting under current accounting rules.

As a result of the acquisition, the Company recorded $113,973,000 of goodwill and $11,400,000 of net intangibles. The net intangibles have a weighted average amortization period of approximately 11 years. The Company expects substantially all of the goodwill will be deductible for tax purposes. Acquisition and integration related costs of $5,353,000, consisting primarily of legal, audit and other professional fees plus other expenses, were expensed as incurred to selling, general and administrative expense in 2011.

On April 15, 2011, the Company purchased United Holdings LLC ("United"), a distributor and service provider of engine and transmission related products for the oil and gas services, power generation and on-highway transportation industries, and manufacturer of oilfield service equipment. The purchase price was $271,192,000 in cash, plus a three-year earnout provision for up to an additional $50,000,000 payable in 2014, dependent on achieving certain financial targets. United, headquartered in Oklahoma City, Oklahoma with 21 locations across seven states, distributes and services equipment and parts for Allison Transmission ("Allison"), MTU Detroit Diesel ("MTU"), Daimler Trucks NA ("Daimler"), and other diesel and natural gas engines. United also manufactures oilfield service equipment, including hydraulic fracturing equipment. United's principal customers are oilfield service companies, oil and gas operators and producers, compression companies and on-highway transportation companies.

The Company considers United to be a natural extension of the current diesel engine services segment, expanding into the land-based diesel engines and transmissions service business, especially the pressure pumping and oilfield services market.

Total consideration transferred was as follows (in thousands):

Cash consideration paid	$	271,192
Fair value of contingent earnout provision payable in 2014		16,300
Fair value of consideration transferred	$	287,492

The fair values of the assets acquired and liabilities assumed recorded at the acquisition date were as follows (in thousands):

Assets:
Accounts receivable	$	71,427
Inventories		64,680
Other current assets		1,246
Property and equipment		16,629
Goodwill		132,302
Other assets		75,864
Total assets	$	362,148
Liabilities:
Accounts payable	$	39,809
Accrued liabilities		7,202
Deferred revenues		27,331
Deferred income taxes		314
Total liabilities	$	74,656
Net assets acquired	$	287,492

The analysis of the United fair values above is substantially complete but all fair values have not been finalized pending obtaining the information necessary to complete the analysis. Companies have one year after an acquisition to finalize acquisition accounting under current accounting rules.

As a result of the acquisition, the Company recorded $132,302,000 of goodwill and $75,697,000 of intangibles. The intangibles have a weighted average amortization period of approximately 16 years. The Company expects substantially all of the goodwill will be deductible for tax purposes. Acquisition related costs of $760,000, consisting primarily of legal and audit fees and other expenses, were expensed as incurred to selling, general and administrative expense in 2011.

On February 24, 2011, the Company purchased 21 inland and offshore tank barges and 15 inland towboats and offshore tugboats from Enterprise Marine Services LLC ("Enterprise") for $53,200,000 in cash. Enterprise provided transportation and delivery services for ship bunkers (engine fuel) to cruise ships, container ships and freighters primarily in the Miami, Port Everglades and Cape Canaveral, Florida area, the three largest cruise ship ports in the United States, as well as Tampa, Florida, Mobile, Alabama and Houston, Texas.

On February 9, 2011, the Company purchased from Kinder Morgan Petcoke, L.P. ("Kinder Morgan") for $4,050,000 in cash a 51% interest in Kinder Morgan's shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel. Kinder Morgan retained the remaining 49% interest and the Company will manage the operation. In addition, the Company purchased a towboat from Kinder Morgan for $1,250,000 in cash.

The following unaudited pro forma results present consolidated information as if the United and K-Sea acquisitions had been completed as of January 1, 2009. The pro forma results do not include the acquisitions of Seaboats, Enterprise and Kinder Morgan described above as the effect of these acquisitions would not be materially different from the Company's actual results.

The pro forma results include the amortization associated with the acquired intangible assets, interest expense associated with the debt used to fund a portion of the acquisitions, the impact of the additional shares issued in connection with the K-Sea acquisition, the impact of certain fair value adjustments such as depreciation adjustments related to adjustments to property and equipment, elimination of K-Sea's goodwill impairment charge in the second quarter of 2010, and standardization of accounting policies. The pro forma results do not include any cost savings or potential synergies related to the acquisitions nor any integration costs. The pro forma results should not be considered indicative of the results of operations or financial position of the combined companies had the acquisitions had been consummated as of January 1, 2009 and are not necessarily indicative of results of future operations of the Company.

The following table sets forth the Company's pro forma revenues, net earnings attributable to Kirby, basic net earnings per share and fully diluted net earnings per share attributable to Kirby common stockholders for the years ended December 31, 2011, 2010 and 2009 (unaudited and in thousands, except per share amounts):

	2011 Pro forma		2010 Pro forma		2009 Pro forma
Revenues	$	2,105,904	$	1,685,173	$	1,554,806
Net earnings attributable to Kirby	$	172,426	$	123,981	$	138,726
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.10	$	2.22	$	2.49
Diluted	$	3.09	$	2.22	$	2.49

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Stock Award Plans (Summary Of Stock Option Activity Under Employee Plan) (Details) (Stock Options [Member], USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Stock Options [Member]
Outstanding Non-Qualified Or Nonincentive Stock Awards
Beginning balance	434,447	640,483	514,181
Granted, Outstanding Non-Qualified or Nonincentive Stock Awards	103,021	103,999	228,246
Exercised, Outstanding Non-Qualified or Nonincentive Stock Awards	(91,794)	(228,543)	(101,944)
Canceled or expired, Outstanding Non-Qualified or Nonincentive Stock Awards		(81,492)
Ending balance	445,674	434,447	640,483
Weighted Average Exercise Price
Beginning balance	$ 33.53	$ 33.39	$ 35.28
Granted, Weighted Average Exercise Price	$ 47.01	$ 32.60	$ 23.98
Exercised, Weighted Average Exercise Price	$ 32.75	$ 28.36	$ 21.86
Canceled or expired, Weighted Average Exercise Price		$ 45.73
Ending balance	$ 36.81	$ 33.53	$ 33.39

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Fair Value Measurements (Narrative) (Details) (USD $)	0 Months Ended	12 Months Ended
	Apr. 15, 2011	Dec. 31, 2011
Fair Value Measurements [Abstract]
Earnout Provision		$ 50,000,000
Fair value contingent earnout liability	16,300,000	22,600,000
Increase in fair value amount charged to selling general and administrative expense		$ 6,300,000

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Taxes On Income (Tables)

12 Months Ended

Dec. 31, 2011

Taxes On Income [Abstract]

Earnings Before Taxes

	2011		2010		2009
Earnings before taxes on income — United States	$	294,747	$	189,640	$	205,558
Provision for taxes on income:
Federal:
Current	$	33,640	$	33,014	$	30,443
Deferred		65,451		30,643		38,404
State and local		10,164		8,601		9,173
	$	109,255	$	72,258	$	78,020

Schedule Of Effective Income Tax Rate Reconciliation

	2011			2010			2009
United States income tax statutory rate		35.0	%		35.0	%		35.0	%
State and local taxes, net of federal benefit		2.2			2.9			2.9
Other – net		(.1	)		.2			.1
		37.1	%		38.1	%		38.0	%

Schedule Of Deferred Tax Assets And Liabilities

	2011			2010
Current deferred tax assets:
Compensated absences	$	695		$	518
Allowance for doubtful accounts		1,752			1,400
Insurance accruals		4,150			2,319
Other		7,589			2,181
	$	14,186		$	6,418
Non-current deferred tax assets and liabilities:
Deferred tax assets:
Postretirement health care benefits	$	3,422		$	3,548
Insurance accruals		1,420			876
Deferred compensation		8,290			7,456
Unrealized loss on derivative financial instruments		3,384			6,162
Unrealized loss on defined benefit plans		28,114			12,582
Operating loss carryforwards		1,305			1,023
Other		9,047			9,177
		54,982			40,824
Deferred tax liabilities:
Property		(298,335	)		(234,732	)
Deferred state taxes		(25,738	)		(22,571	)
Pension benefits		(15,376	)		(8,738	)
Goodwill and other intangibles		(6,563	)		(5,538	)
Other		(1,325	)		(1,020	)
		(347,337	)		(272,599	)
	$	(292,355	)	$	(231,775	)

Reconciliation Of Liability For Unrecognized Tax Benefits

	2011			2010			2009
Balance at beginning of year	$	2,088		$	2,290		$	2,451
Additions based on tax positions related to the current year		602			279			417
Additions for tax positions of prior years		402			84			87
Reductions for tax positions of prior years		(738	)		(443	)		(665	)
Settlements		(822	)		(122	)		—
Balance at end of year	$	1,532		$	2,088		$	2,290

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Long-Term Debt (Tables)

12 Months Ended

Dec. 31, 2011

Long-Term Debt [Abstract]

Schedule Of Long-Term Debt

	2011		2010
Long-term debt, including current portion:
$540,000,000 term loan due May 31, 2016	$	507,000	$	—
$250,000,000 revolving credit facility due November 9, 2015		95,000		—
Senior notes due February 28, 2013		200,000		200,000
Other long-term debt		5		134
	$	802,005	$	200,134

Schedule Of Aggregate Payments Due On The Long-Term Debt

2012	$	39,005
2013		265,000
2014		91,000
2015		199,000
2016		208,000
Thereafter		—
	$	802,005

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Taxes On Income (Reconciliation Of Liability For Unrecognized Tax Benefits) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Taxes On Income [Abstract]
Balance at beginning of year	$ 2,088	$ 2,290	$ 2,451
Additions based on tax positions related to the current year	602	279	417
Additions for tax positions of prior years	402	84	87
Reductions for tax positions of prior years	(738)	(443)	(665)
Settlements	(822)	(122)
Balance at end of year	$ 1,532	$ 2,088	$ 2,290

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Fair Value Measurements (Assets And Liabilities Measured At Fair Value On A Recurring Basis) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivatives, assets
Derivatives, liabilities	9,597	17,576
Contingent earnout liability	22,600
Liabilities fair value	32,197
Quoted Prices In Active Markets For Identical Assets (Level 1)
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivatives, assets
Derivatives, liabilities
Contingent earnout liability
Liabilities fair value
Significant Other Observable Inputs (Level 2)
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivatives, assets
Derivatives, liabilities	9,597	17,576
Liabilities fair value	9,597
Significant Unobservable Inputs (Level 3)
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]
Derivatives, assets
Derivatives, liabilities
Contingent earnout liability	22,600
Liabilities fair value	$ 22,600

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Leases (Tables)

12 Months Ended

Dec. 31, 2011

Leases [Abstract]

Schedule Of Rent Expense

	2011		2010		2009
Rental expense:
Marine equipment — barges	$	16,396	$	9,075	$	9,489
Marine equipment — towing vessels		91,796		79,016		81,453
Other buildings and equipment		8,156		5,334		5,240
Rental expense	$	116,348	$	93,425	$	96,182

Schedule Of Future Minimum Lease Payments Under Operating Leases

	Land, Buildings and Equipment		Marine Equipment
			Barges		Towing Vessels		Total
2012	$	7,164	$	20,151	$	52,888	$	80,203
2013		6,168		18,587		23,020		47,775
2014		5,110		16,722		15,991		37,823
2015		4,857		15,065		9,094		29,016
2016		2,759		11,539		3,034		17,332
Thereafter		6,378		33,446		—		39,824
	$	32,436	$	115,510	$	104,027	$	251,973

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Stock Award Plans (Tables)

12 Months Ended

Dec. 31, 2011

Compensation Cost Breakdown In Statement Of Earnings

	2011		2010		2009
Compensation cost	$	9,228	$	10,867	$	9,855
Income tax benefit	$	3,534	$	4,162	$	3,775

Employee Plan [Member]

Summary Of Stock Option Activity

	Outstanding Non-Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2008		514,181		$	35.28
Granted		228,246		$	23.98
Exercised		(101,944	)	$	21.86
Canceled or expired		—		$	—
Outstanding at December 31, 2009		640,483		$	33.39
Granted		103,999		$	32.60
Exercised		(228,543	)	$	28.36
Canceled or expired		(81,492	)	$	45.73
Outstanding at December 31, 2010		434,447		$	33.53
Granted		103,021		$	47.01
Exercised		(91,794	)	$	32.75
Canceled or expired		—		$	—
Outstanding at December 31, 2011		445,674		$	36.81

Summary Of Outstanding And Exercisable Stock Options

	Options Outstanding								Options Exercisable
Range of Exercise Prices	Number Outstanding		Weighted Average Remaining Contractual Life in Years		Weighted Average Exercise Price		Aggregated Intrinsic Value		Number Exercisable		Weighted Average Exercise Price		Aggregated Intrinsic Value
$23.98 — $32.56		226,450		3.4	$	27.72				113,364	$	26.47
$34.40 — $36.35		24,000		2.4	$	34.73				21,333	$	34.52
$46.74 — $58.28		195,224		3.7	$	47.61				92,203	$	48.28
$23.98 — $58.28		445,674		3.5	$	36.81	$	12,937,000		226,900	$	36.09	$	6,750,000

Summary Of Restricted Stock Award Activity

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2008		502,818		$	33.64
Granted		263,579		$	24.70
Vested		(207,106	)	$	36.60
Forfeited		(16,612	)	$	32.70
Nonvested balance at December 31, 2009		542,679		$	30.70
Granted		197,994		$	33.42
Vested		(234,831	)	$	39.34
Forfeited		(6,507	)	$	32.00
Nonvested balance at December 31, 2010		499,335		$	31.98
Granted		150,612		$	46.50
Vested		(163,480	)	$	33.27
Forfeited		(10,835	)	$	38.90
Nonvested balance at December 31, 2011		475,632		$	36.43

Director Plan [Member]

Summary Of Stock Option Activity

	Outstanding Non-Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2008		309,572		$	30.94
Granted		50,433		$	29.60
Exercised		(46,068	)	$	11.85
Forfeited		(12,000	)	$	35.99
Outstanding at December 31, 2009		301,937		$	33.43
Granted		57,492		$	41.24
Exercised		(3,000	)	$	10.67
Outstanding at December 31, 2010		356,429		$	34.88
Granted		60,552		$	56.42
Exercised		(63,356	)	$	32.17
Outstanding at December 31, 2011		353,625		$	39.05

Summary Of Outstanding And Exercisable Stock Options

	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
$12.69 — $17.88		45,814		1.4	$	15.78				45,814	$	15.78
$20.28 — $29.60		56,433		6.1	$	26.63				56,433	$	26.63
$35.17 — $36.82		86,036		4.7	$	35.88				86,036	$	35.88
$41.24 — $56.45		165,342		8.1	$	51.39				164,704	$	51.37
$12.69 — $56.45		353,625		6.1	$	39.05	$	9,473,000		352,987	$	39.02	$	9,467,000

Summary Of Restricted Stock Award Activity

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2008		390		$	56.00
Granted		10,919		$	29.77
Vested		(10,577	)	$	30.74
Nonvested balance at December 31, 2009		732		$	29.77
Granted		11,097		$	41.33
Vested		(11,304	)	$	40.58
Nonvested balance at December 31, 2010		525		$	41.33
Granted		11,990		$	56.85
Vested		(10,767	)	$	55.90
Nonvested balance at December 31, 2011		1,748		$	58.07

Summary Of Stock Option Activity Under Director Plans

	2011			2010			2009
Dividend yield		None			None			None
Average risk-free interest rate		2.4	%		3.1	%		1.9	%
Stock price volatility		33	%		33	%		33	%
Estimated option term		Six years or sevenyears			Six years or sevenyears			Four years or eightyears

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Summary Of Significant Accounting Policies

12 Months Ended

Dec. 31, 2011

Summary Of Significant Accounting Policies [Abstract]

Summary Of Significant Accounting Policies

(1) Summary of Significant Accounting Policies

Principles of Consolidation. The consolidated financial statements include the accounts of Kirby Corporation and all majority-owned subsidiaries ("the Company"). Two affiliated limited partnerships, in which the Company owns a 50% interest, is the general partner and has effective control and whose activities are an integral part of the operations of the Company, are consolidated. All other investments in which the Company owns 20% to 50% and exercises significant influence over operating and financial policies are accounted for using the equity method. All material intercompany accounts and transactions have been eliminated in consolidation. Certain reclassifications have been made to reflect the current presentation of financial information.

Accounting Policies

Cash Equivalents. Cash equivalents consist of all short-term, highly liquid investments with maturities of three months or less at date of purchase.

Accounts Receivable. In the normal course of business, the Company extends credit to its customers. The Company regularly reviews the accounts and makes adequate provisions for probable uncollectible balances. It is the Company's opinion that the accounts have no impairment, other than that for which provisions have been made. Included in accounts receivable as of December 31, 2011 and 2010 were $53,083,000 and $24,626,000, respectively, of accruals for revenues earned which have not been invoiced as of the end of each year.

The Company's marine transportation and diesel engine services operations are subject to hazards associated with such businesses. The Company maintains insurance coverage against these hazards with insurance companies. Included in accounts receivable as of December 31, 2011 and 2010 were $15,530,000 and $3,453,000, respectively, of receivables from insurance companies to cover claims in excess of the Company's deductible.

Concentrations of Credit Risk. Financial instruments which potentially subject the Company to concentrations of credit risk are primarily trade accounts receivables. The Company's marine transportation customers include the major oil refining and petrochemical companies. The diesel engine services customers are oil and gas service companies, marine transportation companies, commercial fishing companies, power generation companies, and the United States government. The Company regularly reviews its accounts and estimates the amount of uncollectible receivables each period and establishes an allowance for uncollectible amounts. The amount of the allowance is based on the age of unpaid amounts, information about the current financial strength of customers, and other relevant information. Estimates of uncollectible amounts are revised each period, and changes are recorded in the period they become known.

Fair Value of Financial Instruments. Cash, accounts receivable, accounts payable and accrued liabilities have carrying values that approximate fair value due to the short-term maturity of these financial instruments. The fair value of the Company's debt instruments is more fully described in Note 6, Long-Term Debt.

