KIRBY CORP - Annual Report: 2017 (Form 10-K)

---

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

---

 

Form 10-K

(Mark One)

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

For the fiscal year ended December 31, 2017

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 ☒ 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 ☒

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 ☒ 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 ☒ 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	☒	Accelerated filer	☐
Non-accelerated filer	☐ (Do not check if a smaller reporting company)	Smaller reporting company	☐
		Emerging growth company	☐

 

---

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

 

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

The aggregate market value of common stock held by nonaffiliates of the registrant as of June 30, 2017, based on the closing sales price of such stock on the New York Stock Exchange on June 30, 2017, was $3,511,931,000. 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 23, 2018, 59,674,000 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, 2018, to be filed with the Commission pursuant to Regulation 14A, is incorporated by reference into Part III of this report.

KIRBY CORPORATION

2017 FORM 10-K

TABLE OF CONTENTS

	Page
PART I
Item 1. Business	4
THE COMPANY	4
Documents and Information Available on Web Site	4
BUSINESS AND PROPERTY	5
MARINE TRANSPORTATION	6
Marine Transportation Industry Fundamentals	7
Inland Tank Barge Industry	7
Coastal Tank Barge Industry	9
Competition in the Tank Barge Industry	9
Products Transported	10
Demand Drivers in the Tank Barge Industry	10
Marine Transportation Operations	12
Contracts and Customers	15
Employees	15
Properties	15
Governmental Regulations	16
Environmental Regulations	17
DISTRIBUTION AND SERVICES	19
Oil and Gas Operations	20
Oil and Gas Customers	20
Oil and Gas Competitive Conditions	21
Commercial and Industrial Operations	21
Commercial and Industrial Customers	22
Commercial and Industrial Competitive Conditions	23
Employees	23
Properties	23
Executive Officers of the Registrant	24
Item 1A. Risk Factors	26
Item 1B. Unresolved Staff Comments	33
Item 2. Properties	33
Item 3. Legal Proceedings	33
Item 4. Mine Safety Disclosures	35
PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	36
Item 6. Selected Financial Data	37
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations	37
Item 7A. Quantitative and Qualitative Disclosures about Market Risk	65
Item 8. Financial Statements and Supplementary Data	65
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	65
Item 9A. Controls and Procedures	65
PART III
Items 10 Through 14	66
PART IV
Item 15. Exhibits and Financial Statement Schedules	104

PART I

Item 1.

Business

THE COMPANY

Kirby Corporation (the “Company”) is the nation’s largest domestic tank barge operator, transporting bulk liquid products throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise along all three United States coasts, and in Alaska and Hawaii. The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge. The Company also operates five offshore dry-bulk barges, five offshore tugboats and one docking tugboat transporting dry-bulk commodities in the United States coastal trade. Through its distribution and services segment, the Company provides after-market service and parts for engines, transmissions, reduction gears, and related equipment used in oilfield services, marine, mining, power generation, on-highway and other industrial applications. The Company also rents equipment including generators, fork lifts, pumps and compressors for use in a variety of industrial markets, and manufactures and remanufactures oilfield service equipment, including pressure pumping units, for the oilfield service and oil and gas operator and producer 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.

BUSINESS AND PROPERTY

The Company, through its subsidiaries, conducts operations in two business segments: marine transportation and distribution and 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, coastwise along all three United States coasts, and in Alaska and Hawaii. The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge. The Company operates offshore dry-bulk barge and tugboat units engaged in the offshore transportation of dry-bulk cargoes in the United States coastal trade. 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 operate under the United States flag and are qualified for domestic trade under the Jones Act.

The Company, through its distribution and services segment, sells genuine replacement parts, provides service mechanics to overhaul and repair engines, transmissions, reduction gears and related oilfield services equipment, rebuilds component parts or entire diesel engines, transmissions and reduction gears, and related equipment used in oilfield services, marine, mining, power generation, on-highway and other industrial applications. The Company also rents equipment including generators, fork lifts, pumps and compressors for use in a variety of industrial markets, and manufactures and remanufactures oilfield service equipment, including pressure pumping units, for the oilfield service and oil and gas operator and producer markets.

The Company and its marine transportation and distribution and services segments have approximately 5,775 employees, the large majority 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):

		2017				2016				2015
Revenues from unaffiliated customers:
Marine transportation		$	1,324,106			$	1,471,893			$	1,663,090
Distribution and services			890,312				298,780				484,442
Consolidated revenues		$	2,214,418			$	1,770,673			$	2,147,532
Operating profits:
Marine transportation		$	136,011			$	257,102			$	374,842
Distribution and services			86,585				3,186				18,921
General corporate expenses			(18,150	)			(14,966	)			(14,773	)
Impairment of long-lived assets			(105,712	)			—				—
Gain (loss) on disposition of assets			(4,487	)			(127	)			1,672
			94,247				245,195				380,662
Equity in earnings of affiliates			291				532				451
Other expense			(52	)			(291	)			(663	)
Interest expense			(21,472	)			(17,690	)			(18,738	)
Earnings before taxes on income		$	73,014			$	227,746			$	361,712
Identifiable assets:
Marine transportation		$	3,485,099			$	3,613,951			$	3,444,785
Distribution and services			1,567,085				623,268				632,764
			5,052,184				4,237,219				4,077,549
Investment in affiliates			1,890				2,622				2,090
General corporate assets			73,353				50,054				60,919
Consolidated assets		$	5,127,427			$	4,289,895			$	4,140,558

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 23, 2018, the equipment owned or operated by the marine transportation segment consisted of 998 inland tank barges with 22.0 million barrels of capacity, 302 inland towboats, 56 coastal tank barges with 5.4 million barrels of capacity, 53 coastal tugboats, five offshore dry-bulk cargo barges, five offshore tugboats and one docking tugboat, and includes 157 inland tank barges and 75 inland towboats added with the acquisition of Higman Marine, Inc. and affiliated companies (“Higman”) on February 14, 2018, with the following specifications and capacities:

Class of equipment		Number in class				Average age (in years)				Barrel capacities
Inland tank barges (owned and leased):
Regular double hull:
20,000 barrels and under			348				12.6				4,001,000
Over 20,000 barrels			593				11.2				17,085,000
Specialty double hull			57				39.5				888,000
Total inland tank barges			998				13.3				21,974,000
Inland towboats (owned and chartered):
800 to 1300 horsepower			64				39.3
1400 to 1900 horsepower			70				32.2
2000 to 2400 horsepower			134				10.3
2500 to 3200 horsepower			16				33.7
3300 to 4800 horsepower			14				30.8
Greater than 5000 horsepower			3				42.0
Spot charters (chartered trip to trip)			1			─
Total inland towboats			302				24.2
Coastal tank barges (owned and leased):
Double hull:
30,000 barrels and under			3				19.2				65,000
50,000 to 70,000 barrels			11				14.6				560,000
80,000 to 90,000 barrels			20				13.2				1,663,000
100,000 to 110,000 barrels			6				11.5				630,000
120,000 to 150,000 barrels			7				21.9				898,000
Over 150,000 barrels			9				14.3				1,554,000
Total coastal tank barges			56				14.7				5,370,000
Coastal tugboats (owned and chartered):
1000 to 1900 horsepower			4				29.5
2000 to 2900 horsepower			2				38.6
3000 to 3900 horsepower			10				36.8
4000 to 4900 horsepower			14				20.3
5000 to 6900 horsepower			13				17.8
Greater than 7000 horsepower			10				13.3
Total coastal tugboats			53				22.9
										Deadweight Tonnage
Offshore dry-bulk cargo barges (owned)			5				23.1				96,000
Offshore tugboats and docking tugboat (owned and chartered)			6				28.6

The 302 inland towboats, 53 coastal tugboats, five offshore tugboats and one docking tugboat provide the power source and the 998 inland tank barges, 56 coastal tank barges and five offshore dry-bulk 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-bulk 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 waterway system consists 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 regional 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 petroleum products principally from coastal tank barges. Smaller volumes of petrochemicals are distributed from Gulf Coast plants to end users and black oil, including crude oil and natural gas condensate, is distributed regionally from refineries and terminals along the United States coast to refineries, power plants and distribution terminals.

Based on cost and safety, barge transportation is often the most efficient and safest means of surface transportation of bulk commodities when compared with railroads and trucks. The cargo capacity of a 27,500 barrel inland tank barge is the equivalent of 46 railroad tank cars or 144 tractor-trailer tank trucks. A typical Company lower Mississippi River linehaul tow of 15 barges has the carrying capacity of approximately 216 railroad tank cars plus six locomotives, or approximately 1,050 tractor-trailer tank trucks. The Company’s inland tank barge fleet capacity of 22.0 million barrels equates to approximately 36,800 railroad tank cars or approximately 115,000 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 478 miles by railcar 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 5.4 million barrels equates to approximately 8,900 railroad tank cars or approximately 28,200 tractor-trailer tank trucks. 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 approximately 40 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 transportation of bulk liquid cargoes for customers and, in the case of captives, for their own account, throughout the Mississippi River and its tributaries and on the Gulf Intracoastal Waterway. The most significant markets in this industry include the transportation of petrochemicals, black oil, 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, and then increased over the years to approximately 3,850 by the end of 2016 and an estimated 3,825 at the end of 2017. 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 approximately 3,850 by the end of 2016 primarily resulted from increased barge construction and deferred retirements due to strong demand and resulting capacity shortages.  The decrease to 3,825 during 2017 was primarily due to industry overcapacity in the inland tank barge market, the result of reduced crude oil and natural gas condensate volumes to be moved by tank barge due to a decline in oil prices, a decline in domestic drilling and additional pipeline capacity, coupled with the large number of tank barges built during the last several years, many of which were for the movement of crude oil and natural gas condensate. The Company’s 998 inland tank barges represent approximately 26% of the industry’s 3,825 inland tank barges.