Property, Maintenance and Repairs. Property is recorded at cost. Improvements and betterments are capitalized as incurred. Depreciation is recorded on the straight-line method over the estimated useful lives of the individual assets as follows: marine transportation equipment, 5-40 years; buildings, 10-40 years; other equipment, 2-10 years; and leasehold improvements, term of lease. When property items are retired, sold or otherwise disposed of, the related cost and accumulated depreciation are removed from the accounts with any gain or loss on the disposition included in the statement of earnings. Maintenance and repairs on vessels built for use on the inland waterways are charged to operating expense as incurred and includes the costs incurred in United States Coast Guard ("USCG") inspections unless the shipyard extends the life or improves the operating capacity of the vessel which results in the costs being capitalized.

Drydocking on Ocean-Going Vessels. The Company's ocean-going vessels are subject to regulatory drydocking requirements after certain periods of time to be inspected, have planned major maintenance performed and be recertified by the American Bureau of Shipping ("ABS"). These recertifications generally occur twice in a five year period. The Company defers the drydocking expenditures incurred on its ocean-going vessels due to regulatory marine inspections by the ABS and amortizes the costs of the shipyard over the period between drydockings, generally 30 months, unless the drydocking extends the life or improves the operating capability of the vessels which results in the costs being capitalized. Routine repairs and maintenance on ocean-going vessels are expensed as incurred.

Environmental Liabilities. The Company expenses costs related to environmental events as they are incurred or when a loss is considered probable and estimable.

Goodwill. The excess of the purchase price over the fair value of identifiable net assets acquired in transactions accounted for as a purchase is included in goodwill. The Company conducted its annual goodwill impairment test at November 30, 2011 and 2010. For 2011 and 2010, the Company noted no impairment of goodwill. The Company will continue to conduct goodwill impairment tests as of November 30 of subsequent years, or whenever events or circumstances indicate that interim impairment testing is necessary. The gross carrying value of goodwill at December 31, 2011 and 2010 was $500,935,000 and $246,340,000, respectively, and accumulated amortization at December 31, 2011 and 2010 was $15,566,000. Accumulated impairment losses were $1,901,000 at December 31, 2011 and 2010.

Net goodwill for the marine transportation segment was $276,163,000 and $153,870,000 at December 31, 2011 and 2010, respectively. Net goodwill for the diesel engine services segment was $207,305,000 and $75,003,000 at December 31, 2011 and 2010, respectively.

Revenue Recognition. The majority of marine transportation revenue is derived from term contracts, ranging from one to five years, some of which have renewal options, and the remainder is from spot market movements. The majority of the term contracts are for terms of one year. The Company is a provider of marine transportation services for its customers and, in almost all cases, does not assume ownership of the products it transports. A term contract is an agreement with a specific customer to transport cargo from a designated origin to a designated destination at a set rate or at a daily rate. The rate may or may not escalate during the term of the contract, however, the base rate generally remains constant and contracts often include escalation provisions to recover changes in specific costs such as fuel. A spot contract is an agreement with a customer to move cargo from a specific origin to a designated destination for a rate negotiated at the time the cargo movement takes place. Spot contract rates are at the current "market" rate, including fuel, and are subject to market volatility. The Company uses a voyage accounting method of revenue recognition for its marine transportation revenues which allocates voyage revenue based on the percent of the voyage completed during the period. There is no difference in the recognition of revenue between a term contract and a spot contract.

Diesel engine service products and services are generally sold based upon purchase orders or preferential service agreements with the customer that include fixed or determinable prices and that do not include right of return or significant post delivery performance obligations. Diesel engine parts sales are recognized when title passes upon shipment to customers or when customer-specific acceptance requirements are met. Service revenue is recognized as the service is provided. Diesel manufacturing and assembly projects revenue is reported on the percentage of completion method of accounting using measurements of progress towards completion appropriate for the work performed.

Stock-Based Compensation. The Company has share-based compensation plans covering selected officers and other key employees as well as the Company's Board of Directors. Stock-based grants made under the Company's stock plans are recorded at fair value on the date of the grant and the cost is recognized ratably over the vesting period of the stock option or restricted stock. Stock option grants are valued at the date of grant as calculated under the Black-Scholes option pricing model. The Company's stock-based compensation plans are more fully described in Note 9, Stock Award Plans.

Taxes on Income. The Company follows the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

Accrued Insurance. Accrued insurance liabilities include estimates based on individual incurred claims outstanding and an estimated amount for losses incurred but not reported ("IBNR") or fully developed based on past experience. Insurance premiums, IBNR losses and incurred claim losses, up to the Company's deductible, for 2011, 2010 and 2009 were $18,673,000, $13,461,000 and $12,786,000, respectively.

Noncontrolling Interests. The Company has a majority interest in and is the general partner in several affiliated entities. In situations where losses applicable to the minority interest in the affiliated entities exceed the limited partners' equity capital, such excess and any further loss attributable to the minority interest is charged against the Company's interest in the affiliated entities. If future earnings materialize in the respective affiliated entities, the Company's interest would be credited to the extent of any losses previously absorbed.

Treasury Stock. The Company follows the average cost method of accounting for treasury stock transactions.

Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of. The Company reviews long-lived assets and certain identifiable intangibles for impairment by vessel class whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable.

Recoverability on marine transportation assets is assessed based on vessel classes, not on individual assets, because identifiable cash flows for individual marine transportation assets are not available. Projecting customer contract volumes allows estimation of future cash flows by projecting pricing and utilization by vessel class but it is not practical to project which individual marine transportation asset will be utilized for any given contract. Because customers do not specify which particular vessel is used, prices are quoted based on vessel classes not individual assets. Nominations of vessels for specific jobs are determined on a day by day basis and are a function of the equipment class required and the geographic position of vessels within that class at that particular time as vessels within a class are interchangeable and provide the same service. The Company's vessels are mobile assets and equipped to operate in geographic regions throughout the United States and the Company has in the past and expects to continue to move vessels from one region to another when it is necessary due to changing markets and it is economical to do so. Barge vessel classes are based on similar capacities, hull type, and type of product and towing vessels are based on similar hull type and horsepower. Recoverability of the vessel classes is measured by a comparison of the carrying amount of the assets to future net cash flows expected to be generated by the assets. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs to sell.

Accounting Standards

In September 2011, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2011-08, "Testing Goodwill for Impairment." ASU 2011-08 amends the guidance in ASC 350-20, "Intangibles – Goodwill and Other – Goodwill." Under ASU 2011-08, entities have the option of performing a qualitative assessment before calculating the fair value of the reporting unit when testing goodwill for impairment. If the fair value of the reporting unit is determined, based on qualitative factors, to be more likely than not less than the carrying amount of the reporting unit, then entities are required to perform the two-step goodwill impairment test. This ASU is effective for goodwill impairment tests performed in interim and annual periods for fiscal years beginning after December 15, 2011, with early adoption permitted. The Company adopted the provisions of this ASU for its 2011 goodwill impairment testing with no impact on its consolidated financial statements.

In June 2011, the FASB issued ASU 2011-05, "Comprehensive Income (Topic 220): Presentation of Comprehensive Income." ASU 2011-05 requires entities to present components of comprehensive income in either a single continuous statement of comprehensive income or two separate but consecutive statements that would include reclassification adjustments for items that are reclassified from other comprehensive income ("OCI") to net income on the face of the financial statements. This ASU is effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. The adoption of ASU 2011-05 will not have a material impact on the Company's consolidated financial statements.

In December 2011, the FASB issued ASU 2011-12, "Comprehensive Income (Topic 220): Deferral of the Effective Date for Amendments to the Presentation of Reclassifications of Items Out of Accumulated Other Comprehensive Income in Accounting Standards Update No. 2011-05" ("ASU 2011-12"). The amendments to the Codification in ASU 2011-12 are effective at the same time as the amendments in ASU 2011-05, so that entities will not be required to comply with the presentation requirements in ASU 2011-05 that ASU 2011-12 is deferring. The amendments are being made to allow the FASB time to reevaluate whether to present on the face of the financial statements the effects of reclassifications out of accumulated OCI on the components of net income and OCI for all periods presented. ASU 2011-12 will be effective for fiscal years, and interim periods within those years, beginning after December 15, 2011. The adoption of ASU 2011-12 will not have a material impact on the Company's consolidated financial statements.

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Retirement Plans (Tables)

12 Months Ended

Dec. 31, 2011

Defined Benefit Plan Disclosure [Line Items]

Summary Of Asset Allocation

Asset Category	2011			2010			Current Minimum, Target and Maximum Allocation Policy
U.S. equity securities		43	%		50	%	30% — 50% — 70%
International equity securities		16	%		20	%	0% — 20% — 30%
Debt securities		25	%		29	%	15% — 30% — 55%
Cash and cash equivalents		16	%		1	%	0% — 0% — 5%
		100	%		100	%

Schedule Of Change In Benefit Obligation

													Other Postretirement Benefits
	Pension Benefits												Postretirement Welfare Plan
	Pension Plan						SERP
	2011			2010			2011			2010			2011			2010
Change in benefit obligation
Benefit obligation at beginning of year	$	170,742		$	141,338		$	1,511		$	1,429		$	2,790		$	5,459
Service cost		7,303			6,883			—			—			—			—
Interest cost		9,693			9,399			80			84			164			154
Actuarial loss (gain)		33,662			17,124			157			101			182			(3,108	)
Plan amendments		—			—			—			—			—			519
Gross benefits paid		(4,474	)		(4,002	)		(103	)		(103	)		(122	)		(234	)
Benefit obligation at end of year	$	216,926		$	170,742		$	1,645		$	1,511		$	3,014		$	2,790
Accumulated benefit obligation at end of year	$	179,190		$	141,666		$	1,645		$	1,511		$	—		$	—

Weighted-Average Assumption Used To Determine Benefit Obligation And Net Periodic Benefit Cost

Weighted-average assumption used to determine benefit obligation at end of year
Discount rate	4.6	%	5.5	%	4.6	%	5.5	%	4.6	%	5.5	%
Rate of compensation increase	4.25	%	4.25	%	—		—		—		—
Health care cost trend rate
Initial rate	—		—		—		—		7.5	%	8.0	%
Ultimate rate	—		—		—		—		5.0	%	5.0	%
Years to ultimate	—		—		—		—		2017		2017

Effect Of One-Percentage-Point Change In Assumed Health Care Cost Trend Rate

Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation
Increase	$	—	$	—	$	—	$	—	$	285		$	223
Decrease		—		—		—		—		(250	)		(196	)

Summary Of Change In Plan Assets

Change in plan assets
Fair value of plan assets at beginning of year	$	152,696		$	126,490		$	—		$	—		$	—		$	—
Actual return on plan assets		(1,499	)		18,308			—			—			—			—
Employer contribution		27,500			11,900			103			103			122			234
Gross benefits paid		(4,474	)		(4,002	)		(103	)		(103	)		(122	)		(234	)
Fair value of plan assets at end of year	$	174,223		$	152,696		$	—		$	—		$	—		$	—

Summary Of Funded Status At End Of Year

													Other Postretirement Benefits
	Pension Benefits												Postretirement
	Pension Plan						SERP						Welfare Plan
	2011			2010			2011			2010			2011			2010
Funded status at end of year
Fair value of plan assets	$	174,223		$	152,696		$	—		$	—		$	—		$	—
Benefit obligations		216,926			170,742			1,645			1,511			3,014			2,790
Funded status and amount recognized at end of year	$	(42,703	)	$	(18,046	)	$	(1,645	)	$	(1,511	)	$	(3,014	)	$	(2,790	)

Amounts Recognized In The Consolidated Balance Sheets

Amounts recognized in the consolidated balance sheets
Current liability	$	—		$	—		$	(102	)	$	(102	)	$	(256	)	$	(246	)
Long-term liability		(42,703	)		(18,046	)		(1,543	)		(1,409	)		(2,758	)		(2,544	)

Amounts Recognized In Accumulated Other Comprehensive Income

Amounts recognized in accumulated other comprehensive income
Net actuarial loss (gain)	$	86,633	$	43,048		$	442	$	293	$	(6,751	)	$	(7,523	)
Prior service cost (credit)		—		(38	)		—		—		—			158
Accumulated other compensation income	$	86,633	$	43,010		$	442	$	293	$	(6,751	)	$	(7,365	)

Projected Benefit Obligation In Excess Of Plan Assets

	Pension Benefits
	Pension Plan				SERP
	2011		2010		2011		2010
Projected benefit obligation in excess of plan assets
Projected benefit obligation at end of year	$	216,926	$	170,742	$	1,645	$	1,511
Fair value of plan assets at end of year		174,223		152,696		—		—

Accumulated Benefit Obligation In Excess Of Plan Assets

	Pension Benefits
	Pension Plan				SERP
	2011		2010		2011		2010
Accumulated benefit obligation in excess of plan assets
Projected benefit obligation at end of year	$	216,926	$	—	$	1,645	$	1,511
Accumulated benefit obligation at end of year		179,190		—		1,645		1,511
Fair value of plan assets at end of year		174,223		—		—		—

Schedule Of Employer Contribution

									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011		2010
Expected employer contributions
First year	$	11,800	$	—	$	102	$	102	$	256	$	246

Expected Benefit Payments

									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011		2010
Expected benefit payments (gross)
Year one	$	5,142	$	4,639	$	102	$	102	$	271	$	262
Year two		5,590		5,058		100		100		264		261
Year three		6,113		5,480		98		99		268		253
Year four		6,649		5,997		97		97		271		257
Year five		7,252		6,524		105		95		271		258
Next five years		47,701		42,703		597		558		1,343		1,274

Summary Of Expected Federal Subsidy

									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011			2010
Expected federal subsidy
Year one	$	—	$	—	$	—	$	—	$	(15	)	$	(16	)
Year two		—		—		—		—		(15	)		(16	)
Year three		—		—		—		—		(15	)		(16	)
Year four		—		—		—		—		(15	)		(16	)
Year five		—		—		—		—		(15	)		(16	)
Next five years		—		—		—		—		(67	)		(74	)

Components Of Net Periodic Benefit Cost

	Pension Benefits
	Pension Plan									SERP
	2011			2010			2009			2011			2010			2009
Components of net periodic benefit cost
Service cost	$	7,303		$	6,883		$	6,523		$	—		$	—		$	—
Interest cost		9,693			9,399			8,486			80			84			84
Expected return on plan assets		(11,283	)		(9,329	)		(7,333	)		—			—			—
Amortization:
Actuarial loss		2,859			3,162			5,666			7			2			2
Prior service credit		(38	)		(89	)		(88	)		—			—			—
Net periodic benefit cost		8,534			10,026			13,254			87			86			86
Other changes in plan assets and benefit obligations recognized in other comprehensive income
Current year actuarial loss (gain)		46,444			8,145			(28,443	)		156			102			14
Recognition of actuarial loss		(2,859	)		(3,162	)		(5,666	)		(7	)		(2	)		(2	)
Recognition of prior service credit		38			89			88			—			—			—
Total recognized in other comprehensive income		43,623			5,072			(34,021	)		149			100			12
Total recognized in net periodic benefit cost and other comprehensive income	$	52,157		$	15,098		$	(20,767	)	$	236		$	186		$	98

Pension Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Weighted-Average Assumption Used To Determine Benefit Obligation And Net Periodic Benefit Cost

Weighted average assumptions used to determine net periodic benefit cost
Discount rate	5.5	%	6.1	%	6.1	%	5.5	%	6.1	%	6.1	%
Expected long-term rate of return on plan assets	7.5	%	7.5	%	7.5	%	—		—		—
Rate of compensation increase	4.25	%	4.0	%	4.0	%	—		—		—

Estimated Amounts That Will Be Amortized From Accumulated Other Comprehensive Income Into Net Periodic Benefit Cost

	Pension Benefits
	Pension Plan		SERP
Actuarial loss	$	7,007	$	14
Prior service credit		—		—
	$	7,007	$	14

Other Postretirement Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Weighted-Average Assumption Used To Determine Benefit Obligation And Net Periodic Benefit Cost

Weighted average assumptions used to determine net periodic benefit cost
Discount rate	5.5	%	6.1	%	6.1	%
Health care cost trend rate:
Initial rate	8.0	%	7.5	%	8.0	%
Ultimate rate	5.0	%	5.0	%	5.0	%
Years to ultimate	2017		2015		2015

Effect Of One-Percentage-Point Change In Assumed Health Care Cost Trend Rate

Effect of one-percentage-point change in assumed health care cost trend rate on aggregate service and interest cost
Increase	$	16		$	14		$	12
Decrease		(14	)		(12	)		(11	)

Components Of Net Periodic Benefit Cost

	Other Postretirement Benefits
	Postretirement Welfare Plan
	2011			2010			2009
Components of net periodic benefit cost
Service cost	$	—		$	—		$	246
Interest cost		164			154			322
Curtailment loss		119			—			—
Amortization:
Actuarial gain		(593	)		(660	)		(325	)
Prior service cost		40			560			40
Net periodic benefit cost		(270	)		54			283
Other changes in benefit obligations recognized in other comprehensive income
Current year actuarial gain		182			(3,109	)		(141	)
Recognition of actuarial gain		593			660			325
Recognition of prior service cost		(158	)		(40	)		(40	)
Adjustment for actual Medicare Part D reimbursement		(3	)		(10	)		—
Total recognized in other comprehensive income		614			(2,499	)		144
Total recognized in net periodic benefit cost and other comprehensive income	$	344		$	(2,445	)	$	427

Estimated Amounts That Will Be Amortized From Accumulated Other Comprehensive Income Into Net Periodic Benefit Cost

	Other Postretirement Benefits
	Postretirement Welfare Plan
Actuarial gain	$	(616	)
Prior service cost		—
	$	(616	)

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Retirement Plans (Components Of Net Periodic Benefit Cost) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 7,303	$ 6,883	$ 6,523
Interest cost	9,693	9,399	8,486
Expected return on plan assets	(11,283)	(9,329)	(7,333)
Actuarial loss (gain)	2,859	3,162	5,666
Prior service (credit) cost	(38)	(89)	(88)
Net periodic benefit cost	8,534	10,026	13,254
Current year actuarial loss (gain)	46,444	8,145	(28,443)
Recognition of actuarial loss (gain)	(2,859)	(3,162)	(5,666)
Recognition of prior service credit (cost)	38	89	88
Total recognized in other comprehensive income	43,623	5,072	(34,021)
Total recognized in net periodic benefit cost and other comprehensive income	52,157	15,098	(20,767)
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Interest cost	80	84	84
Actuarial loss (gain)	7	2	2
Net periodic benefit cost	87	86	86
Current year actuarial loss (gain)	156	102	14
Recognition of actuarial loss (gain)	(7)	(2)	(2)
Total recognized in other comprehensive income	149	100	12
Total recognized in net periodic benefit cost and other comprehensive income	236	186	98
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost			246
Interest cost	164	154	322
Curtailment loss	119
Actuarial loss (gain)	(593)	(660)	(325)
Prior service (credit) cost	40	560	40
Net periodic benefit cost	(270)	54	283
Current year actuarial loss (gain)	182	(3,109)	(141)
Recognition of actuarial loss (gain)	593	660	325
Recognition of prior service credit (cost)	(158)	(40)	(40)
Adjustment for actual Medicare Part D reimbursement	(3)	(10)
Total recognized in other comprehensive income	614	(2,499)	144
Total recognized in net periodic benefit cost and other comprehensive income	$ 344	$ (2,445)	$ 427