For 2015, the Company estimated that industry-wide 260 tank barges were placed in service and 60 tank barges were retired. For 2016, the Company estimated that industry-wide 100 tank barges were placed in service and 100 tank barges were retired.  For 2017, the Company estimated that industry-wide 75 tank barges were placed in service and 100 tank barges were retired.  During 2015, 2016 and 2017, the decline in industry-wide demand for the movement of crude oil and natural gas condensate, and the subsequent transfer of inland crude oil barges to other tank barge markets, created excess industry-wide tank barge capacity. As a result, the Company estimates that approximately 30 tank barges were ordered during 2017 for delivery throughout 2018 and many older tank barges will be retired, dependent on 2018 market conditions. The risk of a continued oversupply of tank barges may be mitigated by increased petrochemical, black oil and refined petroleum products volumes from increased production from current facilities, plant expansions or the opening of new facilities, and the fact that the inland tank barge industry has a mature fleet, with approximately 500 tank barges over 30 years old and approximately 250 of those over 40 years old, which may lead to retirement of older tank barges.

The average age of the nation’s inland tank barge fleet is approximately 16 years. Neither the Company, nor the industry, operates any single hull inland tank barges. Single hull tank barges were required by current federal law to either be retrofitted with double hulls or phased out of domestic service by December 31, 2014.

The Company’s inland marine transportation segment also owns a shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel and in Freeport, Texas, and a shipyard for the building of inland towboats and providing routine maintenance on marine vessels.  The Company also owns a two-thirds interest in Osprey Line, L.L.C. (“Osprey”), a 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, operating tank barges in the 195,000 barrel or less category. This market is composed of approximately 15 large integrated transportation companies and small operators. The 195,000 barrel or less category coastal tank barge industry primarily provides regional marine transportation distribution 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 from refineries and storage facilities to a variety of destinations, including other refineries, distribution terminals, power plants and ships, the regional movement of crude oil and natural gas condensate to Gulf Coast, Northeast and West Coast refineries, and the movement of petrochemicals primarily from Gulf Coast petrochemical facilities to end users.

The number of coastal tank barges that operate in the 195,000 barrel or less category is approximately 290, of which the Company operates 56 or approximately 19%. The average age of the nation’s coastal tank barge fleet is approximately 13 years.  In the 2015 fourth quarter, the Company placed in service a new 185,000 barrel coastal articulated tank barge and tugboat unit (“ATB”) and a second 185,000 barrel ATB was placed in service in the 2016 second quarter.  During the 2016 fourth quarter, the Company placed in service a new 155,000 barrel ATB and a second 155,000 barrel ATB was placed in service in the 2017 third quarter.  The Company also took delivery in December 2016 of a 35,000 barrel coastal petrochemical tank barge.  The Company is aware of seven coastal ATBs under construction by competitors for delivery in 2018 and 2019.  The coastal tank barge fleet is also mature, with approximately 20 tank barges over 30 years old.  The number of older tank barges, coupled with low industry-wide utilization levels, may lead to the retirement of older 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, most of the industry’s customers, through an increased emphasis on safety, the environment, quality and a trend toward a “single source” supply of services, 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 998 tank barges as of February 23, 2018, 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 tank barges in the 195,000 barrels or less category. Coastal tank barges in the 195,000 barrels or less category have the ability to enter the large majority of coastal ports. Ocean-going tank barges and United States product tankers in the 300,000 barrels plus category, excluding the fleet of large tankers dedicated to Alaska crude oil transportation, primarily move large volumes of refined petroleum products within the Gulf of Mexico with occasional movements from the Gulf Coast to the East Coast, along the West Coast and from Texas and Louisiana to Florida. There are approximately 50 such vessels and, because of their size, their access to ports is limited by terminal size and draft restrictions.

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 and tractor-trailer tank trucks. As noted above, the Company believes that both inland and coastal marine transportation of bulk liquid products enjoy a substantial cost advantage over railroad and truck transportation. The Company believes that refined product and crude oil 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.

Products Transported

The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise along all three United States coasts and in Alaska and Hawaii. During 2017, the Company’s inland marine transportation operation moved over 42 million tons of liquid cargo on the United States inland waterway system.

Petrochemicals. Bulk liquid petrochemicals transported include such products as benzene, styrene, methanol, acrylonitrile, xylene, naphtha and caustic soda, all consumed in the production of paper, fiber 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 56% of the segment’s 2017 revenues. Customers shipping these products are petrochemical and refining companies.

Black Oil. Black oil transported includes such products as residual fuel oil, No. 6 fuel oil, coker feedstock, vacuum gas oil, asphalt, carbon black feedstock, crude oil, natural gas condensate and ship bunkers (engine fuel). Such products represented 23% of the segment’s 2017 revenues. Black oil customers are refining companies, marketers and end users that require the transportation of black oil between refineries and storage terminals, to refineries and to power plants. Ship bunker 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, heating oil and diesel fuel, and represented 17% of the segment’s 2017 revenues. The Company also classifies ethanol in the refined petroleum products category. Customers are oil and refining companies, marketers and ethanol producers.

Agricultural Chemicals. Agricultural chemicals transported represented 4% of the segment’s 2017 revenues. Agricultural chemicals 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.

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, 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 among the petrochemical, refined petroleum products and crude oil markets as needed.

 

The demand for black oil, 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 the majority of 2015, inland black oil tank barge utilization remained strong, in the 90% to 95% range, due to strong demand driven by steady refinery production levels from major customers, and the export of diesel fuel and heavy fuel oil. With the decline in the price of crude oil in late 2014 and the low price throughout 2015 and 2016, movements by tank barge of crude oil and natural gas condensate were at reduced levels industry-wide. During 2015 and 2016, the Company and the industry were generally successful in moving barges from that trade to other markets. During 2016 and 2017, the Company continued to transport crude oil and natural gas condensate produced from the Eagle Ford and Permian Basin shale formations in Texas both along the Gulf Intracoastal Waterway with inland vessels and in the Gulf of Mexico with coastal equipment, and continued to transport Utica crude oil and natural gas condensate downriver from the Mid-Atlantic to the Gulf Coast, however, at reduced levels as certain of the product was transported by newly constructed pipelines. The decline in demand for crude oil and natural gas condensate movements and an industry-wide oversupply of inland tank barges resulted in a decline in inland black oil tank barge utilization in 2016 to the low-to-mid 80% range and in 2017 to the mid-80% to low 90% range for the first three quarters and low to mid-90% range for the fourth quarter. Coastal black oil tank barge utilization declined from the 90% to 95% range for the majority of 2015 to the low 80% range by the end of 2016, and the low 60% to low 80% range during 2017, partly attributable to the decrease in the movements of crude oil and natural gas condensate and to the continued industry-wide oversupply of tank barges in the coastal industry. Inland and coastal asphalt shipments are generally seasonal, with higher volumes shipped during April through November, months when weather allows for efficient road construction. The Company saw seasonally normal cessation of most operations in Alaska in the 2016 and 2017 first and fourth quarters.

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. Volumes were also driven by diesel fuel transported to terminals along the Gulf Coast for export to South America. Ethanol, produced in the Midwest, is moved from the Midwest to Gulf Coast customers. In the coastal trade, tank barges are frequently used regionally 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. Coastal refined petroleum products tank barge utilization declined from the 90% to 95% range for the majority of 2015 to the low-to-mid 80% range for the majority of 2016, and declined throughout 2017 from a low 80% range in first quarter to the low 60% range in the fourth quarter, all predominately from the industry-wide oversupply of coastal tank barge capacity.

Marine Transportation Operations

The marine transportation segment operates a fleet of 998 inland tank barges and 302 inland towboats, as well as 56 coastal tank barges and 53 coastal tugboats. The segment also operates five offshore dry-bulk cargo barges, five offshore tugboats and one docking tugboat transporting dry-bulk commodities in United States coastal trade.

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, 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. Black oil is 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 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, 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 and agricultural chemicals is generally more seasonal. Movements of black oil, 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 998 inland tank barges currently operated, 783 are petrochemical and refined petroleum products barges, 139 are black oil barges, 61 are pressure barges, 10 are refrigerated anhydrous ammonia barges and five are specialty barges. Of the 998 inland tank barges, 967 are owned by the Company and 31 are leased.

The fleet of 302 inland towboats ranges from 800 to 5200 horsepower. Of the 302 inland towboats, 229 are owned by the Company and 73 are chartered. Towboats in the 800 to 2100 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 3200 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, typically 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 the first nine months of 2016 and all of 2015, approximately 80% of the inland marine transportation revenues were under term contracts and 20% were spot contract revenues. During the 2016 fourth quarter and all of 2017, approximately 75% of inland marine transportation revenues were under term contracts and 25% were spot contract revenues.

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 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 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, Freeport and Orange, Texas, Baton Rouge, Covington and New Orleans, Louisiana, Mobile, Alabama and Greenville, Mississippi. Included in the fleeting service is a shifting operation and fleeting service for dry cargo barges and tank barges on the Houston Ship Channel and in Freeport, Texas. 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 Inland Marine also provides shore-based barge tankermen to the Company and third parties. Services to the Company and third parties cover the Gulf Coast, mid-Mississippi Valley, and the Ohio River Valley.

San Jac Marine, Inc. (“San Jac”), a subsidiary of Kirby Inland Marine, owns and operates a shipyard in Channelview, Texas used to build marine vessels for both inland and coastal applications, and provide maintenance and repair services.  Kirby Inland Marine is building inland towboats and performing routine maintenance and repairs at the shipyard.

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, Kirby Offshore Marine, LLC (“Kirby Offshore Marine”) and Kirby Ocean Transport Company (“Kirby Ocean Transport”).

Kirby Offshore Marine provides marine transportation of refined petroleum products, petrochemicals and black oil in coastal regions of the United States. The coastal operations consist of the Atlantic and Pacific 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, in the Eastern Canadian provinces. The tank barges operating in the Atlantic Division are in the 10,000 to 194,000 barrel capacity range and coastal tugboats in the 2400 to 10000 horsepower range, transporting primarily refined petroleum products, petrochemicals and black oil.

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 52,000 to 194,000 barrel capacity range and tugboats in the 1000 to 11000 horsepower range, transporting primarily refined petroleum products.

The Pacific Division also services local petroleum retailers and oil companies distributing refined petroleum products and black oil between the Hawaiian Islands and provides other services to the local maritime community. The Hawaii fleet consists of tank barges in the 53,000 to 86,000 barrel capacity range and tugboats in the 1000 to 5000 horsepower range, transporting refined petroleum products for local and regional customers, black oil to power generation customers and delivering bunker fuel to ships. The Hawaii fleet 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 is impacted by seasonality, partially dependent on the area of operations. Operations along the West Coast and in Alaska 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 56 tank barges with 5.4 million barrels of capacity, primarily transporting refined petroleum products, black oil and petrochemicals. The Company owns 49 of the coastal tank barges and seven are leased. Of the 56 coastal tank barges currently operating, 37 are refined petroleum products and petrochemical barges and 19 are black oil barges. The Company operates 53 coastal tugboats ranging from 1000 to 11000 horsepower, of which 48 are owned by the Company and five are chartered.

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 2015 second half, 2016 and 2017, approximately 80% of the coastal marine transportation revenues were under term contracts and 20% were spot contract revenues.  For the 2015 first half, approximately 85% of coastal marine transportation revenues were under term contract and 15% were spot contract revenues.

Kirby Offshore Marine also operates a fleet of two offshore dry-bulk barge and tugboat units involved in the transportation of sugar and other dry products between Florida and East Coast ports. These vessels primarily operate under contracts of affreightment that are typically one year or less in length.

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

Kirby Ocean Transport is also engaged in the transportation of coal, fertilizer, sugar 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.

Contracts and Customers

Marine transportation inland and coastal services are conducted under term contracts, typically 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 many 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 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 49% of the marine transportation’s inland revenues under term contracts during 2017, 52% of revenue under term contracts during 2016 and 55% of the revenue under term contracts during 2015. 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 more predictable revenue stream while maintaining spot market exposure to take advantage of new business opportunities and existing customers’ peak demands. During the first nine months of 2016 and all of 2015, approximately 80% of the inland marine transportation revenues were under term contracts and 20% were spot contract revenues. During the 2016 fourth quarter and all of 2017, approximately 75% of inland marine transportation revenues were under term contracts and 25% were spot contract revenues. Coastal time charters represented approximately 85% of the marine transportation coastal revenues under term contracts in 2017 and 2016, as compared to 90% in 2015.

No single customer of the marine transportation segment accounted for 10% of the Company’s revenues in 2017, 2016 and 2015.

Employees

The Company’s marine transportation segment has approximately 3,225 employees, of which approximately 2,500 are vessel crew members. None of the segment’s inland operations are subject to collective bargaining agreements. The segment’s coastal operations include approximately 750 vessel employees some of which are subject to collective bargaining agreements in certain geographic areas. Approximately 300 Kirby Offshore Marine vessel crew members employed in the Atlantic Division are subject to a collective bargaining agreement with the Richmond Terrace Bargaining Unit that expired on December 31, 2016. This collective bargaining agreement was extended to August 31, 2018 and is currently subject to ongoing negotiations. In addition, approximately 120 Penn Maritime, Inc. vessel crew members are represented by the Seafarers International Union under a collective bargaining agreement in effect through April 2018.

 

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, federal regulations have been finalized that lay out new compliance options as well as new equipment, construction and operational requirements for towing vessels subjecting inland and coastal towing vessels to USCG inspection requirements. These regulations became effective July 20, 2016 and provide for the phase-in of certain requirements over time. Existing towing vessels have until July 20, 2018 to meet most of the requirements of the regulations, with additional timing for other portions of the regulations.

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 could 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 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 user tax of 29.1 cents per gallon consisting of a .1 cent per gallon leaking underground storage tank tax and 29 cents per gallon waterways user tax. The waterways user tax rate increased from 20 to 29 cents per gallon of fuel effective April 1, 2015.

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.

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 and international jurisdictions to the extent that the Company’s vessels transit in international waters. Government regulations require the Company to obtain permits, licenses and certificates for the operation of its vessels. Failure to maintain necessary permits or approvals could require the Company to incur costs or temporarily suspend operation of one or more of its vessels.

Water Pollution Regulations. The Federal Water Pollution Control Act of 1972, as amended by the Clean Water Act of 1977 (“Clean Water Act”), 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 was 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 either 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. 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.

Clean Water Act. The United States Environmental Protection Agency (“EPA”) regulates the discharge of ballast water and other substances in United States waters under the Clean Water Act. Effective February 6, 2009, EPA regulations required vessels 79 feet in length or longer to comply with a Vessel General Permit authorizing ballast water discharges and other discharges incidental to the operation of the vessels. The EPA regulations also imposed technology and water quality based effluent limits for certain types of discharges and established specific inspection, monitoring, recordkeeping and reporting requirements for vessels to ensure effluent limitations are met. The Vessel General Permit is effective from December 19, 2013 to December 18, 2018. The Company maintains Vessel General Permits and has established recordkeeping and reporting procedures in compliance with these obligations.

 

The USCG adopted regulations on ballast water management treatment systems establishing a standard for the allowable concentration of living organisms in certain vessel ballast water discharged in waters of the United States under the National Invasive Species Act. The regulations include requirements for the installation of engineering equipment to treat ballast water by establishing an approval process for ballast water management systems (“BWMS”). The BWMS implementation was suspended until December 2016 at which time the USCG approved manufacturers’ systems that met the regulatory discharge standard equivalent to the International Maritime Organization’s D-2 standard. The phase-in schedule for those existing vessels requiring a system to install ballast water treatment management systems is dependent on vessel build date, ballast water capacity, and drydock schedule. Compliance with the ballast water treatment regulations requires the installation of equipment on some of the Company’s vessels to treat ballast water before it is discharged. The installation of BWMS equipment will require capital expenditures at the next scheduled drydocking for statutory purposes of those existing vessels requiring a system in order to complete the installation of the approved system.

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 petroleum 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 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 $3.8 billion in hull values. Liabilities such as collision, cargo, environmental, personal injury and general liability are insured up to $1.3 billion per occurrence. The Company also maintains insurance coverage to address commercial liabilities arising in connection with its distribution and services segment.

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. Another is the participation by the Company in the American Waterways Operators Responsible Carrier program which is oriented towards continuously reducing the barge industry’s 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.

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 2017, approximately 1,100 certificates were issued for the completion of courses at the training facility, of which approximately 550 were USCG approved classes and the balance were employee development and Company required classes, including Leadership and Defensive Driving.

Quality. Kirby Inland Marine has made a substantial commitment to the implementation, maintenance and improvement of Quality Assurance Systems in compliance with the International Quality Standard, ISO 9001. Kirby Offshore Marine is certified under ABS ISM standards. These Quality Assurance Systems and certification have enabled both shore and vessel personnel to effectively manage the changes which occur in the working environment, as well as enhancing the Company’s safety and environmental performance.

DISTRIBUTION AND SERVICES

The Company, through its wholly owned subsidiary Kirby Distribution & Services, Inc. and its wholly owned subsidiaries Kirby Engine Systems LLC, (“Kirby Engine Systems”), Stewart & Stevenson LLC (“S&S”) and United Holdings LLC (“United”), and through Kirby Engine Systems’ wholly owned subsidiaries Marine Systems, Inc. (“Marine Systems”) and Engine Systems, Inc. (“Engine Systems”), serves two markets, oil and gas, and commercial and industrial.  The Company sells genuine replacement parts, provides service mechanics to overhaul and repair engines, transmissions, reduction gears and related oilfield service equipment, rebuilds component parts or entire diesel engines, transmissions and reduction gears, and related equipment used in oilfield services, marine, mining, power generation, on-highway, and other commercial and industrial applications. The Company manufactures and remanufactures oilfield service equipment, including pressure pumping units, for North American as well international oilfield service companies, and oil and gas operator and producer markets.  The Company also sells engines, transmissions, power generation systems, and rents equipment including generators, fork lifts, pumps, air compressors and railcar movers for use in a variety of commercial and industrial markets.

For the oil and gas market, the Company sells Original Equipment Manufacturers (OEM) replacement parts, sells and services diesel engines, pumps and transmissions, and manufactures and remanufactures pressure pumping units, and manufactures cementing and pumping equipment, coil tubing and well intervention equipment, and gas compression equipment.  Customers include oilfield service companies, and oil and gas operators and producers.

For the commercial and industrial market, the Company sells OEM replacement parts and new diesel engines, provides service mechanics and maintains facilities to overhaul and repair diesel engines and ancillary products for marine and on-highway transportation companies, mining and industrial companies.  The Company provides engineering and field services, OEM replacement parts and safety-related products to power generation operators and to the nuclear industry, manufactures engine generator and pump packages for power generation operators and municipalities, offers power generation systems customized for specific commercial and industrial applications, and rents equipment including power generation systems, pumps, air compressors, fork lifts and railcar movers.