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Acquisitions (Fair Values Of Assets Acquired And Liabilities Assumed) (Details) (USD $)	Jul. 31, 2011	Apr. 30, 2011	Jul. 31, 2011 K-Sea Transportation Partners L.P. [Member]	Apr. 15, 2011 United Holdings LLC [Member]
Business Acquisition [Line Items]
Cash			$ 4,044,000
Accounts receivable			40,013,000	71,427,000
Inventories				64,680,000
Other current assets			8,881,000	1,246,000
Property and equipment			495,312,000	16,629,000
Goodwill	113,973,000	132,302,000	113,973,000	132,302,000
Deferred income taxes			3,439,000
Other assets			26,126,000	75,864,000
Total assets			691,788,000	362,148,000
Accounts payable			27,279,000	39,809,000
Accrued liabilities			40,675,000	7,202,000
Deferred revenues			8,224,000	27,331,000
Other long-term liabilities			8,100,000
Deferred income taxes				314,000
Non-controlling interests			4,083,000
Total liabilities			88,361,000	74,656,000
Net assets acquired			$ 603,427,000	$ 287,492,000

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Taxes On Income (Earnings Before Taxes) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Taxes On Income [Abstract]
Earnings before taxes on income - United States	$ 87,279	$ 86,328	$ 68,279	$ 52,861	$ 51,202	$ 50,116	$ 47,965	$ 40,357	$ 294,747	$ 189,640	$ 205,558
Current									33,640	33,014	30,443
Deferred									65,451	30,643	38,404
State and local									10,164	8,601	9,173
Total provision for taxes on income	$ 30,510	$ 32,734	$ 26,050	$ 19,961	$ 19,279	$ 19,211	$ 18,322	$ 15,446	$ 109,255	$ 72,258	$ 78,020

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Retirement Plans (Weighted-Average Assumption Used To Determine Benefit Obligation) (Details)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.60%	5.50%
Rate of compensation increase	4.25%	4.25%
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.60%	5.50%
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.60%	5.50%
Health care cost trend rate, Initial rate	7.50%	8.00%
Health care cost trend rate, Ultimate rate	5.00%	5.00%
Health care cost trend rate, Years to ultimate	2017	2017

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
ASSETS
Cash and cash equivalents	$ 16,249	$ 195,600
Accounts receivable:
Trade - less allowance for doubtful accounts of $5,007 ($4,000 in 2010)	303,087	146,359
Other	32,060	21,612
Inventories - net, at lower of average cost or market	130,130	38,821
Prepaid expenses and other current assets	33,617	17,105
Deferred income taxes	14,186	6,418
Total current assets	529,329	425,915
Property and equipment:
Marine transportation equipment	2,466,506	1,748,488
Land, buildings and equipment	151,762	113,823
Property and equipment	2,618,268	1,862,311
Accumulated depreciation	796,095	744,150
Property and equipment - net	1,822,173	1,118,161
Investment in affiliates	3,682	3,336
Goodwill - net	483,468	228,873
Other assets	121,759	18,652
Total assets	2,960,411	1,794,937
LIABILITIES AND STOCKHOLDERS' EQUITY
Current portion of long-term debt	39,005	128
Income taxes payable	4,124	3,065
Accounts payable	158,855	71,354
Accrued liabilities:
Interest	1,168	1,006
Insurance premiums and claims	45,817	24,416
Employee compensation	42,706	30,582
Taxes - other than on income	9,972	7,550
Other	17,599	10,525
Deferred revenues	39,554	11,633
Total current liabilities	358,800	160,259
Long-term debt - less current portion	763,000	200,006
Deferred income taxes	292,355	231,775
Other long-term liabilities	92,098	43,758
Total long-term liabilities	1,147,453	475,539
Contingencies and commitments
Kirby stockholders' equity:
Common stock, $.10 par value per share. Authorized 120,000,000 shares, issued 59,276,000 shares	5,928	5,734
Additional paid-in capital	357,294	237,014
Accumulated other comprehensive income - net	(56,176)	(33,642)
Retained earnings	1,229,641	1,046,615
Treasury stock - at cost, 3,532,000 shares in 2011 and 3,780,000 in 2010	(94,162)	(99,622)
Total Kirby stockholders' equity	1,442,525	1,156,099
Noncontrolling interests	11,633	3,040
Total equity	1,454,158	1,159,139
Total liabilities and equity	$ 2,960,411	$ 1,794,937

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Derivative Instruments (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2011
Derivative [Line Items]
Interest rate cash flow hedge derivative at fair value, net	$ 200,000,000
Foreign currency contracts loss	211,000
Forward Contracts [Member]
Derivative [Line Items]
Derivative, notional amount	5,406,000
Interest Rate Contracts [Member]
Derivative [Line Items]
Derivative instruments loss expected to reclassify from accumulated OCI into income effective portion	$ 4,781,000

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Consolidated Statements Of Stockholders' Equity And Comprehensive Income (Parenthetical) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Consolidated Statements Of Stockholders' Equity And Comprehensive Income [Abstract]
Change in defined benefit plans' minimum liabilities, taxes	$ 16,994	$ 1,028	$ (12,962)
Change in fair value of derivative financial instruments, taxes	(2,915)	986	(1,974)
Purchase of treasury stock, shares		618,000	20,000
Cost of treasury stock issued upon exercise of stock options and issuance of restricted stock	248,000	338,000	368,000
Other comprehensive income (loss), taxes	$ 14,079	$ 2,013	$ (14,936)

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Leases (Schedule Of Future Minimum Lease Payments Under Operating Leases) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011
Operating Leased Assets [Line Items]
2012	$ 80,203
2013	47,775
2014	37,823
2015	29,016
2016	17,332
Thereafter	39,824
Future minimum lease payments under operating leases	251,973
Marine Equipment [Member] | Tank Barges [Member]
Operating Leased Assets [Line Items]
2012	20,151
2013	18,587
2014	16,722
2015	15,065
2016	11,539
Thereafter	33,446
Future minimum lease payments under operating leases	115,510
Marine Equipment [Member] | Towing Vessels [Member]
Operating Leased Assets [Line Items]
2012	52,888
2013	23,020
2014	15,991
2015	9,094
2016	3,034
Future minimum lease payments under operating leases	104,027
Land Buildings And Equipment [Member]
Operating Leased Assets [Line Items]
2012	7,164
2013	6,168
2014	5,110
2015	4,857
2016	2,759
Thereafter	6,378
Future minimum lease payments under operating leases	$ 32,436

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Segment Data (Tables)

12 Months Ended

Dec. 31, 2011

Segment Data [Abstract]

Revenues, Profit Or Loss, Total Assets, Depreciation And Amortization And Capital Expenditures By Reportable Segment

	2011			2010			2009
Revenues:
Marine transportation	$	1,194,607		$	915,046		$	881,298
Diesel engine services		655,810			194,511			200,860
	$	1,850,417		$	1,109,557		$	1,082,158
Segment profit (loss):
Marine transportation	$	262,193		$	192,758		$	208,086
Diesel engine services		68,105			20,553			21,005
Other		(35,551	)		(23,671	)		(23,533	)
	$	294,747		$	189,640		$	205,558
Total assets:
Marine transportation	$	2,307,821		$	1,383,252		$	1,336,358
Diesel engine services		608,886			185,824			185,573
Other		43,704			225,861			114,032
	$	2,960,411		$	1,794,937		$	1,635,963
Depreciation and amortization:
Marine transportation	$	111,292		$	88,710		$	87,589
Diesel engine services		11,801			4,055			4,247
Other		2,936			2,531			2,132
	$	126,029		$	95,296		$	93,968
Capital expenditures:
Marine transportation	$	218,777		$	132,744		$	188,479
Diesel engine services		5,576			920			1,768
Other		1,885			3,177			2,413
	$	226,238		$	136,841		$	192,660

Other Segment Loss

	2011			2010			2009
General corporate expenses	$	(17,915	)	$	(13,189	)	$	(12,239	)
Impairment of goodwill		—			—			(1,901	)
Interest expense		(17,902	)		(10,960	)		(11,080	)
Gain (loss) on disposition of assets		(40	)		(78	)		1,079
Other income		306			556			608
	$	(35,551	)	$	(23,671	)	$	(23,533	)

Other Total Assets

	2011		2010		2009
General corporate assets	$	40,022	$	222,525	$	110,980
Investment in affiliates		3,682		3,336		3,052
	$	43,704	$	225,861	$	114,032

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Stock Award Plans (Summary Of Stock Option Activity Under Director Plans) (Details) (Director Plans [Member], USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Director Plans [Member]
Outstanding Non-Qualified Or Nonincentive Stock Awards
Beginning balance	356,429	301,937	309,572
Granted, Outstanding Non-Qualified or Nonincentive Stock Awards	60,552	57,492	50,433
Exercised, Outstanding Non-Qualified or Nonincentive Stock Awards	(63,356)	(3,000)	(46,068)
Forfeited, Outstanding Non-Qualified or Nonincentive Stock Awards			(12,000)
Ending balance	353,625	356,429	301,937
Weighted Average Exercise Price
Beginning balance	$ 34.88	$ 33.43	$ 30.94
Granted, Weighted Average Exercise Price	$ 56.42	$ 41.24	$ 29.60
Exercised, Weighted Average Exercise Price	$ 32.17	$ 10.67	$ 11.85
Forfeited, Weighted Average Exercise Price			$ 35.99
Ending balance	$ 39.05	$ 34.88	$ 33.43

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Related Party Transactions

12 Months Ended

Dec. 31, 2011

Related Party Transactions [Abstract]

Related Party Transactions

(15) Related Party Transactions

During 2011, the Company and its subsidiaries paid 55 Waugh, LP, a partnership 60% owned by C. Berdon Lawrence, the former Chairman of the Board and current director of the Company, and his family, $1,491,000 for the rental of office space in a building owned by 55 Waugh, LP. The Company's headquarters are located in the building under a lease that was signed in 2005, prior to the purchase of the building by 55 Waugh, LP, and expires at the end of 2015.

The Company is a 50% owner of The Hollywood Camp, L.L.C. ("The Hollywood Camp"), a company that owns and operates a hunting and fishing facility used by the Company and L3 Partners, LLC ("L3P"), a company owned by Mr. Lawrence, which is also a 50% owner. The Company uses The Hollywood Camp primarily for customer entertainment. L3P acts as manager of The Hollywood Camp. The Hollywood Camp allocates lease and lodging expenses to its members based on their usage of the facilities. During 2011, the Company paid $2,121,000 to The Hollywood Camp for its share of facility expenses.

Richard J. Alario, a current director of the Company, is the Chairman of the Board, President and Chief Executive Officer of Key Energy Services, Inc. ("Key Energy"). In 2011, Key Energy paid the Company $7,978,000 for oilfield service equipment and for parts and service. Such sales and service were in the ordinary course of business of the Company.

The husband of Amy D. Husted, Vice President — Legal of the Company, is a partner in the law firm of Strasburger & Price, LLP. In 2011, the Company paid the law firm $483,000 for legal services in connection with matters in the ordinary course of business of the Company.

The brother-in-law of Ronald A. Dragg, Vice President and Controller of the Company, is a 50% owner of MB Western Industrial Contracting Company ("MB Western"). In 2011, the Company paid MB Western $1,160,000 for shoreside facilities construction services. Such services were completed in the ordinary course of business of the Company.

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Summary Of Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Significant Accounting Policies [Line Items]
Limited partnership ownership	50.00%
Accruals for revenues earned included in accounts receivable	$ 53,083,000	$ 24,626,000
Receivables from insurance companies to cover claims in excess included in accounts receivable	15,530,000	3,453,000
Gross carrying value of goodwill	500,935,000	246,340,000
Accumulated amortization	15,566,000	15,566,000
Accumulated impairment losses	1,901,000	1,901,000
Net goodwill	483,468,000	228,873,000
Accrued insurance liabilities	18,673,000	13,461,000	12,786,000
Maximum [Member]
Significant Accounting Policies [Line Items]
Other investments ownership percentage	50.00%
Minimum [Member]
Significant Accounting Policies [Line Items]
Other investments ownership percentage	20.00%
Buildings [Member]
Significant Accounting Policies [Line Items]
Estimated useful lives of the individual assets, minimum (years)	10
Estimated useful lives of the individual assets, maximum (years)	40
Other Equipment [Member]
Significant Accounting Policies [Line Items]
Estimated useful lives of the individual assets, minimum (years)	2
Estimated useful lives of the individual assets, maximum (years)	10
Marine Transportation Equipment [Member] | Maximum [Member]
Significant Accounting Policies [Line Items]
Estimated useful lives of the individual assets, maximum (years)	40
Marine Transportation Equipment [Member] | Minimum [Member]
Significant Accounting Policies [Line Items]
Estimated useful lives of the individual assets, minimum (years)	5
Marine Transportation Segment [Member]
Significant Accounting Policies [Line Items]
Net goodwill	276,163,000	153,870,000
Range of term contracts, years	one
Marine Transportation Segment [Member] | Maximum [Member]
Significant Accounting Policies [Line Items]
Range of term contracts, years	five
Marine Transportation Segment [Member] | Minimum [Member]
Significant Accounting Policies [Line Items]
Range of term contracts, years	one
Diesel Engine Services Segment [Member]
Significant Accounting Policies [Line Items]
Net goodwill	$ 207,305,000	$ 75,003,000

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Acquisitions (Tables)

12 Months Ended

Dec. 31, 2011

Business Acquisition [Line Items]

Pro Forma Revenues, Basic And Diluted Net Earnings Per Share

	2011 Pro forma		2010 Pro forma		2009 Pro forma
Revenues	$	2,105,904	$	1,685,173	$	1,554,806
Net earnings attributable to Kirby	$	172,426	$	123,981	$	138,726
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.10	$	2.22	$	2.49
Diluted	$	3.09	$	2.22	$	2.49

K-Sea Transportation Partners L.P. [Member]

Business Acquisition [Line Items]

Consideration Transferred

Cash consideration paid	$	227,617
Cash to retire K-Sea's outstanding debt		262,791
Stock consideration through issuance of Company common stock		113,019
Fair value of consideration transferred	$	603,427

Fair Values Of Assets Acquired And Liabilities Assumed

Assets:
Cash	$	4,044
Accounts receivable		40,013
Other current assets		8,881
Property and equipment		495,312
Goodwill		113,973
Deferred income taxes		3,439
Other assets		26,126
Total assets	$	691,788
Liabilities:
Accounts payable	$	27,279
Accrued liabilities		40,675
Deferred revenues		8,224
Other long-term liabilities		8,100
Non-controlling interests		4,083
Total liabilities	$	88,361
Net assets acquired	$	603,427

United Holdings LLC [Member]

Business Acquisition [Line Items]

Consideration Transferred

Cash consideration paid	$	271,192
Fair value of contingent earnout provision payable in 2014		16,300
Fair value of consideration transferred	$	287,492

Fair Values Of Assets Acquired And Liabilities Assumed

Assets:
Accounts receivable	$	71,427
Inventories		64,680
Other current assets		1,246
Property and equipment		16,629
Goodwill		132,302
Other assets		75,864
Total assets	$	362,148
Liabilities:
Accounts payable	$	39,809
Accrued liabilities		7,202
Deferred revenues		27,331
Deferred income taxes		314
Total liabilities	$	74,656
Net assets acquired	$	287,492

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Stock Award Plans (Schedule Of Share-Based Payment Award, Stock Options, Valuation Assumption) (Details)	12 Months Ended
	Dec. 31, 2011 years	Dec. 31, 2010 years	Dec. 31, 2009 years
Stock Award Plans [Abstract]
Dividend yield	0.00%	0.00%	0.00%
Average risk-free interest rate	2.40%	3.10%	1.90%
Stock price volatility	33.00%	33.00%	33.00%
Estimated option term years, minimum	6	6	4
Estimated option term years, maximum	7	7	8

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Consolidated Statements Of Cash Flows (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Cash flows from operating activities:
Net earnings	$ 185,492	$ 117,382	$ 127,538
Adjustments to reconcile net earnings to net cash provided by operations:
Depreciation and amortization	126,029	95,296	93,968
Provision (credit) for doubtful accounts	266	(15)	(1,104)
Provision for deferred income taxes	70,004	34,439	42,424
Loss (gain) on disposition of assets	40	78	(1,079)
Equity in earnings of affiliates	(347)	(283)	(874)
Amortization of unearned share-based compensation	9,228	10,867	9,855
Impairment of goodwill			1,901
Other	901		(104)
Increase (decrease) in cash flows resulting from changes in:
Accounts receivable	(58,351)	(17,563)	59,083
Inventory	(26,355)	973	8,724
Other assets	(7,247)	(2,511)	(1,585)
Income taxes payable	3,026	(13,284)	3,557
Accounts payable	21,492	19,262	(25,929)
Accrued and other liabilities	(12,183)	605	3,510
Net cash provided by operating activities	311,995	245,246	319,885
Cash flows from investing activities:
Capital expenditures	(226,238)	(136,841)	(192,660)
Acquisitions of businesses and marine equipment, net of cash acquired	(859,512)
Proceeds from disposition of assets	11,821	9,725	7,388
Retirement of interest rate swaps assumed in acquisition	(14,803)
Net cash used in investing activities	(1,088,732)	(127,116)	(185,272)
Cash flows from financing activities:
Borrowings on long-term debt	531,646
Borrowings (payments) on bank credit facilities, net	95,000		(46,000)
Payments on long-term debt, net	(33,128)	(105)	(1,087)
Return of investment to noncontrolling interests	(2,115)	(1,794)	(1,782)
Proceeds from noncontrolling interest investments	268	69	315
Proceeds from exercise of stock options	4,367	4,884	2,774
Purchase of treasury stock		(23,793)	(657)
Excess tax benefit from equity compensation plans	1,348	373	1,013
Net cash provided by (used in) financing activities	597,386	(20,366)	(45,424)
Increase (decrease) in cash and cash equivalents	(179,351)	97,764	89,189
Cash and cash equivalents, beginning of year	195,600	97,836	8,647
Cash and cash equivalents, end of year	16,249	195,600	97,836
Supplemental disclosures of cash flow information:
Interest	16,455	10,604	10,899
Income taxes	34,926	50,743	31,005
Noncash investing activity:
Stock issued in acquisition	113,019
Cash acquired in acquisition	4,044
Disposition of assets for receivables	$ 682	$ 1,569	$ 934

XML

Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Consolidated Balance Sheets [Abstract]
Trade, allowance for doubtful accounts	$ 5,007	$ 4,000
Common stock, par value per share	$ 0.1	$ 0.1
Common stock, shares authorized	120,000,000	120,000,000
Common stock, shares issued	59,276,000	59,276,000
Treasury stock, shares	3,532,000	3,780,000

XML

Retirement Plans

12 Months Ended

Dec. 31, 2011

Retirement Plans [Abstract]

Retirement Plans

(10) 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 fair value of plan assets was $174,223,000 and $152,696,000 at December 31, 2011 and 2010, respectively. As of December 31, 2011 and 2010, these assets were allocated among asset categories as follows:

Asset Category	2011			2010			Current Minimum, Target and Maximum Allocation Policy
U.S. equity securities		43	%		50	%	30% — 50% — 70%
International equity securities		16	%		20	%	0% — 20% — 30%
Debt securities		25	%		29	%	15% — 30% — 55%
Cash and cash equivalents		16	%		1	%	0% — 0% — 5%
		100	%		100	%

The cash and cash equivalents asset category exceeded the maximum percentage allocation in 2011 due to the 2011 pension plan contribution of $27,500,000 being funded on the last day of 2011 which resulted in insufficient time to properly allocate the contribution among the asset categories. The Company allocated the contribution among the appropriate asset categories in January 2012.