No single customer of the distribution and services segment accounted for 10% of the Company’s revenues in 2017, 2016 or 2015. The distribution and services segment also provides service to the Company’s marine transportation segment, which accounted for approximately 2% of the distribution and services segment’s 2017 revenues, 8% of 2016 revenues and 5% of 2015 revenues. Such revenues are eliminated in consolidation and not included in the table below.

The following table sets forth the revenues for the distribution and services segment for the three years ended December 31, 2017 (dollars in thousands):

		2017								2016								2015
		Amounts				%				Amounts				%				Amounts				%
Overhauls and service		$	383,241				43	%		$	181,035				61	%		$	251,447				52	%
Direct parts sales			304,607				34				114,568				38				138,183				28
Manufacturing			202,464				23				3,177				1				94,812				20
		$	890,312				100	%		$	298,780				100	%		$	484,442				100	%

Oil and Gas Operations

The Company is engaged in the distribution and service of high-speed diesel engines, pumps and transmissions, and the manufacture and remanufacture of oilfield service equipment. The oil and gas operations represented 69% of the segment’s 2017 revenues. The Company offers custom fabricated oilfield service equipment, fully tested and field ready. The Company manufactures and remanufactures oilfield service equipment, including pressure pumping units, nitrogen pumping units, cementers, hydration equipment, mud pumps and blenders, coil tubing, well intervention equipment and gas compression equipment.  The Company sells OEM replacement parts, and sells and services diesel engines, pumps and transmissions, and offers in-house and in-field service capabilities.  The Company is the largest off-highway distributor for Allison Transmission and a major distributor for MTU in North America.

The Company’s manufacturing and remanufacturing facilities and service facilities are based in Houston, Texas, and Edmund and Oklahoma City, Oklahoma, key oil and gas producing regions.

Oil and Gas Customers

The Company’s major oil and gas customers include large and mid-cap oilfield service providers, oil and gas operators and producers. The Company has long standing relationships with most of its customers.  Since the oil and gas business is linked to the oilfield services industry, and 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 Company’s oil and gas distribution and services operations are largely tied to the industries it serves and, therefore, are influenced by the cycles of such industries.

Oil and Gas Competitive Conditions

The Company’s primary competitors are other oilfield equipment manufacturers and remanufacturers, and equipment service 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.

Commercial and Industrial Operations

The Company serves the marine, on-highway, mining, power generation, and other commercial and industrial markets primarily in the United States.  The commercial and industrial operations represented 31% of the segment’s 2017 revenues.

The Company is engaged in the overhaul and repair of medium-speed and high-speed marine diesel engines and reduction gears, line boring, block welding services and related parts sales for customers in the marine industry. 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 1000 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, harbor docking vessels, commercial ferries, vessels owned by the United States government and large pleasure crafts.

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 and Harvey, Louisiana, Houston, Texas, Chesapeake, Virginia, Paducah, Kentucky, Seattle, Washington and Tampa, Florida, serving as the authorized distributor for EMD Power Products (“EMD”) throughout the United States. The Company is also a distributor and representative for certain Alfa Laval products in the Midwest and on the East Coast, Gulf Coast, and West Coast. 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, and the United States government. The Houma and Harvey, Louisiana and Houston, Texas operations concentrate 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, the offshore barge industry, the United States government, and other customers in Alaska, Hawaii and the Pacific Rim.

The high-speed marine operations are located in Houston, Texas, Houma, Baton Rouge, Belle Chasse and New Iberia, Louisiana, Paducah, Kentucky, Mobile, Alabama, Lodi and Thorofare, New Jersey, and 10 locations in Florida. The Company serves as a factory-authorized marine dealer for Caterpillar diesel engines in multiple states. The Company also operates factory-authorized full service marine distributorships/dealerships for Cummins, Detroit Diesel, John Deere, MTU and Volvo Penta diesel engines, as well as Falk, Lufkin and Twin Disc marine gears. High-speed diesel engines provide the main propulsion for a significant amount of the United States flag commercial vessels and large pleasure craft vessels, other marine applications, including engines for power generators and barge pumps.

The Company distributes, sells parts for and services diesel engines and transmissions for on-highway use and provides in-house and in-field service capabilities. The Company is the largest on-highway distributor for Allison Transmission and Detroit Diesel/Daimler Truck North America, providing parts, service and warranty on engines, transmissions and related equipment in Arkansas, Colorado, Florida, Louisiana, New Mexico, New York, Oklahoma, Texas, Wyoming, and the country of Colombia.  The Company also provides similar service for off-highway use and additionally has distributor rights for Deutz and Isuzu diesel engines.  Off-highway applications are primarily surface and underground mining equipment, including loaders, crawlers, crushers, power screens, pumps, cranes, generators, haul trucks and personnel carriers, as well as the rental of equipment.

The Company is engaged in the overhaul and repair of diesel engines and generators, and related parts sales for power generation customers. The Company is also engaged in the sale and distribution of diesel engine parts, engine modifications, generator modifications, controls, governors and diesel generator packages to the nuclear industry. The Company services users of diesel engines that provide emergency standby, peak and base load power generation.  The Company also sells power generation systems that are customized for specific applications and the rental of power generation systems.

The Company has power generation operations throughout the United States providing in-house and in-field repair capabilities and products for power generation applications. Through its Rocky Mount, North Carolina operation, the Company serves as the exclusive worldwide distributor of EMD products to the nuclear industry, the worldwide distributor for Woodward, Inc. products to the nuclear industry, the worldwide distributor of  Baker Hughes, a GE Company (“Baker Hughes”) 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 an exclusive distributor for Norlake Manufacturing Company transformer products to the nuclear industry, an exclusive distributor of Hannon Company generator and motor 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 Company is a non-exclusive distributor of Ingersoll Rand air start equipment to the nuclear industry worldwide.

The Company sells pre-packaged and fabricated power generation systems for emergency, standby and auxiliary power for commercial and industrial applications.  The Company also offers rental generator systems from MTU, Atlas Copco, and Multiquip from 50 to 2000 kilowatts of power to a broad range of customers.  The Company also is engaged in the rental of power generator systems, fork lifts, pumps, air compressors and railcar movers.  In addition, the Company provides accessory products such as cables, hoses, fuel cells, air dryers, air compressor boosters and ground heaters.  Lastly, the Company is a dealer for Thermo King refrigeration systems for trucks, railroad cars and other land transportation markets in south and central Texas.

Commercial and Industrial Customers

The Company’s major marine customers include inland and offshore barge operators, oil service companies, offshore fishing companies, other marine transportation entities, the United States government and large pleasure crafts.  Since the marine business is linked to the relative health of the inland towboat, offshore and coastal tugboat, harbor docking tugboat, offshore oil service, oil and gas drilling, offshore commercial fishing industries, Great Lakes ore vessels, dredging vessels, coastal ferries, United States government vessels and the pleasure craft industry, there is no assurance that its present gross revenues can be maintained in the future. The results of the distribution and services industry are largely tied to the industries it serves and, therefore, are influenced by the cycles of such industries.

The Company’s on-highway customers are long-haul and short-haul trucking companies, commercial and industrial companies with truck fleets, buses owned by municipalities and private companies. Off-highway companies include surface and underground mining operations with a large variety of equipment.

The Company’s power generation customers are domestic utilities and the worldwide nuclear power industry, municipalities, universities, medical facilities, data centers, petrochemical plants, manufacturing facilities, shopping malls, office complexes, residential and other industrial users.

The Company’s rental customers are primarily commercial and industrial companies, and residential customers with short-term rental requirements.

Commercial and Industrial Competitive Conditions

The Company’s primary marine competitors are independent distribution and 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 service agreements with certain 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.

The Company is one of a limited number of authorized resellers of EMD, Caterpillar, Cummins, Detroit Diesel, John Deere, MTU and Volvo Penta parts. The Company is also the marine distributor for Falk, Lufkin and Twin Disc reduction gears throughout the United States.

The Company’s primary power generation 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.

As noted above, the Company is the exclusive worldwide distributor of EMD, Baker Hughes, Woodward, Nordberg, Norlake and Hannon parts for the nuclear industry, and non-exclusive distributor of Weschler parts and Ingersoll Rand air start equipment for the nuclear industry. Specific regulations relating to equipment used in nuclear power generation require extensive testing and certification of replacement parts. OEM parts need to be properly tested and certified for nuclear applications.

Employees

The Company’s distribution and services segment has approximately 2,450 employees. None of the United Holdings and Kirby Engine Systems operations are subject to collective bargaining agreements.  Approximately 60 S&S employees in New Jersey are subject to a collective bargaining agreement with the Local 15C, International Union of Operating Engineers, AFL-CIO that expires in October 2023.  The remaining S&S employees are not subject to collective bargaining agreements.

Properties

The principal office of the distribution and services segment is located in Houston, Texas.  There are 69 active facilities in the distribution and services segment, with 30 of these facilities owned and 39 are leased facilities.

The oil and gas operation’s principal manufacturing facilities are located in Houston, Texas, and Edmund and Oklahoma City, Oklahoma, with all three facilities owned by the Company.  The oil and gas focused operations have 22 parts and service facilities, with two in Arkansas, two in Colorado, five in Louisiana, one in New Mexico, 11 in Texas and one in Wyoming, with many of these facilities shared with the commercial and industrial operations.

The commercial and industrial businesses operate 44 parts and service facilities, with one facility in Alabama, one in Arizona, one in Connecticut, 11 in Florida, two in Kansas, one in Kentucky, two in Louisiana, one in Massachusetts, one in Oklahoma, four in New Jersey, one in New York, one in North Carolina, 10 in Texas, one in Virginia, one in Washington and five facilities located in Colombia, South America.