The plan assets are invested entirely in common collective trusts. These instruments are public investment vehicles valued using the net asset value provided by the administrator of the fund. The net asset value is classified within Level 2 of the valuation hierarchy as set forth in the accounting guidance for fair value measurements because the net asset value price is quoted on an inactive private market although the underlying investments are traded on an active market.

The Company's investment strategy focuses on total return on invested assets (capital appreciation plus dividend and interest income). The primary objective in the investment management of assets is to achieve long-term growth of principal while avoiding excessive risk. Risk is managed through diversification of investments within and among asset classes, as well as by choosing securities that have an established trading and underlying operating history.

The Company makes various assumptions when determining defined benefit plan costs including, but not limited to, the current discount rate and the expected long-term return on plan assets. Discount rates are determined annually and are based on a yield curve that consists of a hypothetical portfolio of high quality corporate bonds with maturities matching the projected benefit cash flows. The Company assumed that plan assets would generate a long-term rate of return of 7.5% in 2011 and 2010. The Company developed its expected long-term rate of return assumption by evaluating input from investment consultants comparing historical returns for various asset classes with its actual and targeted plan investments. The Company believes that its long-term asset allocation, on average, will approximate the targeted allocation.

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. The Company's contribution of $27,500,000 in December 2011 resulted in funding 97% of the pension plan's ABO at December 31. 2011.

The Company sponsors an unfunded defined benefit health care plan that provides limited postretirement medical benefits to employees who met 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 following table presents the change in benefit obligation and plan assets for the Company's defined benefit plans and postretirement benefit plan (in thousands):

													Other Postretirement Benefits
	Pension Benefits												Postretirement Welfare Plan
	Pension Plan						SERP
	2011			2010			2011			2010			2011			2010
Change in benefit obligation
Benefit obligation at beginning of year	$	170,742		$	141,338		$	1,511		$	1,429		$	2,790		$	5,459
Service cost		7,303			6,883			—			—			—			—
Interest cost		9,693			9,399			80			84			164			154
Actuarial loss (gain)		33,662			17,124			157			101			182			(3,108	)
Plan amendments		—			—			—			—			—			519
Gross benefits paid		(4,474	)		(4,002	)		(103	)		(103	)		(122	)		(234	)
Benefit obligation at end of year	$	216,926		$	170,742		$	1,645		$	1,511		$	3,014		$	2,790
Accumulated benefit obligation at end of year	$	179,190		$	141,666		$	1,645		$	1,511		$	—		$	—

Weighted-average assumption used to determine benefit obligation at end of year
Discount rate	4.6	%	5.5	%	4.6	%	5.5	%	4.6	%	5.5	%
Rate of compensation increase	4.25	%	4.25	%	—		—		—		—
Health care cost trend rate
Initial rate	—		—		—		—		7.5	%	8.0	%
Ultimate rate	—		—		—		—		5.0	%	5.0	%
Years to ultimate	—		—		—		—		2017		2017

Effect of one-percentage-point change in assumed health care cost trend rate on postretirement obligation
Increase	$	—	$	—	$	—	$	—	$	285		$	223
Decrease		—		—		—		—		(250	)		(196	)

Change in plan assets
Fair value of plan assets at beginning of year	$	152,696		$	126,490		$	—		$	—		$	—		$	—
Actual return on plan assets		(1,499	)		18,308			—			—			—			—
Employer contribution		27,500			11,900			103			103			122			234
Gross benefits paid		(4,474	)		(4,002	)		(103	)		(103	)		(122	)		(234	)
Fair value of plan assets at end of year	$	174,223		$	152,696		$	—		$	—		$	—		$	—

The following table presents the funded status and amounts recognized in the Company's consolidated balance sheet for the Company's defined benefit plans and postretirement benefit plan at December 31, 2011 and 2010 (in thousands):

													Other Postretirement Benefits
	Pension Benefits												Postretirement
	Pension Plan						SERP						Welfare Plan
	2011			2010			2011			2010			2011			2010
Funded status at end of year
Fair value of plan assets	$	174,223		$	152,696		$	—		$	—		$	—		$	—
Benefit obligations		216,926			170,742			1,645			1,511			3,014			2,790
Funded status and amount recognized at end of year	$	(42,703	)	$	(18,046	)	$	(1,645	)	$	(1,511	)	$	(3,014	)	$	(2,790	)

Amounts recognized in the consolidated balance sheets
Current liability	$	—		$	—		$	(102	)	$	(102	)	$	(256	)	$	(246	)
Long-term liability		(42,703	)		(18,046	)		(1,543	)		(1,409	)		(2,758	)		(2,544	)

Amounts recognized in accumulated other comprehensive income
Net actuarial loss (gain)	$	86,633	$	43,048		$	442	$	293	$	(6,751	)	$	(7,523	)
Prior service cost (credit)		—		(38	)		—		—		—			158
Accumulated other compensation income	$	86,633	$	43,010		$	442	$	293	$	(6,751	)	$	(7,365	)

The projected benefit obligation and fair value of plan assets for pension plans with a projected benefit obligation in excess of plan assets at December 31, 2011 and 2010 were as follows (in thousands):

	Pension Benefits
	Pension Plan				SERP
	2011		2010		2011		2010
Projected benefit obligation in excess of plan assets
Projected benefit obligation at end of year	$	216,926	$	170,742	$	1,645	$	1,511
Fair value of plan assets at end of year		174,223		152,696		—		—

The projected benefit obligation, accumulated benefit obligation and fair value of plan assets for pension plans with an accumulated benefit obligation in excess of plan assets at December 31, 2011 and 2010 were as follows (in thousands):

	Pension Benefits
	Pension Plan				SERP
	2011		2010		2011		2010
Accumulated benefit obligation in excess of plan assets
Projected benefit obligation at end of year	$	216,926	$	—	$	1,645	$	1,511
Accumulated benefit obligation at end of year		179,190		—		1,645		1,511
Fair value of plan assets at end of year		174,223		—		—		—

The following tables presents the expected cash flows for the Company's defined benefit plans and postretirement benefit plan at December 31, 2011 and 2010 (in thousands):

									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011		2010
Expected employer contributions
First year	$	11,800	$	—	$	102	$	102	$	256	$	246

									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011		2010
Expected benefit payments (gross)
Year one	$	5,142	$	4,639	$	102	$	102	$	271	$	262
Year two		5,590		5,058		100		100		264		261
Year three		6,113		5,480		98		99		268		253
Year four		6,649		5,997		97		97		271		257
Year five		7,252		6,524		105		95		271		258
Next five years		47,701		42,703		597		558		1,343		1,274

									Other Postretirement Benefits
	Pension Benefits								Postretirement
	Pension Plan				SERP				Welfare Plan
	2011		2010		2011		2010		2011			2010
Expected federal subsidy
Year one	$	—	$	—	$	—	$	—	$	(15	)	$	(16	)
Year two		—		—		—		—		(15	)		(16	)
Year three		—		—		—		—		(15	)		(16	)
Year four		—		—		—		—		(15	)		(16	)
Year five		—		—		—		—		(15	)		(16	)
Next five years		—		—		—		—		(67	)		(74	)

The components of net periodic benefit cost and other changes in plan assets and benefit obligations recognized in other comprehensive income for the Company's defined benefit plans for the years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	Pension Benefits
	Pension Plan									SERP
	2011			2010			2009			2011			2010			2009
Components of net periodic benefit cost
Service cost	$	7,303		$	6,883		$	6,523		$	—		$	—		$	—
Interest cost		9,693			9,399			8,486			80			84			84
Expected return on plan assets		(11,283	)		(9,329	)		(7,333	)		—			—			—
Amortization:
Actuarial loss		2,859			3,162			5,666			7			2			2
Prior service credit		(38	)		(89	)		(88	)		—			—			—
Net periodic benefit cost		8,534			10,026			13,254			87			86			86
Other changes in plan assets and benefit obligations recognized in other comprehensive income
Current year actuarial loss (gain)		46,444			8,145			(28,443	)		156			102			14
Recognition of actuarial loss		(2,859	)		(3,162	)		(5,666	)		(7	)		(2	)		(2	)
Recognition of prior service credit		38			89			88			—			—			—
Total recognized in other comprehensive income		43,623			5,072			(34,021	)		149			100			12
Total recognized in net periodic benefit cost and other comprehensive income	$	52,157		$	15,098		$	(20,767	)	$	236		$	186		$	98

Weighted average assumptions used to determine net periodic benefit cost
Discount rate	5.5	%	6.1	%	6.1	%	5.5	%	6.1	%	6.1	%
Expected long-term rate of return on plan assets	7.5	%	7.5	%	7.5	%	—		—		—
Rate of compensation increase	4.25	%	4.0	%	4.0	%	—		—		—

The estimated amounts that will be amortized from accumulated other comprehensive income into net periodic benefit cost in 2012 are as follows (in thousands):

	Pension Benefits
	Pension Plan		SERP
Actuarial loss	$	7,007	$	14
Prior service credit		—		—
	$	7,007	$	14

The components of net periodic benefit cost and other changes in benefit obligations recognized in other comprehensive income for the Company's postretirement benefit plan for the years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	Other Postretirement Benefits
	Postretirement Welfare Plan
	2011			2010			2009
Components of net periodic benefit cost
Service cost	$	—		$	—		$	246
Interest cost		164			154			322
Curtailment loss		119			—			—
Amortization:
Actuarial gain		(593	)		(660	)		(325	)
Prior service cost		40			560			40
Net periodic benefit cost		(270	)		54			283
Other changes in benefit obligations recognized in other comprehensive income
Current year actuarial gain		182			(3,109	)		(141	)
Recognition of actuarial gain		593			660			325
Recognition of prior service cost		(158	)		(40	)		(40	)
Adjustment for actual Medicare Part D reimbursement		(3	)		(10	)		—
Total recognized in other comprehensive income		614			(2,499	)		144
Total recognized in net periodic benefit cost and other comprehensive income	$	344		$	(2,445	)	$	427

Weighted average assumptions used to determine net periodic benefit cost
Discount rate	5.5	%	6.1	%	6.1	%
Health care cost trend rate:
Initial rate	8.0	%	7.5	%	8.0	%
Ultimate rate	5.0	%	5.0	%	5.0	%
Years to ultimate	2017		2015		2015

Effect of one-percentage-point change in assumed health care cost trend rate on aggregate service and interest cost
Increase	$	16		$	14		$	12
Decrease		(14	)		(12	)		(11	)

The estimated amounts that will be amortized from accumulated other comprehensive income into net periodic benefit cost in 2012 are as follows (in thousands):

	Other Postretirement Benefits
	Postretirement Welfare Plan
Actuarial gain	$	(616	)
Prior service cost		—
	$	(616	)

In addition to the defined benefit plan, the Company sponsors various defined contribution plans for substantially all employees. The aggregate contributions to the plans were $13,793,000, $11,614,000 and $13,682,000 in 2011, 2010 and 2009, respectively.

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Related Party Transactions (Details) (USD $)	12 Months Ended
	Dec. 31, 2011
Related Party Transaction [Line Items]
Rental expenses	$ 1,491,000
Oilfield service equipment	7,978,000
Facility expenses	2,121,000
Legal services	483,000
Shoreside marine construction	$ 1,160,000
Lawrence And His Family [Member]
Related Party Transaction [Line Items]
Ownership percentage	60.00%
Hollywood Camp [Member]
Related Party Transaction [Line Items]
Ownership percentage	50.00%
L3 Partners [Member]
Related Party Transaction [Line Items]
Ownership percentage	50.00%
MB Western [Member]
Related Party Transaction [Line Items]
Ownership percentage	50.00%

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Segment Data (Other Segment Loss) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Segment Data [Abstract]
General corporate expenses									$ (17,915)	$ (13,189)	$ (12,239)
Impairment of goodwill											(1,901)
Interest expense	(5,817)	(5,974)	(3,278)	(2,833)	(2,845)	(2,750)	(2,697)	(2,668)	(17,902)	(10,960)	(11,080)
Gain (loss) on disposition of assets	(111)	97	40	(66)	(23)	8	(19)	(44)	(40)	(78)	1,079
Other income									306	556	608
Profit (loss) from other segment									$ (35,551)	$ (23,671)	$ (23,533)

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Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2011	Feb. 22, 2012	Jun. 30, 2011
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2011
Document Fiscal Year Focus	2011
Document Fiscal Period Focus	FY
Entity Registrant Name	KIRBY CORP
Entity Central Index Key	0000056047
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		55,847,000
Entity Well-known Seasoned Issuer	Yes
Entity Public Float			$ 2,915,796,000
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No

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Earnings Per Share

12 Months Ended

Dec. 31, 2011

Earnings Per Share [Abstract]

Earnings Per Share

(11) Earnings Per Share

The following table presents the components of basic and diluted earnings per share for the years ended December 31, 2011, 2010 and 2009 (in thousands, except per share amounts):

	2011			2010			2009
Net earnings attributable to Kirby	$	183,026		$	116,249		$	125,941
Undistributed earnings allocated to restricted shares		(1,613	)		(1,125	)		(1,403	)
Income available to Kirby common stockholders — basic		181,413			115,124			124,538
Undistributed earnings allocated to restricted shares		1,613			1,125			1,403
Undistributed earnings reallocated to restricted shares		(1,606	)		(1,122	)		(1,400	)
Income available to Kirby common stockholders — diluted	$	181,420		$	115,127		$	124,541
Shares outstanding:
Weighted average common stock issued and outstanding		54,673			53,852			53,791
Weighted average unvested restricted stock		(482	)		(521	)		(599	)
Weighted average common stock outstanding — basic		54,191			53,331			53,192
Dilutive effect of stock options		222			135			121
Weighted average common stock outstanding — diluted		54,413			53,466			53,313
Net earnings per share attributable to Kirby common stockholders:
Basic	$	3.35		$	2.16		$	2.34
Diluted	$	3.33		$	2.15		$	2.34

Certain outstanding options to purchase approximately 2,000, 114,000 and 248,000 shares of common stock were excluded in the computation of diluted earnings per share as of December 31, 2011, 2010 and 2009, respectively, as such stock options would have been antidilutive.

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Retirement Plans (Schedule Of Employer Contribution) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	$ 11,800
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	102	102
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected employer contributions	$ 256	$ 246

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Segment Data (Revenues, Profit Or Loss, Total Assets, Depreciation And Amortization And Capital Expenditures By Reportable Segment) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Segment Reporting Information [Line Items]
Marine transportation									$ 1,194,607	$ 915,046	$ 881,298
Diesel engine services									655,810	194,511	200,860
Total revenues	550,145	563,582	437,331	299,359	286,318	281,317	273,669	268,253	1,850,417	1,109,557	1,082,158
Segment profit (loss)	87,279	86,328	68,279	52,861	51,202	50,116	47,965	40,357	294,747	189,640	205,558
Total assets	2,960,411				1,794,937				2,960,411	1,794,937	1,635,963
Depreciation and amortization									126,029	95,296	93,968
Capital expenditures									226,238	136,841	192,660
Marine Transportation [Member]
Segment Reporting Information [Line Items]
Segment profit (loss)									262,193	192,758	208,086
Total assets	2,307,821				1,383,252				2,307,821	1,383,252	1,336,358
Depreciation and amortization									111,292	88,710	87,589
Capital expenditures									218,777	132,744	188,479
Diesel Engine Services [Member]
Segment Reporting Information [Line Items]
Segment profit (loss)									68,105	20,553	21,005
Total assets	608,886				185,824				608,886	185,824	185,573
Depreciation and amortization									11,801	4,055	4,247
Capital expenditures									5,576	920	1,768
Other [Member]
Segment Reporting Information [Line Items]
Segment profit (loss)									(35,551)	(23,671)	(23,533)
Total assets	43,704				225,861				43,704	225,861	114,032
Depreciation and amortization									2,936	2,531	2,132
Capital expenditures									$ 1,885	$ 3,177	$ 2,413

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Consolidated Statements Of Earnings (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Revenues:
Marine transportation	$ 1,194,607	$ 915,046	$ 881,298
Diesel engine services	655,810	194,511	200,860
Total revenues	1,850,417	1,109,557	1,082,158
Costs and expenses:
Costs of sales and operating expenses	1,228,440	683,236	637,833
Selling, general and administrative	170,386	117,694	121,401
Taxes, other than on income	13,179	13,209	12,104
Depreciation and amortization	126,029	95,296	93,968
Impairment of goodwill			1,901
Loss (gain) on disposition of assets	40	78	(1,079)
Total costs and expenses	1,538,074	909,513	866,128
Operating income	312,343	200,044	216,030
Equity in earnings of affiliates	347	283	874
Other income (expense)	(41)	273	(266)
Interest expense	(17,902)	(10,960)	(11,080)
Earnings before taxes on income	294,747	189,640	205,558
Provision for taxes on income	(109,255)	(72,258)	(78,020)
Net earnings	185,492	117,382	127,538
Less: Net earnings attributable to noncontrolling interests	(2,466)	(1,133)	(1,597)
Net earnings attributable to Kirby	$ 183,026	$ 116,249	$ 125,941
Net earnings per share attributable to Kirby common stockholders:
Basic	$ 3.35	$ 2.16	$ 2.34
Diluted	$ 3.33	$ 2.15	$ 2.34

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Derivative Instruments

12 Months Ended

Dec. 31, 2011

Derivative Instruments [Abstract]

Derivative Instruments

(5) 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. Special accounting for derivatives qualifying as fair value hedges allows a derivative's gains and losses to offset related results on the hedged item in the statement of earnings. 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 and expects to continue to utilize 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. Derivative financial instruments related to the Company's interest rate risks are intended to reduce the Company's exposure to increases in the benchmark interest rates underlying the Company's floating rate senior notes, variable rate term loan and variable rate bank revolving credit facility.