Executive Officers of the Registrant

The executive officers of the Company are as follows:

Name		Age		Positions and Offices
Joseph H. Pyne		70		Chairman of the Board
David W. Grzebinski		56		President, Chief Executive Officer and Chief Financial Officer
William G. Harvey (1)		60		Executive Vice President – Finance
Christian G. O’Neil		45		President – Kirby Inland Marine and Kirby Offshore Marine
Joseph H. Reniers		43		President – Kirby Distribution & Services, Inc.
Dorman L. Strahan		61		President – Kirby Engine Systems
Kim B. Clarke		62		Vice President and Chief Human Resources Officer
Ronald A. Dragg		54		Vice President, Controller and Assistant Secretary
Eric S. Holcomb		43		Vice President – Investor Relations
Amy D. Husted		49		Vice President and General Counsel
David R. Mosley		53		Vice President and Chief Information Officer
William M. Woodruff		57		Vice President – Public and Governmental Affairs
Renato A. Castro		46		Treasurer

(1) On January 31, 2018, the Company announced the employment of William G. Harvey as Executive Vice President – Finance.  Mr. Harvey will assume the role of Chief Financial Officer of the Company after the filing of the Company’s 2017 Form 10-K.

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 since April 2014. He served the Company as Chairman of the Board and Chief Executive Officer from January 2014 to April 2014, as Chairman of the Board, President and Chief Executive Officer from April 2013 to January 2014 and 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.

David W. Grzebinski is a Chartered Financial Analyst and holds a Master of Business Administration degree from Tulane University and a degree in chemical engineering from the University of South Florida. He has served as President and Chief Executive Officer since April 2014. He served as President and Chief Operating Officer from January 2014 to April 2014 and as Chief Financial Officer from March 2010 to April 2014. He served as Chairman of Kirby Offshore Marine from February 2012 to April 2013 and served as Executive Vice President from March 2010 to January 2014. Prior to joining the Company in February 2010, he served in various administrative positions since 1988 with FMC Technologies Inc. (“FMC”), including Controller, Energy Services, Treasurer, and Director of Global SAP and Industry Relations. Prior to joining FMC, he was employed by Dow Chemical Company.

William G. Harvey is a Chartered Financial Analysts and holds a Master of Business Administration degree from the University of Toronto and a degree in mechanical engineering from Queens University.  He has served as Executive Vice President – Finance since February 2018.  Prior to joining the Company, Mr. Harvey served as Executive Vice President and Chief Financial Officer of Walter Energy, Inc. from 2012 to 2017, Senior Vice President and Chief Financial Officer of Resolute Forest Products Inc. (“Resolute”) from 2008 to 2011, and as Executive Vice President and Chief Financial Officer of Bowater Inc., a predecessor company of Resolute, from 2004 to 2008.

Christian G. O’Neil holds a Master of Business Administration degree from Rice University, a doctorate of jurisprudence from Tulane University and a bachelor of arts degree from Southern Methodist University. He has served as President of Kirby Inland Marine and Kirby Offshore Marine since January 2018.  He served as Executive Vice President and Chief Operating Officer of Kirby Inland Marine and Kirby Offshore Marine from May 2016 to January 2018. He also served as Executive Vice President – Commercial Operations of Kirby Inland Marine and Kirby Offshore Marine from April 2014 to May 2016, Vice President – Human Resources of the Company from May 2012 to April 2014, Vice President – Sales for Kirby Inland Marine from 2009 to 2012 and President of Osprey from 2006 through 2008. He has also served in various sales and business development roles at the Company and Osprey. Prior to joining the Company, he served as Sales Manager and Fleet Manager at Hollywood Marine, Inc. (“Hollywood Marine”) after joining Hollywood Marine in 1997.

Joseph H. Reniers holds a degree in mechanical engineering from the United States Naval Academy and a Master of Business Administration degree from the University of Chicago Booth School of Business. He has served the Company as President – Kirby Distribution & Services, Inc. since September 2017.  He served as Executive Vice President – Diesel Engine Services and Supply Chain from May 2016 to September 2017, Senior Vice President – Diesel Engine Services and Marine Facility Operations from February 2015 to May 2016, Vice President – Strategy and Operational Service from April 2014 to February 2015, Vice President – Supply Chain from April 2012 to April 2014 and Vice President – Human Resources from March 2010 to April 2012. 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.

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.

Kim B. Clarke holds a Bachelor of Science degree from the University of Houston. She has served as Vice President and Chief Human Resources Officer since October 2017.  She served as Vice President – Human Resources from December 2016 to April 2017. Prior to joining the Company, she served in senior leadership roles in human resources, safety, information technology and business development as Senior Vice President and Chief Administration Officer for Key Energy Services, Inc. from 2004 to March 2016.

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.

Eric S. Holcomb is a Certified Public Accountant and holds a B.B.A. degree in accounting from Southern Methodist University.  He has served the Company as Vice President – Investor Relations since December 2017.  Prior to joining the Company, he was employed by Baker Hughes Incorporated from 2003 to December 2017 serving in various roles including Investor Relations Director, Finance Director for North America Land, Finance Director for North America Offshore and Finance Director for Canada.

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 has Vice President and General Counsel since January 2017. She served as Vice President – Legal from January 2008 to January 2017 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.

William M. Woodruff holds a doctorate of jurisprudence from the University of Houston Law Center and a bachelor of science degree from Texas A&M University.  He was elected Vice President – Public and Governmental Affairs in October 2017.  He served as Director – Public & Government Affairs from 2014 to October 2017 after joining the Company as Director – Government Affairs in 2004.  Prior to joining the Company, he was a maritime lawyer in private practice and Vice President and General Counsel of Coastal Towing, Inc.

Renato A. Castro is a Certified Public Accountant and holds a Master of 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.

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 29 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 and distribution and services segments. 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. The Company’s distribution and services segment is subject to tropical storms and hurricanes impacting its coastal locations and tornadoes impacting its Oklahoma facilities.

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 surface transportation of 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, refined petroleum products and agricultural chemicals throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise 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. Lifestyle issues are a deterrent for employment for inland and coastal crew members. Inland 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 ongoing retirements and competitive labor pressure in the marine transportation segment, the Company continues to monitor and implement market competitive pay practices. The Company also utilizes an internal development program to train Maritime Academy graduates for vessel leadership positions.

The Company’s marine transportation segment has approximately 3,225 employees, of which approximately 2,500 are vessel crew members. None of the segment’s inland operations are subject to collective bargaining agreements. The segment’s coastal operations include approximately 750 vessel employees, of whom approximately 420 are subject to collective bargaining agreements in certain geographic areas. Any work stoppages or labor disputes could adversely affect coastal operations in those areas.

The Company may be unable to make attractive acquisitions or successfully integrate acquired businesses, and any inability to do so may adversely affect the Company’s business and hinder its ability to grow. The Company has made asset and business acquisitions in the past and may continue to make acquisitions of assets or businesses in the future that complement or expand the Company’s current business. The Company may not be able to identify attractive acquisition opportunities. Even if attractive acquisition opportunities are identified, the Company may not be able to complete the acquisition or do so on commercially acceptable terms. The success of any completed acquisition depends on the Company’s ability to integrate the acquired assets or business effectively into the Company’s existing operations. The process of integrating acquired assets or businesses may involve difficulties that require a disproportionate amount of the Company’s managerial and financial resources to resolve. The value of acquired assets or businesses may be negatively impacted by a variety of circumstances unknown to the Company prior to the acquisition. In addition, possible future acquisitions may be larger and for purchase prices significantly higher than those paid for earlier acquisitions. No assurance can be given that the Company will be able to identify additional suitable acquisition opportunities, negotiate acceptable terms, obtain financing for acquisitions on acceptable terms or successfully acquire identified targets. The Company’s failure to achieve consolidation savings, to integrate successfully the acquired businesses and assets into the Company’s existing operations, or to minimize any unforeseen operational difficulties could have a material adverse effect on the Company’s business, financial condition, and results of operations. In addition, agreements governing the Company’s indebtedness from time to time may impose certain limitations on the Company’s ability to undertake acquisitions or make investments or may limit the Company’s ability to incur certain indebtedness and liens, which could limit the Company’s ability to make acquisitions.

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 could 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 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 or international trade agreements or laws were to be modified 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 believes 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 the Secretary may prescribe whenever the Secretary deems that such action is necessary in the interest of national defense. On September 8, 2017, following Hurricanes Harvey and Irma, the Department of Homeland Security issued a waiver of the Jones Act for a 7-day period for shipments from New York, Pennsylvania, Texas and Louisiana to South Carolina, Georgia, Florida and Puerto Rico.  The waiver was specifically tailored to address the transportation of refined petroleum products due to disruptions in hurricane-affected areas.  On September 11, 2017, the waiver was extended for 11 days and expanded to include additional states.  Following Hurricane Maria, on September 28, 2017, the Department of Homeland Security issued a waiver of the Jones Act for movement of products shipped from United States coastwise points to Puerto Rico through October 18, 2017. Waivers 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 and capital expenditures 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 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 2017, 56% of the marine transportation segment’s revenues were from the movement of petrochemicals, including the movement of raw materials and feedstocks from one refinery or petrochemical plant to another, as well as the movement of more finished products to end users and terminals for export. During 2017, petrochemical volumes were relatively stable compared with 2016 and 2015. The United States petrochemical industry continues to benefit from a low-cost domestically produced natural gas feedstock advantage, producing strong volumes of raw materials and intermediate products for transportation between Gulf Coast petrochemical plants and the transportation of more finished products to terminals for both domestic consumers and for export destinations. In addition, approximately 30 new United States petrochemical projects, including expansion of existing plants or new plants, are scheduled to be completed during 2018 and 2019 which should provide additional movements for the marine transportation segment.  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.