From time to time, the Company hedges its exposure to fluctuations in short-term interest rates under its variable rate bank revolving credit facility and floating rate senior notes by entering into interest rate swap agreements. The interest rate swap agreements are designated as cash flow hedges, therefore, the changes in fair value, to the extent the swap agreements are effective, are recognized in OCI until the hedged interest expense is recognized in earnings. The current swap agreements effectively convert the Company's interest rate obligation on the Company's variable rate senior notes from quarterly floating rate payments based on the London Interbank Offered Rate ("LIBOR") to quarterly fixed rate payments. As of December 31, 2011, the Company had a total notional amount of $200,000,000 of interest rate swaps designated as cash flow hedges for its variable rate senior notes as follows (dollars in thousands):

Notional Amount	Effective date	Termination date	Fixed pay rate			Receive rate
$100,000	March 2006	February 2013		5.45	%	Three-month LIBOR
$50,000	November 2008	February 2013		3.50	%	Three-month LIBOR
$50,000	May 2009	February 2013		3.795	%	Three-month LIBOR

Foreign Currency Risk Management

From time to time, the Company has utilized and expects to continue to utilize 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 December 31, 2011, the Company had forward contracts with notional amounts aggregating $5,406,000 to hedge its exposure to foreign currency rate fluctuations in expected foreign currency transactions. These contracts expire on various dates beginning in the first quarter of 2012 and ending in the first quarter of 2014. These forward contracts are designated as cash flow hedges, therefore, the changes in fair value, to the extent the forward contracts are effective, are recognized in OCI until the forward contracts expire and are 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 December 31, 2011 and 2010 (in thousands):

Liability Derivatives	Balance Sheet Location	2011		2010
Derivatives designated as hedging instruments under ASC 815:
Foreign currency contracts	Other accrued liabilities	$	363	$	798
Foreign currency contracts	Other long-term liabilities		32		569
Interest rate contracts	Other long-term liabilities		9,202		16,209
Total derivatives designated as hedging instruments under ASC 815		$	9,597	$	17,576
Total liability derivatives		$	9,597	$	17,576

Fair value amounts were derived as of December 31, 2011 and 2010 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 4, 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 years ended December 31, 2011, 2010 and 2009 (in thousands):

Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	7,007		$	(908	)	$	5,701
Foreign exchange contracts		Cost of sales and operating expenses		929			(1,419	)		(51	)
Total			$	7,936		$	(2,327	)	$	5,650
Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	(8,586	)	$	(8,529	)	$	(7,356	)
Foreign exchange contracts		Cost of sales and operating expenses		(13	)		(411	)		—
Total			$	(8,599	)	$	(8,940	)	$	(7,356	)

The Company anticipates $4,781,000 of net losses on interest rate swap agreements included in accumulated OCI will be transferred into earnings over the next year based on current interest rates. Gains or losses on interest rate swap agreements offset increases or decreases in rates of the underlying debt, which results in a fixed rate for the underlying debt. The Company also expects $211,000 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.

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Fair Value Measurements

12 Months Ended

Dec. 31, 2011

Fair Value Measurements [Abstract]

Fair Value Measurements

(4) 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 at December 31, 2011 and 2010 (in thousands):

	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
December 31, 2011:
Assets:
Derivatives	$	—	$	—	$	—	$	—
Liabilities:
Derivatives	$	—	$	9,597	$	—	$	9,597
Contingent earnout liability		—		—		22,600		22,600
	$	—	$	9,597	$	22,600	$	32,197

	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
December 31, 2010:
Assets:
Derivatives	$	—	$	—	$	—	$	—
Liabilities:
Derivatives	$	—	$	17,576	$	—	$	17,576

The fair value of the Company's derivative instruments is more fully described below in Note 5, Derivative Instruments.

In connection with the acquisition of 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 increase in the fair value of the earnout liability of $6,300,000 for 2011 was charged to selling, general and administrative expense. As of December 31, 2011, the Company had recorded an earnout liability of $22,600,000.

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. The Company is of the opinion that amounts included in the consolidated financial statements for outstanding debt materially represent the fair value of such debt due to their variable interest rates.

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 years ended December 31, 2011 and 2010, there was no indication that the Company's long-lived assets were impaired, and accordingly, measurement at fair value was not required.

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Summary Of Significant Accounting Policies (Policy)

12 Months Ended

Dec. 31, 2011

Summary Of Significant Accounting Policies [Abstract]

Principles Of Consolidation

Principles of Consolidation. The consolidated financial statements include the accounts of Kirby Corporation and all majority-owned subsidiaries ("the Company"). Two affiliated limited partnerships, in which the Company owns a 50% interest, is the general partner and has effective control and whose activities are an integral part of the operations of the Company, are consolidated. All other investments in which the Company owns 20% to 50% and exercises significant influence over operating and financial policies are accounted for using the equity method. All material intercompany accounts and transactions have been eliminated in consolidation. Certain reclassifications have been made to reflect the current presentation of financial information.

Cash Equivalents

Cash Equivalents. Cash equivalents consist of all short-term, highly liquid investments with maturities of three months or less at date of purchase.

Accounts Receivable

Accounts Receivable. In the normal course of business, the Company extends credit to its customers. The Company regularly reviews the accounts and makes adequate provisions for probable uncollectible balances. It is the Company's opinion that the accounts have no impairment, other than that for which provisions have been made. Included in accounts receivable as of December 31, 2011 and 2010 were $53,083,000 and $24,626,000, respectively, of accruals for revenues earned which have not been invoiced as of the end of each year.

The Company's marine transportation and diesel engine services operations are subject to hazards associated with such businesses. The Company maintains insurance coverage against these hazards with insurance companies. Included in accounts receivable as of December 31, 2011 and 2010 were $15,530,000 and $3,453,000, respectively, of receivables from insurance companies to cover claims in excess of the Company's deductible.

Concentrations Of Credit Risk

Concentrations of Credit Risk. Financial instruments which potentially subject the Company to concentrations of credit risk are primarily trade accounts receivables. The Company's marine transportation customers include the major oil refining and petrochemical companies. The diesel engine services customers are oil and gas service companies, marine transportation companies, commercial fishing companies, power generation companies, and the United States government. The Company regularly reviews its accounts and estimates the amount of uncollectible receivables each period and establishes an allowance for uncollectible amounts. The amount of the allowance is based on the age of unpaid amounts, information about the current financial strength of customers, and other relevant information. Estimates of uncollectible amounts are revised each period, and changes are recorded in the period they become known.

Fair Value Of Financial Instruments

Fair Value of Financial Instruments. Cash, accounts receivable, accounts payable and accrued liabilities have carrying values that approximate fair value due to the short-term maturity of these financial instruments. The fair value of the Company's debt instruments is more fully described in Note 6, Long-Term Debt.

Property, Maintenance And Repairs

Property, Maintenance and Repairs. Property is recorded at cost. Improvements and betterments are capitalized as incurred. Depreciation is recorded on the straight-line method over the estimated useful lives of the individual assets as follows: marine transportation equipment, 5-40 years; buildings, 10-40 years; other equipment, 2-10 years; and leasehold improvements, term of lease. When property items are retired, sold or otherwise disposed of, the related cost and accumulated depreciation are removed from the accounts with any gain or loss on the disposition included in the statement of earnings. Maintenance and repairs on vessels built for use on the inland waterways are charged to operating expense as incurred and includes the costs incurred in United States Coast Guard ("USCG") inspections unless the shipyard extends the life or improves the operating capacity of the vessel which results in the costs being capitalized.

Drydocking On Ocean-Going Vessels

Drydocking on Ocean-Going Vessels. The Company's ocean-going vessels are subject to regulatory drydocking requirements after certain periods of time to be inspected, have planned major maintenance performed and be recertified by the American Bureau of Shipping ("ABS"). These recertifications generally occur twice in a five year period. The Company defers the drydocking expenditures incurred on its ocean-going vessels due to regulatory marine inspections by the ABS and amortizes the costs of the shipyard over the period between drydockings, generally 30 months, unless the drydocking extends the life or improves the operating capability of the vessels which results in the costs being capitalized. Routine repairs and maintenance on ocean-going vessels are expensed as incurred.

Environmental Liabilities

Environmental Liabilities. The Company expenses costs related to environmental events as they are incurred or when a loss is considered probable and estimable.

Goodwill

Goodwill. The excess of the purchase price over the fair value of identifiable net assets acquired in transactions accounted for as a purchase is included in goodwill. The Company conducted its annual goodwill impairment test at November 30, 2011 and 2010. For 2011 and 2010, the Company noted no impairment of goodwill. The Company will continue to conduct goodwill impairment tests as of November 30 of subsequent years, or whenever events or circumstances indicate that interim impairment testing is necessary. The gross carrying value of goodwill at December 31, 2011 and 2010 was $500,935,000 and $246,340,000, respectively, and accumulated amortization at December 31, 2011 and 2010 was $15,566,000. Accumulated impairment losses were $1,901,000 at December 31, 2011 and 2010.

Net goodwill for the marine transportation segment was $276,163,000 and $153,870,000 at December 31, 2011 and 2010, respectively. Net goodwill for the diesel engine services segment was $207,305,000 and $75,003,000 at December 31, 2011 and 2010, respectively.

Revenue Recognition

Revenue Recognition. The majority of marine transportation revenue is derived from term contracts, ranging from one to five years, some of which have renewal options, and the remainder is from spot market movements. The majority of the term contracts are for terms of one year. The Company is a provider of marine transportation services for its customers and, in almost all cases, does not assume ownership of the products it transports. A term contract is an agreement with a specific customer to transport cargo from a designated origin to a designated destination at a set rate or at a daily rate. The rate may or may not escalate during the term of the contract, however, the base rate generally remains constant and contracts often include escalation provisions to recover changes in specific costs such as fuel. A spot contract is an agreement with a customer to move cargo from a specific origin to a designated destination for a rate negotiated at the time the cargo movement takes place. Spot contract rates are at the current "market" rate, including fuel, and are subject to market volatility. The Company uses a voyage accounting method of revenue recognition for its marine transportation revenues which allocates voyage revenue based on the percent of the voyage completed during the period. There is no difference in the recognition of revenue between a term contract and a spot contract.

Diesel engine service products and services are generally sold based upon purchase orders or preferential service agreements with the customer that include fixed or determinable prices and that do not include right of return or significant post delivery performance obligations. Diesel engine parts sales are recognized when title passes upon shipment to customers or when customer-specific acceptance requirements are met. Service revenue is recognized as the service is provided. Diesel manufacturing and assembly projects revenue is reported on the percentage of completion method of accounting using measurements of progress towards completion appropriate for the work performed.

Stock-Based Compensation

Stock-Based Compensation. The Company has share-based compensation plans covering selected officers and other key employees as well as the Company's Board of Directors. Stock-based grants made under the Company's stock plans are recorded at fair value on the date of the grant and the cost is recognized ratably over the vesting period of the stock option or restricted stock. Stock option grants are valued at the date of grant as calculated under the Black-Scholes option pricing model. The Company's stock-based compensation plans are more fully described in Note 9, Stock Award Plans.

Taxes On Income

Taxes on Income. The Company follows the asset and liability method of accounting for income taxes. Under the asset and liability method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

Accrued Insurance

Accrued Insurance. Accrued insurance liabilities include estimates based on individual incurred claims outstanding and an estimated amount for losses incurred but not reported ("IBNR") or fully developed based on past experience. Insurance premiums, IBNR losses and incurred claim losses, up to the Company's deductible, for 2011, 2010 and 2009 were $18,673,000, $13,461,000 and $12,786,000, respectively.

Noncontrolling Interests

Noncontrolling Interests. The Company has a majority interest in and is the general partner in several affiliated entities. In situations where losses applicable to the minority interest in the affiliated entities exceed the limited partners' equity capital, such excess and any further loss attributable to the minority interest is charged against the Company's interest in the affiliated entities. If future earnings materialize in the respective affiliated entities, the Company's interest would be credited to the extent of any losses previously absorbed.

Treasury Stock

Treasury Stock. The Company follows the average cost method of accounting for treasury stock transactions.

Impairment Of Long-Lived Assets And For Long-Lived Assets To Be Disposed Of

Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed Of. The Company reviews long-lived assets and certain identifiable intangibles for impairment by vessel class whenever events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable.

Recoverability on marine transportation assets is assessed based on vessel classes, not on individual assets, because identifiable cash flows for individual marine transportation assets are not available. Projecting customer contract volumes allows estimation of future cash flows by projecting pricing and utilization by vessel class but it is not practical to project which individual marine transportation asset will be utilized for any given contract. Because customers do not specify which particular vessel is used, prices are quoted based on vessel classes not individual assets. Nominations of vessels for specific jobs are determined on a day by day basis and are a function of the equipment class required and the geographic position of vessels within that class at that particular time as vessels within a class are interchangeable and provide the same service. The Company's vessels are mobile assets and equipped to operate in geographic regions throughout the United States and the Company has in the past and expects to continue to move vessels from one region to another when it is necessary due to changing markets and it is economical to do so. Barge vessel classes are based on similar capacities, hull type, and type of product and towing vessels are based on similar hull type and horsepower. Recoverability of the vessel classes is measured by a comparison of the carrying amount of the assets to future net cash flows expected to be generated by the assets. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. Assets to be disposed of are reported at the lower of the carrying amount or fair value less costs to sell.

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Quarterly Results

12 Months Ended

Dec. 31, 2011

Quarterly Results [Abstract]

Quarterly Results

(12) Quarterly Results (Unaudited)

The unaudited quarterly results for the year ended December 31, 2011 were as follows (in thousands, except per share amounts):

	Three Months Ended
	March 31, 2011			June 30, 2011			September 30, 2011			December 31, 2011
Revenues	$	299,359		$	437,331		$	563,582		$	550,145
Costs and expenses		243,650			365,892			471,371			457,121
Gain (loss) on disposition of assets		(66	)		40			97			(111	)
Operating income		55,643			71,479			92,308			92,913
Other income (expense)		51			78			(6	)		183
Interest expense		(2,833	)		(3,278	)		(5,974	)		(5,817	)
Earnings before taxes on income		52,861			68,279			86,328			87,279
Provision for taxes on income		(19,961	)		(26,050	)		(32,734	)		(30,510	)
Net earnings		32,900			42,229			53,594			56,769
Less: Net earnings attributable to noncontrolling interests		(470	)		(537	)		(860	)		(599	)
Net earnings attributable to Kirby	$	32,430		$	41,692		$	52,734		$	56,170
Net earnings per share attributable to Kirby common stockholders:
Basic	$	.60		$	.78		$	.95		$	1.01
Diluted	$	.60		$	.77		$	.94		$	1.00

The unaudited quarterly results for the year ended December 31, 2010 were as follows (in thousands, except per share amounts):

	Three Months Ended
	March 31, 2010			June 30, 2010			September 30, 2010			December 31, 2010
Revenues	$	268,253		$	273,669		$	281,317		$	286,318
Costs and expenses		225,196			223,018			228,590			232,631
Gain (loss) on disposition of assets		(44	)		(19	)		8			(23	)
Operating income		43,013			50,632			52,735			53,664
Other income		12			30			131			383
Interest expense		(2,668	)		(2,697	)		(2,750	)		(2,845	)
Earnings before taxes on income		40,357			47,965			50,116			51,202
Provision for taxes on income		(15,446	)		(18,322	)		(19,211	)		(19,279	)
Net earnings		24,911			29,643			30,905			31,923
Less: Net earnings attributable to noncontrolling interests		(237	)		(375	)		(218	)		(303	)
Net earnings attributable to Kirby	$	24,674		$	29,268		$	30,687		$	31,620
Net earnings per share attributable to Kirby common stockholders:
Basic	$	.46		$	.54		$	.57		$	.59
Diluted	$	.46		$	.54		$	.57		$	.59

Quarterly basic and diluted earnings per share may not total to the full year per share amounts, as the weighted average number of shares outstanding for each quarter fluctuates as a result of the assumed exercise of stock options.

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Retirement Plans (Weighted Average Assumptions Used To Determine Net Periodic Benefit Cost) (Details)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Defined Benefit Plan Disclosure [Line Items]
Expected long-term rate of return on plan assets	7.50%	7.50%
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.50%	6.10%	6.10%
Expected long-term rate of return on plan assets	7.50%	7.50%	7.50%
Rate of compensation increase	4.25%	4.00%	4.00%
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.50%	6.10%	6.10%
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	5.50%	6.10%	6.10%
Initial rate	8.00%	7.50%	8.00%
Ultimate rate	5.00%	5.00%	5.00%
Years to ultimate	2017	2015	2015

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Leases

12 Months Ended

Dec. 31, 2011

Leases [Abstract]

Leases

(8) Leases

The Company and its subsidiaries currently lease various facilities and equipment under a number of cancelable and noncancelable operating leases. Lease agreements for barges have terms from one to 10 years expiring at various dates through 2021. Lease agreements for towing vessels chartered by the Company have terms from 30 days to five years expiring at various dates through 2016; however, the majority of the towing vessel charter agreements are for terms of one year or less. Total rental expense for the years ended December 31, 2011, 2010 and 2009 was as follows (in thousands):

	2011		2010		2009
Rental expense:
Marine equipment — barges	$	16,396	$	9,075	$	9,489
Marine equipment — towing vessels		91,796		79,016		81,453
Other buildings and equipment		8,156		5,334		5,240
Rental expense	$	116,348	$	93,425	$	96,182

Future minimum lease payments under operating leases that have initial or remaining noncancelable lease terms in excess of one year at December 31, 2011 were as follows (in thousands):

	Land, Buildings and Equipment		Marine Equipment
			Barges		Towing Vessels		Total
2012	$	7,164	$	20,151	$	52,888	$	80,203
2013		6,168		18,587		23,020		47,775
2014		5,110		16,722		15,991		37,823
2015		4,857		15,065		9,094		29,016
2016		2,759		11,539		3,034		17,332
Thereafter		6,378		33,446		—		39,824
	$	32,436	$	115,510	$	104,027	$	251,973

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Stock Award Plans (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2011 years	Dec. 31, 2010	Dec. 31, 2009
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Shares available for future grants under stock compensation plan	1,214,718
Options exercised intrinsic value	$ 4,072,000	$ 2,835,000	$ 1,859,000
Tax benefit from stock options exercised	1,560,000	1,086,000	712,000
Nonvested stock, unrecognized compensation cost	1,695,000
Weighted average period of recognition in years	1.4
Total fair value, vested	2,618,000	3,491,000	2,763,000
Restricted stock fair value	7,921,000	8,809,000	5,931,000
Weighted average grant date fair value	$ 18.84	$ 13.81	$ 8.15
Grants in period fair value	3,081,000	2,231,000	2,271,000
Options Granted Prior To January 25, 2010 [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Term of stock compensation plan	five years
Vesting period of stock compensation plan	vest ratably over three years
Options Granted On Or After January 25, 2010 [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Term of stock compensation plan	seven years
Vesting period of stock compensation plan	vest ratably over three years
2000 Director Plan, Stock Options [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Vesting period of stock compensation plan	equal quarterly increments during the year to which they relate
Shares available for future grants under stock compensation plan	252,224
2000 Director Plan, Restricted Stock [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Vesting period of stock compensation plan	equal quarterly increments during the year to which they relate
Restricted Stock [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Restricted stock vesting	$ 7,921,000	$ 8,809,000	$ 5,931,000
Tax benefit from restricted stock vesting	3,034,000	3,374,000	2,271,000
Nonvested stock, unrecognized compensation cost	$ 12,038,000
Weighted average period of recognition in years	2.7
When First Elected A Director [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Vesting period of stock compensation plan	vest immediately
When First Elected A Director [Member] | 2000 Director Plan, Restricted Stock [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Term of stock compensation plan	ten years
After Each Annual Meeting [Member] | 2000 Director Plan, Stock Options [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Vesting period of stock compensation plan	six months
Employee Plans [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Stock options exercisable	226,900	200,210	262,488
Director Plans [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Stock options exercisable	352,987	355,555	301,328

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Long-Term Debt

12 Months Ended

Dec. 31, 2011

Long-Term Debt [Abstract]

Long-Term Debt

(6) Long-Term Debt

Long-term debt at December 31, 2011 and 2010 consisted of the following (in thousands):

	2011		2010
Long-term debt, including current portion:
$540,000,000 term loan due May 31, 2016	$	507,000	$	—
$250,000,000 revolving credit facility due November 9, 2015		95,000		—
Senior notes due February 28, 2013		200,000		200,000
Other long-term debt		5		134
	$	802,005	$	200,134

The aggregate payments due on the long-term debt in each of the next five years were as follows (in thousands):

2012	$	39,005
2013		265,000
2014		91,000
2015		199,000
2016		208,000
Thereafter		—
	$	802,005

On May 31, 2011, the Company entered into 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 a base rate calculated with reference to the agent bank's prime rate, among other factors (the "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. The primary purpose of the Term Loan was to provide financing for the Company's acquisition of K-Sea. The acquisition of K-Sea was completed and the Term Loan funded on July 1, 2011. As of December 31, 2011, the Company was in compliance with all Term Loan covenants and had $507,000,000 outstanding under the Term Loan, $39,000,000 of which was classified as current portion of long-term debt. The Term Loan's average interest rate for 2011 was 1.8%, computed by dividing the interest expense under the Term Loan by the average Term Loan borrowings.

The Company has an 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 Revolving Credit Facility allows for an increase in the commitments of the banks from $250,000,000 up to a maximum of $325,000,000, subject to the consent of each bank that elects to participate in the increased commitment. On May 31, 2011, the Revolving Credit Facility was amended to conform the interest rate spread to the spread provided in the Term Loan described above. The unsecured Revolving Credit Facility has a variable interest rate based on LIBOR or an Alternate Base Rate. The variable interest rate spread varies with the Company's senior debt rating. The variable interest rate spread is currently 1.5% over LIBOR for LIBOR loans and 0.5% over the Alternate Base Rate for Alternate Base Rate loans. 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 December 31, 2011, the Company was in compliance with all Revolving Credit Facility covenants and had $95,000,000 outstanding under the Revolving Credit Facility. The average borrowing under the Revolving Credit Facility during 2011 was $59,608,000, computed by averaging the daily balance, and the weighted average interest rate was 1.9%, computed by dividing the interest expense under the Revolving Credit Facility by the average Revolving Credit Facility borrowing. 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 $2,440,000 as of December 31, 2011.

The Company has $200,000,000 of unsecured floating rate senior notes ("Senior Notes") due February 28, 2013. The Senior Notes pay interest quarterly at a rate equal to LIBOR plus a margin of 0.5%. The Senior Notes are callable, at the Company's option, at par. No principal payments are required until maturity in February 2013. As of December 31, 2011, $200,000,000 was outstanding under the Senior Notes and the 2011 average interest rate was 0.8%, computed by dividing the interest expense under the Senior Notes by the average Senior Notes borrowings of $200,000,000. The Company was in compliance with all Senior Notes covenants at December 31, 2011.

The Company has a $10,000,000 line of credit ("Credit Line") with Bank of America, N.A. ("Bank of America") for short-term liquidity needs and letters of credit with a maturity date of June 30, 2012. 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 did not have any borrowings outstanding under the Credit Line as of December 31, 2011. Outstanding letters of credit under the Credit Line were $4,093,000 as of December 31, 2011.

The Company is of the opinion that the amounts included in the consolidated financial statements for outstanding debt materially represent the fair value of such debt at December 31, 2011 and 2010 due to their variable interest rates.

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Taxes On Income

12 Months Ended

Dec. 31, 2011

Taxes On Income [Abstract]

Taxes On Income

(7) Taxes on Income

Earnings before taxes on income and details of the provision for taxes on income for the years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	2011		2010		2009
Earnings before taxes on income — United States	$	294,747	$	189,640	$	205,558
Provision for taxes on income:
Federal:
Current	$	33,640	$	33,014	$	30,443
Deferred		65,451		30,643		38,404
State and local		10,164		8,601		9,173
	$	109,255	$	72,258	$	78,020

During the three years ended December 31, 2011, 2010 and 2009, tax benefits related to the exercise of stock options and the issuance of restricted stock that were allocated directly to additional paid-in capital were $1,348,000, $373,000 and $1,013,000, respectively.

The Company's provision for taxes on income varied from the statutory federal income tax rate for the years ended December 31, 2011, 2010 and 2009 due to the following:

	2011			2010			2009
United States income tax statutory rate		35.0	%		35.0	%		35.0	%
State and local taxes, net of federal benefit		2.2			2.9			2.9
Other – net		(.1	)		.2			.1
		37.1	%		38.1	%		38.0	%

The tax effects of temporary differences that give rise to significant portions of the current deferred tax assets and non-current deferred tax assets and liabilities at December 31, 2011 and 2010 were as follows (in thousands):

	2011			2010
Current deferred tax assets:
Compensated absences	$	695		$	518
Allowance for doubtful accounts		1,752			1,400
Insurance accruals		4,150			2,319
Other		7,589			2,181
	$	14,186		$	6,418
Non-current deferred tax assets and liabilities:
Deferred tax assets:
Postretirement health care benefits	$	3,422		$	3,548
Insurance accruals		1,420			876
Deferred compensation		8,290			7,456
Unrealized loss on derivative financial instruments		3,384			6,162
Unrealized loss on defined benefit plans		28,114			12,582
Operating loss carryforwards		1,305			1,023
Other		9,047			9,177
		54,982			40,824
Deferred tax liabilities:
Property		(298,335	)		(234,732	)
Deferred state taxes		(25,738	)		(22,571	)
Pension benefits		(15,376	)		(8,738	)
Goodwill and other intangibles		(6,563	)		(5,538	)
Other		(1,325	)		(1,020	)
		(347,337	)		(272,599	)
	$	(292,355	)	$	(231,775	)

The Company has determined that it is more likely than not that all deferred tax assets at December 31, 2011 will be realized, including its operating loss carryforwards of $1,305,000 that expire in various amounts through 2030.

The Company or one of its subsidiaries files income tax returns in the United States federal jurisdiction and various state jurisdictions. The Company is currently open to audit under the statute of limitations by the Internal Revenue Service for the 2008 through 2010 tax years. With few exceptions, the Company and its subsidiaries' state income tax returns are open to audit under the statute of limitations for the 2005 through 2010 tax years.

As of December 31, 2011, the Company has provided a liability of $2,509,000 for unrecognized tax benefits related to various income tax issues which includes interest and penalties. The amount that would impact the Company's effective tax rate, if recognized, is $1,775,000, with the difference between the total amount of unrecognized tax benefits and the amount that would impact the effective tax rate being primarily related to the federal tax benefit of state income tax items. It is not reasonably possible to determine if the liability for unrecognized tax benefits will significantly change prior to December 31, 2012 due to the uncertainty of possible examination results.

A reconciliation of the beginning and ending amount of the liability for unrecognized tax benefits for the years ended December 31, 2011, 2010 and 2009, is as follows (in thousands):

	2011			2010			2009
Balance at beginning of year	$	2,088		$	2,290		$	2,451
Additions based on tax positions related to the current year		602			279			417
Additions for tax positions of prior years		402			84			87
Reductions for tax positions of prior years		(738	)		(443	)		(665	)
Settlements		(822	)		(122	)		—
Balance at end of year	$	1,532		$	2,088		$	2,290

The Company accounts for interest and penalties related to uncertain tax positions as part of its provision for federal and state income taxes. The Company recognized net expense (income) of $16,000, $43,000 and $(221,000) in interest and penalties for the years ended December 31, 2011, 2010 and 2009, respectively. The Company had $977,000, $993,000 and $964,000 of accrued liabilities for the payment of interest and penalties at December 31, 2011, 2010 and 2009, respectively.

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Stock Award Plans

12 Months Ended

Dec. 31, 2011

Stock Award Plans [Abstract]

Stock Award Plans

(9) 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 years ended December 31, 2011, 2010 and 2009 were as follows (in thousands):

	2011		2010		2009
Compensation cost	$	9,228	$	10,867	$	9,855
Income tax benefit	$	3,534	$	4,162	$	3,775

The Company has two employee stock award plans for selected officers and other key employees which provide for the issuance of stock options and restricted stock. For both of the plans, 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 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. At December 31, 2011, 1,214,718 shares were available for future grants under the employee plans and no outstanding stock options under the employee plans were issued with stock appreciation rights.

The following is a summary of the stock option activity under the employee plans described above for the years ended December 31, 2011, 2010 and 2009:

	Outstanding Non-Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2008		514,181		$	35.28
Granted		228,246		$	23.98
Exercised		(101,944	)	$	21.86
Canceled or expired		—		$	—
Outstanding at December 31, 2009		640,483		$	33.39
Granted		103,999		$	32.60
Exercised		(228,543	)	$	28.36
Canceled or expired		(81,492	)	$	45.73
Outstanding at December 31, 2010		434,447		$	33.53
Granted		103,021		$	47.01
Exercised		(91,794	)	$	32.75
Canceled or expired		—		$	—
Outstanding at December 31, 2011		445,674		$	36.81

Under the employee plans, stock options exercisable were 226,900, 200,210 and 262,488 at December 31, 2011, 2010 and 2009, respectively.

The following table summarizes information about the Company's outstanding and exercisable stock options under the employee plans at December 31, 2011:

	Options Outstanding								Options Exercisable
Range of Exercise Prices	Number Outstanding		Weighted Average Remaining Contractual Life in Years		Weighted Average Exercise Price		Aggregated Intrinsic Value		Number Exercisable		Weighted Average Exercise Price		Aggregated Intrinsic Value
$23.98 — $32.56		226,450		3.4	$	27.72				113,364	$	26.47
$34.40 — $36.35		24,000		2.4	$	34.73				21,333	$	34.52
$46.74 — $58.28		195,224		3.7	$	47.61				92,203	$	48.28
$23.98 — $58.28		445,674		3.5	$	36.81	$	12,937,000		226,900	$	36.09	$	6,750,000

The following is a summary of the restricted stock award activity under the employee plans described above for the years ended December 31, 2011, 2010 and 2009:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2008		502,818		$	33.64
Granted		263,579		$	24.70
Vested		(207,106	)	$	36.60
Forfeited		(16,612	)	$	32.70
Nonvested balance at December 31, 2009		542,679		$	30.70
Granted		197,994		$	33.42
Vested		(234,831	)	$	39.34
Forfeited		(6,507	)	$	32.00
Nonvested balance at December 31, 2010		499,335		$	31.98
Granted		150,612		$	46.50
Vested		(163,480	)	$	33.27
Forfeited		(10,835	)	$	38.90
Nonvested balance at December 31, 2011		475,632		$	36.43

The Company has two director stock award plans for nonemployee directors of the Company which provide for the issuance of stock options and restricted stock. No additional options can be granted under one of the plans. The 2000 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 2000 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 plans 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 when first elected a director 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 December 31, 2011, 252,224 shares were available for future grants under the 2000 Director Plan. The director stock award plans are intended as an incentive to attract and retain qualified and competent independent directors.

The following is a summary of the stock option activity under the director plans described above for the years ended December 31, 2011, 2010 and 2009:

	Outstanding Non-Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2008		309,572		$	30.94
Granted		50,433		$	29.60
Exercised		(46,068	)	$	11.85
Forfeited		(12,000	)	$	35.99
Outstanding at December 31, 2009		301,937		$	33.43
Granted		57,492		$	41.24
Exercised		(3,000	)	$	10.67
Outstanding at December 31, 2010		356,429		$	34.88
Granted		60,552		$	56.42
Exercised		(63,356	)	$	32.17
Outstanding at December 31, 2011		353,625		$	39.05

Under the director plans, options exercisable were 352,987, 355,555 and 301,328 at December 31, 2011, 2010 and 2009, respectively.

The following table summarizes information about the Company's outstanding and exercisable stock options under the director plans at December 31, 2011:

	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
$12.69 — $17.88		45,814		1.4	$	15.78				45,814	$	15.78
$20.28 — $29.60		56,433		6.1	$	26.63				56,433	$	26.63
$35.17 — $36.82		86,036		4.7	$	35.88				86,036	$	35.88
$41.24 — $56.45		165,342		8.1	$	51.39				164,704	$	51.37
$12.69 — $56.45		353,625		6.1	$	39.05	$	9,473,000		352,987	$	39.02	$	9,467,000

The following is a summary of the restricted stock award activity under the director plan described above for the years ended December 31, 2011, 2010 and 2009:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2008		390		$	56.00
Granted		10,919		$	29.77
Vested		(10,577	)	$	30.74
Nonvested balance at December 31, 2009		732		$	29.77
Granted		11,097		$	41.33
Vested		(11,304	)	$	40.58
Nonvested balance at December 31, 2010		525		$	41.33
Granted		11,990		$	56.85
Vested		(10,767	)	$	55.90
Nonvested balance at December 31, 2011		1,748		$	58.07

The total intrinsic value of all stock options exercised under all of the Company's plans was $4,072,000, $2,835,000 and $1,859,000 for the years ended December 31, 2011, 2010 and 2009, respectively. The actual tax benefit realized for tax deductions from stock option exercises was $1,560,000, $1,086,000 and $712,000 for the years ended December 31, 2011, 2010 and 2009, respectively.

The total intrinsic value of all the restricted stock vestings under all of the Company's plans was $7,921,000, $8,809,000 and $5,931,000 for the years ended December 31, 2011, 2010 and 2009, respectively. The actual tax benefit realized for tax deductions from restricted stock vestings was $3,034,000, $3,374,000 and $2,271,000 for the years ended December 31, 2011, 2010 and 2009, respectively.

As of December 31, 2011, there was $1,695,000 of unrecognized compensation cost related to nonvested stock options and $12,038,000 related to restricted stock. The stock options are expected to be recognized over a weighted average period of approximately 1.4 years and restricted stock over approximately 2.7 years. The total fair value of stock options vested was $2,618,000, $3,491,000 and $2,763,000 during the years ended December 31, 2011, 2010 and 2009, respectively. The fair value of the restricted stock vested was $7,921,000, $8,809,000 and $5,931,000 for the years ended December 31, 2011, 2010 and 2009, respectively.