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 3,825 inland tank barges in the United States, of which the Company operates 998, or 26%. The number of tank barges peaked at an estimated 4,200 in 1982, slowly declined to 2,750 by 2003, and then gradually increased to an estimated 3,850 by the end of 2015 and 2016. At the end of 2017 the Company estimates there are approximately 3,825 inland tank barges.  The Company estimates that industry-wide approximately 260 tank barges were placed in service during 2015, of which 36 were for the Company, and 60 tank barges were retired, 18 of which were by the Company. The Company estimates that industry-wide approximately 100 tank barges were placed in service during 2016, of which five were by the Company, and 100 tank barges were retired, 50 of which were by the Company.  The Company estimates that industry-wide 75 tank barges were placed in service during 2017, of which five were by the Company, and 100 tank barges were retired, 54 of which were by the Company.  The increase for 2015 reflected the improved demand for inland petrochemical, refined petroleum products and black oil barges experienced in 2014 and federal tax incentives on new equipment. The decrease in the number of tank barges at the end of 2016 and 2017 reflected the industry-wide oversupply of tank barges.  The Company estimates that approximately 30 tank barges were ordered during 2017 for delivery throughout 2018, one of which is for the Company, and many older tank barges, including an expected 25 by the Company, will be retired, dependent on 2018 market conditions.

The long-term 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 3,825 tank barges in the industry at the present time, approximately 500 are over 30 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 tank barges as needed, with the extent of both retirements and new builds dependent on petrochemical and refinery production levels and crude oil and natural gas condensate movements, both of which can have a direct effect on industry-wide tank barge utilization, as well as term and spot contract rates.

During the majority of 2015, the coastal operations reflected improvements in market conditions with tank barge utilization in the 90% to 95% range, occasionally declining to the high-80% level during portions of the 2015 fourth quarter. During the majority of 2015, the Company experienced increased demand for coastal crude oil and natural gas condensate moves and success in expanding the coastal customer base to include inland customers with coastal requirements. During the 2015 fourth quarter continuing throughout 2016 and 2017, a decline in crude oil and natural gas condensate transportation volumes increased available capacity and resulted in some reluctance among certain customers to extend term contracts, which led to an increase in the number of coastal vessels operating in the spot market. In addition, the Company and the industry added new coastal tank barge capacity during 2015, 2016 and 2017, with additional new capacity coming on-line in 2018 and 2019. Much of this new capacity is replacement capacity for older vessels anticipated to be retired.

The Company estimates there are approximately 290 tank barges operating in the 195,000 barrel or less coastal industry fleet, the sector of the market in which the Company operates, and approximately 20 of those are over 30 years old.  The Company took delivery of a new 185,000 barrel ATB in late 2015 and a second 185,000 barrel ATB in June 2016.  The Company also took delivery of a new 155,000 barrel ATB in November 2016 and a second 155,000 ATB in September 2017.  The Company also took delivery in December 2016 of a 35,000 barrel coastal petrochemical tank barge. The Company is aware of nine coastal tank barge and tugboat units placed in service in 2016 and seven in 2017 by competitors, and seven announced coastal tank barge and tugboat units under construction by competitors for delivery in 2018 and 2019. The Company removed from service 12 out-of-service coastal tank barges in the 2017 fourth quarter.  The coastal tank barges will be either scrapped or sold into international non-competing markets during 2018.

Higher fuel prices could increase operating expenses and fuel price volatility could reduce profitability. The cost of fuel during 2017 was approximately 9% of marine transportation revenue. 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. Four marine transportation customers accounted for approximately 20% of the Company’s 2017, 25% of 2016 and 30% of 2015 revenue. The Company has contracts with these customers expiring in 2018 through 2021. Two distribution and services customers accounted for approximately 13% of the Company’s 2017, 3% of 2016 and 7% of 2015 revenue. Although the Company considers its relationships with these companies to be strong, the loss of any of these customers could have an adverse effect on the Company.

The Company’s distribution and services segment has a 52-year relationship with EMD, the largest manufacturer of medium-speed diesel engines. The Company, through Kirby Engine Systems, serves as both an EMD distributor and service center for select markets and locations for both service and parts. With the acquisition of S&S in September 2017, the Company added additional EMD exclusive distributorship rights in key states, primarily through the central, south and eastern areas of the United States. With the S&S acquisition, the Company became the United States distributor for EMD marine and power generation applications.  Sales and service of EMD products account for approximately 3% of the Company’s revenues for 2017. 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.

United and S&S have maintained continuous exclusive distribution rights for MTU and Allison since the 1940s. United and S&S are two of MTU’s top five distributors of off-highway engines in North America, with exclusive distribution rights in multiple states.  In addition, as distributors of Allison products, United and S&S have exclusive distribution rights in multiple key growth states. United and S&S are also the distributor for parts, service and warranty on Daimler truck engines and related equipment in multiple states. Sales and service of MTU and Allison products accounted for approximately 12% of the Company’s revenues during 2017. 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 distribution and 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 distribution and services industry is also very competitive. The segment’s oil and gas market’s principal competitors are independent distribution and 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 distribution and services industry and continued low price of natural gas, crude oil or natural gas condensate, and resulting decline in drilling for such natural resources in North American shale formations, could result in less oilfield equipment being manufactured and remanufactured, lower rates for service and parts pricing and result in less manufacturing, remanufacturing, service and repair opportunities and parts sales for the Company. For the commercial and industrial market, the segment’s primary marine diesel 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. For power generation, the primary competitors are other independent service companies.

Significant increases in the construction cost of tank barges and towing vessels may limit the Company’s ability to earn an adequate return on its investment in new tank barges and towing vessels. The price of steel increased significantly from 2006 to 2009, thereby increasing the construction cost of new tank barges and towing vessels. 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 inland tank barges delivered since 2010 steadily increased until reaching its peak in early 2015, but remained below the construction price for tank barges delivered in 2009. Construction costs for inland tank barges ordered in 2016 for delivery in 2017, and ordered in 2017 for delivery in 2018 have declined, reflecting the current industry-wide over-capacity in the inland tank barge market and subsequent decline in the number of tank barges ordered for delivery in 2017 and 2018.

The Company’s marine transportation segment could be adversely impacted by the failure of the Company’s shipyard vendors to deliver new vessels according to contractually agreed delivery schedules and terms. The Company contracts with shipyards to build new vessels and currently has many vessels under construction. Construction projects are subject to risks of delay and cost overruns, resulting from shortages of equipment, materials and skilled labor; lack of shipyard availability; unforeseen design and engineering problems; work stoppages; weather interference; unanticipated cost increases; unscheduled delays in the delivery of material and equipment; and financial and other difficulties at shipyards including labor disputes, shipyard insolvency and inability to obtain necessary certifications and approvals. A significant delay in the construction of new vessels or a shipyard’s inability to perform under the construction contract could negatively impact the Company’s ability to fulfill contract commitments and to realize timely revenues with respect to vessels under construction. Significant cost overruns or delays for vessels under construction could also adversely affect the Company’s financial condition, results of operations and cash flows.

The Company’s distribution and services segment could be adversely impacted by future legislation or additional regulation of hydraulic fracturing practices. The Company, through its United and S & S subsidiaries, 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 pressure pumping units. 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 have adopted or 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 pressure pumping 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 distribution and services segment.

The Company relies on critical information systems for the operation of its businesses, and the failure of any critical information system, including a cyber-security breach, may adversely impact its businesses. The Company is dependent on its technology infrastructure and must maintain and rely upon critical information systems for the effective and safe operation of its businesses. These information systems include software applications and hardware equipment, as well as data networks and telecommunications.

The Company’s information systems, including the Company’s proprietary vessel management computer system, are subject to damage or interruption from a number of potential sources, including but not limited to, natural disasters, software viruses, power failures and cyber-attacks. The Company has implemented measures such as emergency recovery processes, virus protection software, intrusion detection systems and annual attack and penetration audits to mitigate these risks. However, the Company cannot guarantee that its information systems cannot be damaged or compromised.

Any damage or compromise of its data security or its inability to use or access these critical information systems could adversely impact the efficient and safe operation of its businesses, or result in the failure to maintain the confidentiality of data of its customers or its employees and could subject the Company to increased operating expenses or legal action, which could have an adverse effect on the Company.

Prevailing natural gas and crude oil prices, as well as the volatility of their prices, could have an adverse effect on the Company’s businesses. Demand for tank barge transportation services is driven by the production of volumes of the bulk liquid commodities such as petrochemicals, black oil and refined petroleum products that the Company transports by tank barge. This production can depend on the prevailing level of natural gas and crude oil prices, as well as the volatility of their prices.

In general, lower energy prices are good for the United States economy and typically translate into increased petrochemical and refined product production and therefore increased demand for tank barge transportation services. However, during 2015, 2016 and 2017 lower crude oil prices resulted in a decline in domestic crude oil and natural gas condensate production and reduced volumes to be transported by tank barge. The Company estimates that at the beginning of 2015 there were approximately 550 inland tank barges and 35 coastal tank barges in the 195,000 barrels or less category transporting crude oil and natural gas condensate. At the end of 2016, the Company estimated that approximately 140 inland tank barges and approximately ten coastal tank barges in the 195,000 barrel or less category were transporting such products, a reduction of approximately 410 inland tank barges and 25 coastal tank barges that have moved into other markets. At the end of 2017, the Company estimates that approximately 250 inland tank barges and approximately three coastal tank barges were transporting crude and natural gas condensate.  Volatility in the price of natural gas and crude oil can also result in heightened uncertainty which may lead to decreased production and delays in new petrochemical and refinery plant construction.  Increased competition for available black oil and petrochemical barge moves caused by reduced crude oil and natural gas condensate production could have an adverse impact on the Company’s marine transportation segment.