The weighted average per share fair value of stock options granted during the years ended December 31, 2011, 2010 and 2009 was $18.84, $13.81 and $8.15, respectively. The fair value of the stock options granted during the years ended December 31, 2011, 2010 and 2009 was $3,081,000, $2,231,000 and $2,271,000, 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 stock options during the years ended December 31, 2011, 2010 and 2009 were as follows:

	2011			2010			2009
Dividend yield		None			None			None
Average risk-free interest rate		2.4	%		3.1	%		1.9	%
Stock price volatility		33	%		33	%		33	%
Estimated option term		Six years or sevenyears			Six years or sevenyears			Four years or eightyears

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Stock Award Plans (Summary Of Restricted Stock Award Activity) (Details) (Stock Options [Member], USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Stock Options [Member]
Unvested Restricted Stock Award Shares
Beginning balance	499,335	542,679	502,818
Granted, Unvested Restricted Stock Award Shares	150,612	197,994	263,579
Vested, Unvested Restricted Stock Award Shares	(163,480)	(234,831)	(207,106)
Forfeited, Unvested Restricted Stock Award Shares	(10,835)	(6,507)	(16,612)
Ending balance	475,632	499,335	542,679
Weighted Average Grant Date Fair Value Per Share
Beginning balance	$ 31.98	$ 30.70	$ 33.64
Granted, Weighted Average Grant Date Fair Value Per Share	$ 46.50	$ 33.42	$ 24.70
Vested, Weighted Average Grant Date Fair Value Per Share	$ 33.27	$ 39.34	$ 36.60
Forfeited, Weighted Average Grant Date Fair Value Per Share	$ 38.90	$ 32.00	$ 32.70
Ending balance	$ 36.43	$ 31.98	$ 30.70

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Retirement Plans (Estimated Amounts That Will Be Amortized From Accumulated Other Comprehensive Income Into Net Periodic Benefit Cost) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Actuarial gain (loss)	$ 7,007
Estimated amounts to be amortized	7,007
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Actuarial gain (loss)	14
Estimated amounts to be amortized	14
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Actuarial gain (loss)	(616)
Prior service cost (credit)
Estimated amounts to be amortized	$ (616)

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Stock Award Plans (Summary Of Outstanding And Exercisable Stock Options Under Director Plans) (Details) (Director Plans [Member], USD $)	12 Months Ended
	Dec. 31, 2011 years
Total Exercise Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 12.69
Range of Exercise Prices, upper limit	$ 56.45
Options Outstanding
Number Outstanding	353,625
Weighted Average Remaining Contractual Life in Years, Options Outstanding	6.1
Weighted Average Exercise Price, Options Outstanding	$ 39.05
Aggregate Intrinsic Value, Options Outstanding	$ 9,473,000
Options Exercisable
Number Exercisable	352,987
Weighted Average Exercise Price, Options Exercisable	$ 39.02
Aggregate Intrinsic Value, Options Exercisable	$ 9,467,000
First Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 12.69
Range of Exercise Prices, upper limit	$ 17.88
Options Outstanding
Number Outstanding	45,814
Weighted Average Remaining Contractual Life in Years, Options Outstanding	1.4
Weighted Average Exercise Price, Options Outstanding	$ 15.78
Options Exercisable
Number Exercisable	45,814
Weighted Average Exercise Price, Options Exercisable	$ 15.78
Second Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 20.28
Range of Exercise Prices, upper limit	$ 29.60
Options Outstanding
Number Outstanding	56,433
Weighted Average Remaining Contractual Life in Years, Options Outstanding	6.1
Weighted Average Exercise Price, Options Outstanding	$ 26.63
Options Exercisable
Number Exercisable	56,433
Weighted Average Exercise Price, Options Exercisable	$ 26.63
Third Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 35.17
Range of Exercise Prices, upper limit	$ 36.82
Options Outstanding
Number Outstanding	86,036
Weighted Average Remaining Contractual Life in Years, Options Outstanding	4.7
Weighted Average Exercise Price, Options Outstanding	$ 35.88
Options Exercisable
Number Exercisable	86,036
Weighted Average Exercise Price, Options Exercisable	$ 35.88
Fourth Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 41.24
Range of Exercise Prices, upper limit	$ 56.45
Options Outstanding
Number Outstanding	165,342
Weighted Average Remaining Contractual Life in Years, Options Outstanding	8.1
Weighted Average Exercise Price, Options Outstanding	$ 51.39
Options Exercisable
Number Exercisable	164,704
Weighted Average Exercise Price, Options Exercisable	$ 51.37

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Stock Award Plans (Summary Of Outstanding And Exercisable Stock Options) (Details) (Employee Plan [Member], USD $)	12 Months Ended
	Dec. 31, 2011 years
Total Exercise Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 23.98
Range of Exercise Prices, upper limit	$ 58.28
Options Outstanding
Number Outstanding	445,674
Weighted Average Remaining Contractual Life in Years, Options Outstanding	3.5
Weighted Average Exercise Price, Options Outstanding	$ 36.81
Aggregate Intrinsic Value, Options Outstanding	$ 12,937,000
Options Exercisable
Number Exercisable	226,900
Weighted Average Exercise Price, Options Exercisable	$ 36.09
Aggregate Intrinsic Value, Options Exercisable	$ 6,750,000
First Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 23.98
Range of Exercise Prices, upper limit	$ 32.56
Options Outstanding
Number Outstanding	226,450
Weighted Average Remaining Contractual Life in Years, Options Outstanding	3.4
Weighted Average Exercise Price, Options Outstanding	$ 27.72
Options Exercisable
Number Exercisable	113,364
Weighted Average Exercise Price, Options Exercisable	$ 26.47
Second Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 34.40
Range of Exercise Prices, upper limit	$ 36.35
Options Outstanding
Number Outstanding	24,000
Weighted Average Remaining Contractual Life in Years, Options Outstanding	2.4
Weighted Average Exercise Price, Options Outstanding	$ 34.73
Options Exercisable
Number Exercisable	21,333
Weighted Average Exercise Price, Options Exercisable	$ 34.52
Third Price Range [Member]
Share-Based Compensation Arrangement By Share-Based Payment Award [Line Items]
Range of Exercise Prices, lower limit	$ 46.74
Range of Exercise Prices, upper limit	$ 58.28
Options Outstanding
Number Outstanding	195,224
Weighted Average Remaining Contractual Life in Years, Options Outstanding	3.7
Weighted Average Exercise Price, Options Outstanding	$ 47.61
Options Exercisable
Number Exercisable	92,203
Weighted Average Exercise Price, Options Exercisable	$ 48.28

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Segment Data (Other Total Assets) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Segment Reporting Information [Line Items]
Total assets	$ 2,960,411	$ 1,794,937	$ 1,635,963
General Corporate Assets [Member]
Segment Reporting Information [Line Items]
Total assets	40,022	222,525	110,980
Investment In Affiliates [Member]
Segment Reporting Information [Line Items]
Total assets	3,682	3,336	3,052
Other Total Assets [Member]
Segment Reporting Information [Line Items]
Total assets	$ 43,704	$ 225,861	$ 114,032

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Quarterly Results (Tables)

12 Months Ended

Dec. 31, 2011

Quarterly Results [Abstract]

Schedule Of Quarterly Results

	Three Months Ended
	March 31, 2011			June 30, 2011			September 30, 2011			December 31, 2011
Revenues	$	299,359		$	437,331		$	563,582		$	550,145
Costs and expenses		243,650			365,892			471,371			457,121
Gain (loss) on disposition of assets		(66	)		40			97			(111	)
Operating income		55,643			71,479			92,308			92,913
Other income (expense)		51			78			(6	)		183
Interest expense		(2,833	)		(3,278	)		(5,974	)		(5,817	)
Earnings before taxes on income		52,861			68,279			86,328			87,279
Provision for taxes on income		(19,961	)		(26,050	)		(32,734	)		(30,510	)
Net earnings		32,900			42,229			53,594			56,769
Less: Net earnings attributable to noncontrolling interests		(470	)		(537	)		(860	)		(599	)
Net earnings attributable to Kirby	$	32,430		$	41,692		$	52,734		$	56,170
Net earnings per share attributable to Kirby common stockholders:
Basic	$	.60		$	.78		$	.95		$	1.01
Diluted	$	.60		$	.77		$	.94		$	1.00

The unaudited quarterly results for the year ended December 31, 2010 were as follows (in thousands, except per share amounts):

	Three Months Ended
	March 31, 2010			June 30, 2010			September 30, 2010			December 31, 2010
Revenues	$	268,253		$	273,669		$	281,317		$	286,318
Costs and expenses		225,196			223,018			228,590			232,631
Gain (loss) on disposition of assets		(44	)		(19	)		8			(23	)
Operating income		43,013			50,632			52,735			53,664
Other income		12			30			131			383
Interest expense		(2,668	)		(2,697	)		(2,750	)		(2,845	)
Earnings before taxes on income		40,357			47,965			50,116			51,202
Provision for taxes on income		(15,446	)		(18,322	)		(19,211	)		(19,279	)
Net earnings		24,911			29,643			30,905			31,923
Less: Net earnings attributable to noncontrolling interests		(237	)		(375	)		(218	)		(303	)
Net earnings attributable to Kirby	$	24,674		$	29,268		$	30,687		$	31,620
Net earnings per share attributable to Kirby common stockholders:
Basic	$	.46		$	.54		$	.57		$	.59
Diluted	$	.46		$	.54		$	.57		$	.59

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Long-Term Debt (Schedule Of Aggregate Payments Due On The Long-Term Debt) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Long-Term Debt [Abstract]
2012	$ 39,005
2013	265,000
2014	91,000
2015	199,000
2016	208,000
Thereafter
Long-term Debt	$ 802,005	$ 200,134

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Segment Data

12 Months Ended

Dec. 31, 2011

Segment Data [Abstract]

Segment Data

(14) Segment Data

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

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

Diesel Engine Services — Overhaul and repair of medium-speed and high-speed diesel engines, reduction gear repair, and sale of related parts and accessories for customers in the marine and power generation applications, and distribution and service of high-speed diesel engines, transmissions, including the manufacture and remanufacture of hydraulic fracturing equipment for 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's accounting policies for the business segments are the same as those described in Note 1, Summary of Significant Accounting Policies. The Company evaluates the performance of its segments based on the contributions to operating income of the respective segments, and before income taxes, interest, gains or losses on disposition of assets, other nonoperating income, noncontrolling interests, accounting changes, and nonrecurring items. Intersegment sales for 2011, 2010 and 2009 were not significant.

The following table sets forth by reportable segment the revenues, profit or loss, total assets, depreciation and amortization, and capital expenditures attributable to the principal activities of the Company for the years ended December 31, 2011, 2010 and 2009 (in thousands):

	2011			2010			2009
Revenues:
Marine transportation	$	1,194,607		$	915,046		$	881,298
Diesel engine services		655,810			194,511			200,860
	$	1,850,417		$	1,109,557		$	1,082,158
Segment profit (loss):
Marine transportation	$	262,193		$	192,758		$	208,086
Diesel engine services		68,105			20,553			21,005
Other		(35,551	)		(23,671	)		(23,533	)
	$	294,747		$	189,640		$	205,558
Total assets:
Marine transportation	$	2,307,821		$	1,383,252		$	1,336,358
Diesel engine services		608,886			185,824			185,573
Other		43,704			225,861			114,032
	$	2,960,411		$	1,794,937		$	1,635,963
Depreciation and amortization:
Marine transportation	$	111,292		$	88,710		$	87,589
Diesel engine services		11,801			4,055			4,247
Other		2,936			2,531			2,132
	$	126,029		$	95,296		$	93,968
Capital expenditures:
Marine transportation	$	218,777		$	132,744		$	188,479
Diesel engine services		5,576			920			1,768
Other		1,885			3,177			2,413
	$	226,238		$	136,841		$	192,660

The following table presents the details of "Other" segment profit (loss) for the years ended December 31, 2011, 2010 and 2009 (in thousands):

	2011			2010			2009
General corporate expenses	$	(17,915	)	$	(13,189	)	$	(12,239	)
Impairment of goodwill		—			—			(1,901	)
Interest expense		(17,902	)		(10,960	)		(11,080	)
Gain (loss) on disposition of assets		(40	)		(78	)		1,079
Other income		306			556			608
	$	(35,551	)	$	(23,671	)	$	(23,533	)

The following table presents the details of "Other" total assets as of December 31, 2011, 2010 and 2009 (in thousands):

	2011		2010		2009
General corporate assets	$	40,022	$	222,525	$	110,980
Investment in affiliates		3,682		3,336		3,052
	$	43,704	$	225,861	$	114,032

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Fair Value Measurements (Tables)

12 Months Ended

Dec. 31, 2011

Fair Value Measurements [Abstract]

Assets And Liabilities Measured At Fair Value On A Recurring Basis

	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
December 31, 2011:
Assets:
Derivatives	$	—	$	—	$	—	$	—
Liabilities:
Derivatives	$	—	$	9,597	$	—	$	9,597
Contingent earnout liability		—		—		22,600		22,600
	$	—	$	9,597	$	22,600	$	32,197

	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
December 31, 2010:
Assets:
Derivatives	$	—	$	—	$	—	$	—
Liabilities:
Derivatives	$	—	$	17,576	$	—	$	17,576

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Long-Term Debt (Narrative) (Details) (USD $)	12 Months Ended		12 Months Ended			1 Months Ended	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2011 Senior Notes Due February 28, 2013 [Member]	Dec. 31, 2011 Line Of Credit [Member]	Sep. 30, 2011 Line Of Credit [Member]	May 31, 2011 Term Loan [Member] years	Dec. 31, 2011 Term Loan [Member]	Dec. 31, 2011 Revolving Credit Facility [Member]	Dec. 31, 2011 Revolving Credit Facility [Member] Line Of Credit [Member]	Dec. 31, 2011 Letter Of Credit [Member]
Debt Instrument [Line Items]
Credit facility				$ 10,000,000		$ 540,000,000	$ 540,000,000	$ 250,000,000
Term loan, duration						5
Interest rate terms	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.
Commitment fee percentage	0.30%
Credit facility, initiation date							July 1, 2011
Credit facility, expiration date				June 30, 2012			July 1, 2016	November 9, 2015
Credit facility, current borrowing capacity								325,000,000
Interest rate, variable rate basis	The unsecured Revolving Credit Facility has a variable interest rate based on LIBOR or an Alternate Base Rate. The variable interest rate spread varies with the Company's senior debt rating. The variable interest rate spread is currently 1.5% over LIBOR for LIBOR loans and 0.5% over the Alternate Base Rate for Alternate Base Rate loans.
Credit facility, amount outstanding					0		507,000,000	95,000,000	2,440,000	4,093,000
Current portion of long-term debt	39,005,000	128,000					39,000,000
Average borrowing under revolving credit facility	59,608,000
Weighted average interest rate	1.90%						1.80%
Commitment amount								25,000,000
Senior notes, face amount			$ 200,000,000
Senior notes, maturity date			February 28, 2013
Senior notes, interest rate	The Senior Notes pay interest quarterly at a rate equal to LIBOR plus a margin of 0.5%.
Interest rate during period	0.80%

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Acquisitions (Pro Forma Revenues, Basic And Diluted Net Earnings Per Share) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Acquisitions [Abstract]
Revenues	$ 2,105,904	$ 1,685,173	$ 1,554,806
Net earnings attributable to Kirby	$ 172,426	$ 123,981	$ 138,726
Basic	$ 3.10	$ 2.22	$ 2.49
Diluted	$ 3.09	$ 2.22	$ 2.49

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Consolidated Statements Of Stockholders' Equity And Comprehensive Income (USD $)	Common Stock [Member]	Additional Paid-In Capital [Member]	Accumulated Other Comprehensive Income [Member]	Retained Earnings [Member]	Treasury Stock [Member]	Noncontrolling Interests [Member]	Comprehensive Income [Member]	Total
Balance at beginning of year at Dec. 31, 2008	$ 5,734,000	$ 225,718,000	$ (55,047,000)	$ 804,425,000	$ (90,777,000)	$ 3,502,000
Excess (deficit) of proceeds received upon exercise of stock options and issuance of restricted stock over cost of treasury stock issued		(349,000)
Tax benefit realized from equity compensation plans		1,013,000						1,013,000
Issuance of restricted stock, net of forfeitures		(6,513,000)
Amortization of unearned compensation		9,855,000						9,855,000
Change in defined benefit plans' minimum liabilities, net of taxes ($16,994 in 2011, $1,028 in 2010 and $(12,962) in 2009)			20,903,000
Change in fair value of derivative financial instruments, net of taxes (($2,915) in 2011, $986 in 2010 and $(1,974) in 2009)			3,676,000
Net earnings attributable to Kirby for the year				125,941,000				125,941,000
Purchase of treasury stock (618,000 in 2010 and 20,000 shares in 2009)					(657,000)
Cost of treasury stock issued upon exercise of stock options and issuance of restricted stock (248,000 in 2011, 338,000 in 2010 and 368,000 in 2009)					8,541,000
Net earnings attributable to noncontrolling interests						1,597,000		1,597,000
Return of investment to noncontrolling interests						(1,782,000)		(1,782,000)
Proceeds from noncontrolling interest investments						315,000		315,000
Net earnings							127,538,000	127,538,000
Other comprehensive income (loss), net of taxes ($14,079 in 2011, $2,013 in 2010 and $(14,936) in 2009)							24,579,000
Total comprehensive income							152,117,000
Balance at end of year at Dec. 31, 2009	5,734,000	229,724,000	(30,468,000)	930,366,000	(82,893,000)	3,632,000
Excess (deficit) of proceeds received upon exercise of stock options and issuance of restricted stock over cost of treasury stock issued		3,140,000
Tax benefit realized from equity compensation plans		373,000						373,000
Issuance of restricted stock, net of forfeitures		(7,090,000)
Amortization of unearned compensation		10,867,000						10,867,000
Change in defined benefit plans' minimum liabilities, net of taxes ($16,994 in 2011, $1,028 in 2010 and $(12,962) in 2009)			(1,654,000)
Change in fair value of derivative financial instruments, net of taxes (($2,915) in 2011, $986 in 2010 and $(1,974) in 2009)			(1,520,000)
Net earnings attributable to Kirby for the year				116,249,000				116,249,000
Purchase of treasury stock (618,000 in 2010 and 20,000 shares in 2009)					(23,793,000)
Cost of treasury stock issued upon exercise of stock options and issuance of restricted stock (248,000 in 2011, 338,000 in 2010 and 368,000 in 2009)					7,064,000
Net earnings attributable to noncontrolling interests						1,133,000		1,133,000
Return of investment to noncontrolling interests						(1,794,000)		(1,794,000)
Proceeds from noncontrolling interest investments						69,000		69,000
Net earnings							117,382,000	117,382,000
Other comprehensive income (loss), net of taxes ($14,079 in 2011, $2,013 in 2010 and $(14,936) in 2009)							(3,174,000)
Total comprehensive income							114,208,000
Balance at end of year at Dec. 31, 2010	5,734,000	237,014,000	(33,642,000)	1,046,615,000	(99,622,000)	3,040,000		1,159,139,000
Excess (deficit) of proceeds received upon exercise of stock options and issuance of restricted stock over cost of treasury stock issued		4,359,000
Issuance of shares in acquisition	194,000	112,825,000
Tax benefit realized from equity compensation plans		1,348,000						1,348,000
Issuance of restricted stock, net of forfeitures		(7,480,000)
Amortization of unearned compensation		9,228,000						9,228,000
Change in defined benefit plans' minimum liabilities, net of taxes ($16,994 in 2011, $1,028 in 2010 and $(12,962) in 2009)			(27,383,000)
Change in fair value of derivative financial instruments, net of taxes (($2,915) in 2011, $986 in 2010 and $(1,974) in 2009)			5,199,000
Foreign currency translation loss			(350,000)
Net earnings attributable to Kirby for the year				183,026,000				183,026,000
Cost of treasury stock issued upon exercise of stock options and issuance of restricted stock (248,000 in 2011, 338,000 in 2010 and 368,000 in 2009)					5,460,000
Net earnings attributable to noncontrolling interests						2,466,000		2,466,000
Return of investment to noncontrolling interests						(2,115,000)		(2,115,000)
Proceeds from noncontrolling interest investments						268,000		268,000
Acquisition of noncontrolling interests						7,974,000
Net earnings							185,492,000	185,492,000
Other comprehensive income (loss), net of taxes ($14,079 in 2011, $2,013 in 2010 and $(14,936) in 2009)							(22,534,000)
Total comprehensive income							162,958,000
Balance at end of year at Dec. 31, 2011	$ 5,928,000	$ 357,294,000	$ (56,176,000)	$ 1,229,641,000	$ (94,162,000)	$ 11,633,000		$ 1,454,158,000