Lower energy prices generally result in a decrease in the number of oil and gas wells being drilled. Oilfield service companies reduce their capital spending, resulting in decreased demand for new parts and equipment, including pressure pumping units, provided by the Company’s distribution and services segment. This may also lead to order cancellations from customers or customers requesting to delay delivery of new equipment. The Company also services offshore supply vessels and offshore drillings rigs operating in the Gulf of Mexico, as well as internationally. Low energy prices may negatively impact the number of wells drilled in the Gulf of Mexico and international waters. In addition to the possibility that decreased energy prices may result in reduced demand for the Company’s services, parts and equipment, energy price volatility may also result in difficulties in the Company’s ability to ramp up and ramp down production on a timely basis and, therefore, could result in an adverse impact on the Company’s distribution and services segment.

The Company’s distribution and services segment could be adversely impacted by the construction of pressure pumping units by its competitors. In early 2015, an estimated 19.5 million horsepower of pressure pumping units were working in North America. By late 2016, the working horsepower in North America has declined to an estimated 9.0 million, with an estimated 4.5 million horsepower scrapped, an estimated 2.0 million horsepower available for work and an estimated 4.0 million horsepower stacked, the large majority of which would require major service before being placed back in service.  A significant drop in demand due to the low price of crude oil resulted in an oversupply in the pressure pumping market and negatively impacted the Company’s 2015 and 2016 results of operations.  During late 2016 and 2017, with the stabilization of crude oil prices in the $40 to $60 per barrel range, the United States land rig count improved and service intensity in the well completion business increased.  As a result, the Company experienced a healthy rebound in service demand, particularly with pressure pumping unit remanufacturing and transmission overhauls, and with the acquisition of S&S in September 2017, the manufacture of oilfield service equipment, including pressure pumping units, and the sale of transmissions.  However, 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.

Item 1B.

Unresolved Staff Comments

Not applicable.

Item 2.

Properties

The information appearing in Item 1 under “Marine Transportation– Properties” and “Distribution and 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 2009, the Company was named a Potentially Responsible Party (“PRP”) in addition to a group of approximately 250 named PRPs under the Comprehensive Environmental Response, Compensation and Liability Act of 1981 (“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 notified 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 Environmental Protection Agency (“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.

Item 4.

Mine Safety Disclosures

Not applicable.

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
2018
First Quarter (through February 23, 2018)		$	80.90			$	66.80
2017
First Quarter			73.40				61.65
Second Quarter			74.50				62.55
Third Quarter			68.60				59.25
Fourth Quarter			72.95				61.80
2016
First Quarter			63.03				44.63
Second Quarter			73.25				57.92
Third Quarter			64.85				50.80
Fourth Quarter			70.90				55.11

As of February 23, 2018, the Company had 59,674,000 outstanding shares held by approximately 620 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 credit agreements contain covenants restricting the payment of dividends by the Company at any time when there is a default under the agreements.

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, 2017. 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,
		2017				2016				2015				2014				2013
Revenues:
Marine transportation		$	1,324,106			$	1,471,893			$	1,663,090			$	1,770,684			$	1,713,167
Distribution and services			890,312				298,780				484,442				795,634				529,028
		$	2,214,418			$	1,770,673			$	2,147,532			$	2,566,318			$	2,242,195
Net earnings attributable to Kirby		$	313,187			$	141,406			$	226,684			$	282,006			$	253,061
Net earnings per share attributable to Kirby common stockholders:
Basic		$	5.62			$	2.63			$	4.12			$	4.95			$	4.46
Diluted		$	5.62			$	2.62			$	4.11			$	4.93			$	4.44
Common stock outstanding:
Basic			55,308				53,454				54,729				56,674				56,354
Diluted			55,361				53,512				54,826				56,867				56,552

 

		December 31,
		2017				2016				2015				2014				2013
Property and equipment, net		$	2,959,265			$	2,921,374			$	2,778,980			$	2,589,498			$	2,370,803
Total assets		$	5,127,427			$	4,289,895			$	4,140,558			$	4,127,052			$	3,666,402
Long-term debt, including current portion		$	992,406			$	722,802			$	774,849			$	712,405			$	742,493
Total equity		$	3,114,223			$	2,412,867			$	2,279,196			$	2,264,913			$	2,022,153

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, tornados, 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 outstanding applicable to diluted earnings per share for 2017, 2016 and 2015 were 55,361,000, 53,512,000 and 54,826,000, respectively. The increase in the weighted average number of common shares for 2017 compared with 2016 primarily reflects the issuance of 5,696,259 shares of common stock associated with the acquisition of S&S on September 13, 2017, and the issuance of restricted stock and the exercise of stock options. The decrease in the weighted average number of common shares outstanding for 2016 and 2015 compared with 2014 primarily reflects common stock repurchases in the 2014 fourth quarter through the 2016 first quarter, partially offset by the issuance of restricted stock and the exercise of stock options.

Overview

The Company is the nation’s largest domestic tank barge operator, transporting bulk liquid products throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise along all three United States coasts, and in Alaska and Hawaii. The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge. As of December 31, 2017, the Company operated a fleet of 841 inland tank barges with 17.3 million barrels of capacity, and operated an average of 224 inland towboats during 2017. The Company’s coastal fleet consisted of 56 tank barges with 5.4 million barrels of capacity and 53 coastal tugboats. The Company also owns and operates five offshore dry-bulk cargo barges, five offshore tugboats and one docking tugboat transporting dry-bulk commodities in United States coastal trade. Through its distribution and services segment, the Company provides after-market service and parts for engines, transmissions, reduction gears, and related equipment used in oilfield services, marine, mining, power generation, on-highway, and other industrial applications. The Company also rents equipment including generators, fork lifts, pumps and compressors for use in a variety of industrial markets, and manufactures and remanufactures oilfield service equipment, including pressure pumping units, for the oilfield service and oil and gas operator and producer markets.

For 2017, net earnings attributable to Kirby were $313,187,000, or $5.62 per share, on revenues of $2,214,418,000, compared with 2016 net earnings attributable to Kirby of $141,406,000, or $2.62 per share, on revenues of $1,770,673,000. The 2017 year included $269,472,000 after taxes, or $4.83 per share, of deferred tax revaluation benefit, the result of recent federal tax reform legislation that resulted in the remeasurement of the Company’s United States deferred tax assets and liabilities.  This was partially offset by $105,712,000 before taxes, $66,975,000 after taxes, or $1.20 per share, non-cash impairment of long-lived assets and $5,449,000 before taxes, $3,389,000 after taxes, or $.06 per share, charge for severance and early workforce retirements.

Marine Transportation

For 2017, 60% of the Company’s revenues were generated by its marine transportation segment. The segment’s customers include many of the major petrochemical and refining companies that operate in the United States. Products transported include intermediate materials used to produce many of the end products used widely by businesses and consumers — plastics, fiber, paints, detergents, oil additives and paper, among others, as well as residual fuel oil, ship bunkers, asphalt, gasoline, diesel fuel, heating oil, crude oil, natural gas condensate and agricultural chemicals. Consequently, the Company’s marine transportation business is directly affected by the volumes produced by the Company’s petroleum, petrochemical and refining customer base.

The Company’s marine transportation segment’s revenues for 2017 decreased 10% and operating income decreased 47% compared with 2016. The decreases were primarily due to the industry-wide oversupply of tank barges in both the inland and coastal markets, resulting in lower inland and coastal marine transportation term and spot contract pricing, lower coastal equipment utilization and a continued increase in the number of coastal tank barges operating in the spot market, which added increased idle time and voyage costs.  The decrease in operating income was partially offset by a reduction in the average number of inland towboats operated and savings in the coastal market from the release of chartered tugboats, idling owned barges and tugboats and reducing headcount accordingly.

The 2017 marine transportation revenues and operating income decreases were also due to the loss of revenue and additional operating expenses in the inland and coastal marine transportation markets associated with Hurricanes Harvey and Irma. Lost revenues and costs associated with the hurricanes were approximately $0.03 per share for the third quarter. Marine transportation operating income for 2017 included a $3,888,000 severance charge in the fourth quarter. For 2017 and 2016, the inland tank barge fleet contributed 72% and 67%, respectively, and the coastal fleet 28% and 33%, respectively, of marine transportation revenues.

Inland marine transportation equipment utilization ranged from high 80% to low 90% during the 2017 first quarter, mid-80% to high 80% during the second quarter, mid-80% to mid-90% during the third quarter and low to mid-90% during the fourth quarter. The higher utilization during the third quarter reflected recoveries from marine customers for delays and pent-up demand for liquid barge movements as the Gulf Coast petrochemical and refinery complex returned to normal operations following the deterioration in operating conditions experienced after Hurricane Harvey made land-fall on the Texas Gulf Coast at the end of August and unrelated and coinciding infrastructure repairs on the upper Mississippi River.  In addition, favorable commodity prices for customers’ products partially mitigated the negative impact of the hurricanes.  The higher utilization during the fourth quarter reflected a continued favorable pricing environment for customers’ products, the addition of new petrochemical industry capacity and the continued retirement of older barges from the fleet. For 2016, utilization declined to the high 80% range at the end of the year, occasionally declining to the low-to-mid 80% range during the year, from the 90% to 95% range at the beginning of 2016.