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Quarterly Results (Schedule Of Quarterly Results) (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended								12 Months Ended
	Dec. 31, 2011	Sep. 30, 2011	Jun. 30, 2011	Mar. 31, 2011	Dec. 31, 2010	Sep. 30, 2010	Jun. 30, 2010	Mar. 31, 2010	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Quarterly Results [Abstract]
Revenues	$ 550,145	$ 563,582	$ 437,331	$ 299,359	$ 286,318	$ 281,317	$ 273,669	$ 268,253	$ 1,850,417	$ 1,109,557	$ 1,082,158
Costs and expenses	457,121	471,371	365,892	243,650	232,631	228,590	223,018	225,196	1,538,074	909,513	866,128
Gain (loss) on disposition of assets	(111)	97	40	(66)	(23)	8	(19)	(44)	(40)	(78)	1,079
Operating income	92,913	92,308	71,479	55,643	53,664	52,735	50,632	43,013	312,343	200,044	216,030
Other income (expense)	183	(6)	78	51	383	131	30	12	(41)	273	(266)
Interest expense	(5,817)	(5,974)	(3,278)	(2,833)	(2,845)	(2,750)	(2,697)	(2,668)	(17,902)	(10,960)	(11,080)
Earnings before taxes on income	87,279	86,328	68,279	52,861	51,202	50,116	47,965	40,357	294,747	189,640	205,558
Provision for taxes on income	(30,510)	(32,734)	(26,050)	(19,961)	(19,279)	(19,211)	(18,322)	(15,446)	(109,255)	(72,258)	(78,020)
Net earnings	56,769	53,594	42,229	32,900	31,923	30,905	29,643	24,911	185,492	117,382	127,538
Less: Net earnings attributable to noncontrolling interests	(599)	(860)	(537)	(470)	(303)	(218)	(375)	(237)	(2,466)	(1,133)	(1,597)
Net earnings attributable to Kirby	$ 56,170	$ 52,734	$ 41,692	$ 32,430	$ 31,620	$ 30,687	$ 29,268	$ 24,674	$ 183,026	$ 116,249	$ 125,941
Basic	$ 1.01	$ 0.95	$ 0.78	$ 0.60	$ 0.59	$ 0.57	$ 0.54	$ 0.46	$ 3.35	$ 2.16	$ 2.34
Diluted	$ 1.00	$ 0.94	$ 0.77	$ 0.60	$ 0.59	$ 0.57	$ 0.54	$ 0.46	$ 3.33	$ 2.15	$ 2.34

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Inventories

12 Months Ended

Dec. 31, 2011

Inventories [Abstract]

Inventories

(3) Inventories

The following table presents the details of inventories as of December 31, 2011 and 2010 (in thousands):

	December 31, 2011		December 31, 2010
Finished goods	$	111,931	$	35,719
Work in process		18,199		3,102
	$	130,130	$	38,821

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Leases (Schedule Of Rent Expense) (Details) (USD $) In Thousands, unless otherwise specified	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Property Subject To Or Available for Operating Lease [Line Items]
Rental expense	$ 116,348	$ 93,425	$ 96,182
Other Buildings And Equipment [Member]
Property Subject To Or Available for Operating Lease [Line Items]
Rental expense	8,156	5,334	5,240
Tank Barges [Member] | Marine Equipment [Member]
Property Subject To Or Available for Operating Lease [Line Items]
Rental expense	16,396	9,075	9,489
Towing Vessels [Member] | Marine Equipment [Member]
Property Subject To Or Available for Operating Lease [Line Items]
Rental expense	$ 91,796	$ 79,016	$ 81,453

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Retirement Plans (Summary Of Expected Federal Subsidy) (Details) (USD $) In Thousands, unless otherwise specified	Dec. 31, 2011	Dec. 31, 2010
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Year one
Year two
Year three
Year four
Year five
Next five years
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Year one
Year two
Year three
Year four
Year five
Next five years
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Year one	(15)	(16)
Year two	(15)	(16)
Year three	(15)	(16)
Year four	(15)	(16)
Year five	(15)	(16)
Next five years	$ (67)	$ (74)

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Retirement Plans (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Retirement Plans [Abstract]
Fair value of plan assets	$ 174,223,000	$ 152,696,000
Expected long-term rate of return on plan assets	7.50%	7.50%
Pension plan defined benefit plan cost increase limit percentage	4.00%
Contribution percentage to defined contribution plan	97.00%
Pension contributions	27,500,000
Aggregate contributions to the plans	$ 13,793,000	$ 11,614,000	$ 13,682,000

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Derivative Instruments (Tables)

12 Months Ended

Dec. 31, 2011

Derivative Instruments [Abstract]

Interest Rate Risk Management

Notional Amount	Effective date	Termination date	Fixed pay rate			Receive rate
$100,000	March 2006	February 2013		5.45	%	Three-month LIBOR
$50,000	November 2008	February 2013		3.50	%	Three-month LIBOR
$50,000	May 2009	February 2013		3.795	%	Three-month LIBOR

Fair Value Of Derivative Instruments Liabilities

Liability Derivatives	Balance Sheet Location	2011		2010
Derivatives designated as hedging instruments under ASC 815:
Foreign currency contracts	Other accrued liabilities	$	363	$	798
Foreign currency contracts	Other long-term liabilities		32		569
Interest rate contracts	Other long-term liabilities		9,202		16,209
Total derivatives designated as hedging instruments under ASC 815		$	9,597	$	17,576
Total liability derivatives		$	9,597	$	17,576

Cash Flow Hedges

Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Recognized in OCI on Derivatives (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	7,007		$	(908	)	$	5,701
Foreign exchange contracts		Cost of sales and operating expenses		929			(1,419	)		(51	)
Total			$	7,936		$	(2,327	)	$	5,650
Derivatives in ASC 815 Cash Flow Hedging Relationships:	Location of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)		Amount of Gain (Loss) Reclassified from Accumulated OCI into Income (Effective Portion)
			2011			2010			2009
Interest rate contracts		Interest expense	$	(8,586	)	$	(8,529	)	$	(7,356	)
Foreign exchange contracts		Cost of sales and operating expenses		(13	)		(411	)		—
Total			$	(8,599	)	$	(8,940	)	$	(7,356	)

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Retirement Plans (Summary Of Change In Plan Assets) (Details) (USD $)	12 Months Ended
	Dec. 31, 2011	Dec. 31, 2010
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at end of year	$ 174,223,000	$ 152,696,000
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets at beginning of year	152,696,000	126,490,000
Actual return on plan assets	(1,499,000)	18,308,000
Employer contribution	27,500,000	11,900,000
Gross benefits paid	(4,474,000)	(4,002,000)
Fair value of plan assets at end of year	174,223,000	152,696,000
SERP [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contribution	103,000	103,000
Gross benefits paid	(103,000)	(103,000)
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Employer contribution	122,000	234,000
Gross benefits paid	$ (122,000)	$ (234,000)

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Acquisitions (Total Consideration Transferred For K-Sea Transportation Partners L.P) (Details) (K-Sea Transportation Partners L.P. [Member], USD $)	Jul. 31, 2011
K-Sea Transportation Partners L.P. [Member]
Business Acquisition [Line Items]
Cash consideration paid	$ 227,617,000
Cash to retire K-Sea's outstanding debt	262,791,000
Stock consideration through issuance of Company common stock	113,019,000
Fair value of consideration transferred	$ 603,427,000

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Contingencies And Commitments

12 Months Ended

Dec. 31, 2011

Contingencies And Commitments [Abstract]

Contingencies And Commitments

(13) Contingencies and Commitments

In June 2011, the Company as well as three other companies received correspondence from United States Environmental Protection Agency ("EPA") concerning ongoing cleanup and restoration activities under the Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA") with respect to a Superfund site, the Gulfco Marine Maintenance Site ("Gulfco"), located in Freeport, Texas. In prior years, various subsidiaries of the Company utilized a successor to Gulfco to perform tank barge cleaning services, sand blasting and repair on certain Company vessels. The EPA continues to investigate activities at the site to assess additional Potentially Responsible Parties ("PRPs"). Since 2005, four named PRPs have participated in the investigation, cleanup and restoration of the site under an administrative order from EPA. Information received to date indicates that approximately $3,500,000 has been incurred in connection with the cleanup effort in addition to EPA's oversight costs of approximately $1,800,000. To date, neither the EPA nor the named PRPs have performed an allocation of potential liability in connection with the site nor have they provided requested cost and expenses supporting documentation related to the site. The Company is investigating its activities at the site in order to assess what, if any, liability it has in connection with the site.

In 2009, the Company was named a PRP in addition to a group of approximately 250 named PRPs under CERCLA with respect to a Superfund site, the Portland Harbor Superfund site ("Portland Harbor") in Portland, Oregon. The site was declared a Superfund site in December 2000 as a result of historical heavily industrialized use due to manufacturing, shipbuilding, petroleum storage and distribution, metals salvaging, and electrical power generation activities which led to contamination of Portland Harbor, an urban and industrial reach of the lower Willamette River located immediately downstream of downtown Portland. The Company's involvement arises from four spills at the site after it was declared a Superfund site, as a result of predecessor entities' actions in the area. To date, there is no information suggesting the extent of the costs or damages to be claimed from the 250 noticed PRPs. Based on the nature of the involvement at the Portland Harbor site, the Company believes its potential contribution is de minimis; however, to date neither the EPA nor the named PRPs have performed an allocation of potential liability in connection with the site nor have they provided costs and expenses in connection with the site.

In 2000, the Company and a group of approximately 45 other companies were notified that they are PRPs under the CERCLA with respect to a Superfund site, the Palmer Barge Line Superfund Site ("Palmer"), located in Port Arthur, Texas. In prior years, Palmer had provided tank barge cleaning services to various subsidiaries of the Company. The Company and three other PRPs entered into an agreement with the EPA to perform a remedial investigation and feasibility study and, subsequently, a limited remediation was performed and is now complete. During the 2007 third quarter, five new PRPs entered into an agreement with the EPA related to the Palmer site. In July 2008, the EPA sent a letter to approximately 30 PRPs for the Palmer site, including the Company, indicating that it intends to pursue recovery of $2,949,000 of costs it incurred in relation to the site. The Company and the other PRPs continue to discuss suggested pro rata allocations of costs to all PRPs with the EPA and the U.S. Department of Justice ("DOJ") in order to resolve the EPA's past costs claim.

In 2000, the Company and approximately 50 other companies were notified that they are PRPs under the CERCLA with respect to a Superfund site, the State Marine of Port Arthur Superfund Site ("State Marine"), located in Port Arthur, Texas. In the past, State Marine performed tank barge cleaning and services for various subsidiaries of the Company. In March 2010, the DOJ and EPA issued a letter to seven PRPs, which include the former owners/operator of the site and others, including the Company, indicating their intent to pursue reimbursement of its past costs of approximately $2,977,000 in connection with clean-up activities in relation to the site. The Company and the other PRPs will continue to pursue documentation concerning the site activities related to all PRPs in order to determine appropriate allocation of past costs relative to activities at the site to develop suggested pro rata sharing to resolve the EPA's past cost claim.

With respect to the above sites, the Company has recorded reserves, if applicable, for its estimated potential liability for its portion of the EPA's past costs claim based on information developed to date including various factors such as the Company's liability in proportion to other responsible parties and the extent to which such costs are recoverable from third parties.

On July 25, 2011, a subsidiary of the Company was named as a defendant in the U.S. District Court for the Southern District of Texas - Galveston Division, in a complaint styled Figgs. v. Kirby Inland Marine, et al., which alleges that the plaintiff individually as a vessel tankerman, and on behalf of other current and former similarly situated vessel tankerman employed with the Company, is entitled to overtime pay under the Fair Labor Standards Act. Plaintiffs assert that vessel tankerman are not seaman who are expressly exempt from overtime pay provisions under the law. The case was conditionally certified as a collective action on December 22, 2011 at which time the Court prescribed a notice period for current and former employees to voluntarily participate as a plaintiff. The notice period closes on February 27, 2012 after which time discovery will be conducted with respect to the merits of the case. Plaintiff seeks to maintain a collective action, compensatory damages in the form of back pay, attorneys fees, cost and liquidated damages. As discovery as to the merits of the case has not been conducted to date, the Company is unable to assess the liability at this time. Accordingly, the Company is not able to estimate any amount of loss or range of loss.

On January 30, 2012 in the U.S. District Court for the District of New Jersey and styled Rescue Mission of El Paso., Inc., et al. v. John J. Nicola, et al., the Company, its subsidiary, 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 conditions, 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 seeks class certification, compensatory damages, attorneys fees and costs. The Company believes that this suit is without merit and intends to vigorously defend itself in this matter based on the information available to the Company at this time. The Company does not expect the outcome of this matter to have a material adverse effect on its consolidated financial statements; however, there can be no assurance as to the ultimate outcome of this matter.

In addition, 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.

Certain Significant Risks and Uncertainties. The preparation of financial statements in conformity with United States generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. However, in the opinion of management, the amounts would be immaterial.

The customer base of the marine transportation segment includes the major industrial petrochemical and chemical manufacturers, agricultural chemical manufacturers and refining companies operating in the United States. During 2011, approximately 75% of marine transportation's inland revenues were from movements of such products under term contracts, ranging from one year to five years, with renewal options. During the second half of 2011, approximately 60% of the marine transportation's coastal revenues were under term contracts. While the manufacturing and refining companies have generally been customers of the Company for numerous years (some as long as 40 years) and management anticipates a continuing relationship, there is no assurance that any individual contract will be renewed. No single customer of the marine transportation segment accounted for more than 10% of the Company's revenues in 2011. The Dow Chemical Company accounted for 12% of the Company's revenues in 2010 and 11% in 2009. SeaRiver Maritime, Inc., the United States transportation affiliate of Exxon Mobil Corporation, accounted for 11% of the Company's revenues in 2010 and 10% in 2009.

Major customers of the diesel engine services segment include inland and offshore barge operators, oilfield service companies, oil and gas operators and producers, compression companies offshore fishing companies, marine and on-highway transportation companies, the USCG and United States Navy, and power generation, nuclear and industrial companies. The segment operates as an authorized distributor in 17 eastern states and the Caribbean, and as non-exclusive authorized service centers for Electro-Motive Diesel, Inc. ("EMD") throughout the rest of the United States for marine and power generation applications. The diesel engine services segment's relationship with EMD has been maintained for 46 years. The segment also operates factory-authorized full service marine dealerships for Cummins, Detroit Diesel and John Deere high-speed diesel engines and Allison transmissions and gears in the Gulf Coast region, as well as an authorized marine dealer for Caterpillar in Alabama, Kentucky and Louisiana.

United has maintained continuous exclusive distribution rights for MTU and Allison since 1946. United is one of MTU's top five distributors of MTU off-highway engines in North America with exclusive distribution rights in Oklahoma, Arkansas, Louisiana and Mississippi. In addition, as a distributor of Allison transmission products, United has distribution rights in Oklahoma, Arkansas and Louisiana. Finally, United is also the exclusive distributor for Daimler engines and related equipment, in Oklahoma, Arkansas and Louisiana.

The results of the diesel engine services segment are largely tied to the industries it serves and, therefore, can be influenced by the cycles of such industries. No single customer of the diesel engine services segment accounted for more than 10% of the Company's revenues in 2011, 2010 and 2009.

Weather can be a major factor in the day-to-day operations of the marine transportation segment. Adverse weather conditions, such as high or low water, tropical storms, hurricanes, tsunamis, fog and ice, can impair the operating efficiencies of the marine fleet. Shipments of products can be delayed or postponed by weather conditions, which are totally beyond the control of the Company. Adverse water conditions are also factors which impair the efficiency of the fleet and can result in delays, diversions and limitations on night passages, and dictate horsepower requirements and size of tows. Additionally, much of the inland waterway system is controlled by a series of locks and dams designed to provide flood control, maintain pool levels of water in certain areas of the country and facilitate navigation on the inland river system. Maintenance and operation of the navigable inland waterway infrastructure is a government function handled by the Army Corps of Engineers with costs shared by industry. Significant changes in governmental policies or appropriations with respect to maintenance and operation of the infrastructure could adversely affect the Company.

The Company's marine transportation segment is subject to regulation by the USCG, federal laws, state laws and certain international conventions, as well as numerous environmental regulations. The Company believes that additional safety, environmental and occupational health regulations may be imposed on the marine industry. There can be no assurance that any such new regulations or requirements, or any discharge of pollutants by the Company, will not have an adverse effect on the Company.

The Company's marine transportation segment competes principally in markets subject to the Jones Act, a federal cabotage law that restricts domestic marine transportation in the United States to vessels built and registered in the United States, and manned and owned by United States citizens. The Jones Act cabotage provisions occasionally come under attack by interests seeking to facilitate foreign flag competition in trades reserved for domestic companies and vessels under the Jones Act. The Company believes that continued efforts will be made to modify or eliminate the cabotage provisions of the Jones Act. If such efforts are successful, certain elements could have an adverse effect on the Company.

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 is $26,329,000 at December 31, 2011, including $9,260,000 in letters of credit and debt guarantees, and $17,069,000 in performance bonds. All of these instruments have an expiration date within three 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.