Coastal marine transportation utilization declined throughout 2017 as new tank barges were placed in service by the Company and competitors, further adding to the overcapacity in the coastal market and further increasing the number of coastal tank barges operating in the spot market, which added increased idle time and voyage costs.  Equipment utilization was in the mid-70% to low 80% range during the first quarter, high 60% to mid-70% range during the second quarter, and low 60% to mid-60% during the 2017 third and fourth quarters.  Coastal utilization also declined throughout 2016, from the high 80% to low 90% range in the first quarter to the low 80% level in the fourth quarter.

During 2017 and the 2016 fourth quarter, approximately 75% of the inland marine transportation revenues were under term contracts and 25% were spot contract revenues. For the 2016 first nine months, approximately 80% of inland marine transportation revenues were under term contracts and 20% were spot contract revenues. These allocations provide the operations with a more predictable revenue stream. Inland time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented 49% of the inland revenues under term contracts during 2017 compared with 52% during 2016. Rates on inland term contracts renewed in 2017 decreased in the 4% to 8% average range compared with term contracts renewed in 2016. Spot contract rates, which include the cost of fuel, were relatively consistent throughout the year but below term contract rates.  Effective January 1, 2017, annual escalators for labor and the producer price index on a number of inland multi-year contracts resulted in rate increases on those contracts of approximately 0.6%, excluding fuel.

During 2017 and 2016, mainly due to lower revenues for equipment trading in the spot market, approximately 80% of the coastal marine transportation revenues were under term contracts and 20% were spot contract revenues. Coastal time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented approximately 85% of the coastal revenues under term contracts in 2017 and 2016. The majority of coastal term contracts failed to renew during 2017 as customers elected to source their needs in the spot market.  Spot contract rates, which include the cost of fuel, remained meaningfully below term contracts rates during 2017, the degree to which varied based on geography, vessel capacity, vessel type and product serviced.  Revenues were further reduced by an outage at a key customer’s plant during the fourth quarter.

The 2017 marine transportation operating margin was 10.3% compared with 17.5% for 2016.

Distribution and Services

During 2017, the distribution and services segment generated 40% of the Company’s revenues, of which 43% was generated from overhauls and service, 34% from direct parts sales and 23% from manufacturing.  The results of the distribution and services segment are largely influenced by the economic cycles of the oilfield service and oil and gas operator and producer markets, marine, mining, power generation, on-highway and other industrial markets.

Distribution and services revenues for 2017 increased 198% and operating income increased 2,618% compared with 2016. The higher revenues and operating income in 2017 compared to 2016 were primarily attributable to the increased demand in the oil and gas market for the remanufacture of pressure pumping units and transmission overhauls, an improvement in the manufacturing of oilfield service equipment, including pressure pumping units, and an increase in the demand for the sale and distribution of engines, transmissions and related parts. The higher 2017 revenues and operating income also reflected the S&S acquisition on September 13, 2017.  The oil and gas market of S&S benefited from healthy demand for service work, parts sales and the manufacturing of pressure pumping equipment and ancillary oilfield service equipment.  In the commercial and industrial market, for the marine sector throughout the 2017 first nine months, customers deferred major maintenance projects largely due to the weak inland and coastal tank barge markets and inland dry cargo barge market, and experienced continued weakness in the Gulf of Mexico oilfield services market.  During the 2017 fourth quarter, the marine sector experienced a modest turnaround in orders for new engines and overhauls on medium speed engines that had been deferred, as well as higher demand for new parts in the Gulf Coast offshore drilling market. The power generation sector was relatively stable with major generator set upgrades and parts sales for both domestic and international power generation customers.  The commercial and industrial market of S&S benefited from elevated demand for generator rentals and increased service work as a result of demand following Hurricanes Harvey, Irma and Maria. The distribution and services results for 2017 included a severance charge of $1,581,000 incurred in the 2017 fourth quarter, in response to the reduced activity in its marine sector and the integration of S&S into the Company.

The distribution and services operating margin for 2017 was 9.7% compared with 1.1% for 2016.

Cash Flow and Capital Expenditures

For 2017, cash generated and borrowings under the Company’s revolving credit facility were used for capital expenditures of $177,222,000, including $17,906,000 for inland tank barge and towboat construction, $9,375,000 for progress payments on the construction of a 155,000 barrel ATB placed in service in the 2017 third quarter, $17,842,000 for progress payments on the construction of two 4900 horsepower coastal tugboats, one placed in service in the 2017 second quarter and the second in the 2017 fourth quarter, $25,917,000 for progress payments on six 5000 horsepower coastal ATB tugboats, $698,000 in final costs for the construction of a 35,000 barrel coastal petrochemical tank barge, and $105,484,000 primarily for upgrading existing marine equipment and marine transportation and distribution and services facilities, and $470,101,000 for acquisitions of businesses and marine equipment.

 

The Company’s debt-to-capitalization ratio increased to 24.2% at December 31, 2017 from 23.1% at December 31, 2016, primarily due to borrowings under the Company’s Revolving Credit Facility used to purchase the assets of S&S, less the increase in total equity from net earnings attributable to Kirby for 2017 of $313,187,000, stock issued with a fair value of $366,554,000 in connection with the acquisition of the assets of S&S, exercise of stock options and the amortization of unearned equity compensation, partially offset by an $8,486,000 decrease in retained earnings due to the adoption of ASU 2016-09. As of December 31, 2017, the Company had $495,845,000 outstanding under its Revolving Credit Facility and $500,000,000 of senior notes outstanding, offset by $3,442,000 in unamortized debt issuance costs.

During 2017, the Company took delivery of five new inland tank barges with a total capacity of approximately 144,000 barrels, acquired nine specialty pressure tank barges and four 30,000 barrel tank barges with a total capacity of 255,000 barrels, retired 54 inland tank barges, reducing its capacity by approximately 1,024,000 barrels, and temporarily chartered one inland tank barge with a total capacity of approximately 11,000 barrels. The net result was a reduction of 35 inland tank barges and approximately 614,000 barrels of capacity during 2017.

The Company projects that capital expenditures for 2018 will be in the $195,000,000 to $215,000,000 range. The 2018 construction program will consist of one 30,000 barrel inland tank barge, progress payments on the construction of 15 inland towboats, five of which will be placed in service in 2018 and the remaining 10 in 2019 and 2020, and progress payments on the construction of six 5000 horsepower coastal ATB tugboats, three of which will be placed in service in 2018 and three in 2019. Based on current commitments, steel prices and projected delivery schedules, the Company’s 2018 payments on the new inland tank barge and towboats will be approximately $35,000,000 and 2018 progress payments on the construction of the six 5000 horsepower coastal ATB tugboats will be approximately $40,000,000.  Approximately $100,000,000 to $115,000,000 is primarily capital upgrades and improvements to existing marine equipment and facilities.  The balance of $20,000,000 to $25,000,000 will be for rental fleet growth, new machinery and equipment, and facilities improvements in the distribution and services segment.

Outlook

Reduced crude oil volumes to be moved by tank barge due to a decline in oil prices, a decline in domestic drilling and additional pipeline capacity, coupled with the large number of inland tank barges built during 2015 and 2016, and coastal tank barges during 2016 and 2017, many of which were originally built for the movement of crude oil and natural gas condensate, have resulted in excess industry-wide tank barge capacity and resulting lower equipment utilization for both the inland and coastal marine transportation markets. This extra capacity placed inland and coastal tank barge rates under pressure throughout 2016 and 2017. As a result, the inland market for 2018 will be impacted by the pricing declines experienced throughout 2017. However, with continued industry-wide inland tank barge retirements, minimal new inland tank barge construction and higher customer demand, the result of increased production from current facilities, plant expansions and the opening of new facilities, overall inland utilization is anticipated to be in the low to mid-90% range for 2018.  As a result of the anticipated higher utilization, the Company does anticipate a modest pricing improvement in the 2018 second half.

In the coastal marine transportation market, a decline in crude oil and natural gas condensate transportation volumes increased available capacity and resulted in some reluctance among certain customers to extend term contracts, which has led to an increase in the number of coastal vessels operating in the spot market. In addition, the Company and the industry have added new coastal tank barge capacity during 2015, 2016 and 2017, with additional new capacity coming on-line in 2018 and 2019. While much of this new capacity is replacement capacity for older vessels anticipated to be retired, the Company maintains a cautious outlook as the industry absorbs the new capacity. While the Company does expect the supply of tank barges and capacity in the coastal industry fleet to eventually balance with demand, the Company does not anticipate that balance occurring in 2018 without an improvement in demand. As a result, throughout 2017, the Company released chartered tugboats, idled owned barges and tugboats and reduced headcount accordingly. In addition, the Company decided to put certain older out-of-service vessels up for sale in response to lower equipment utilization, pricing pressure and expensive ballast water treatment system installations required in the next few years on some of the coastal tank barges.  The vessels include 12 out-of-service coastal tank barges and 21 inactive coastal tugboats and resulted in a $105,712,000 non-cash pre-tax impairment charge in the 2017 fourth quarter.  Retiring some of the older coastal vessels reduces the fleet’s age profile and improves the efficiency of the fleet.  The Company, considering the retirement of vessels, expects tank barge utilization for the coastal markets to be in the low to mid-80% range for 2018.  The Company anticipates rates on coastal term contracts to decline in the 10% to 15% range during 2018, the majority occurring in the first quarter.

As of December 31, 2017, the Company estimated there were approximately 3,825 inland tank barges in the industry fleet, of which approximately 500 were over 30 years old and approximately 250 of those over 40 years old. Given the age profile of the industry inland tank barge fleet and current market conditions, the expectation is that many older tank barges will be removed from service during 2018. The Company estimates that approximately 30 tank barges were ordered during 2017 for delivery throughout 2018, one of which is for the Company, and many older tank barges, including an expected 25 by the Company, will be retired, dependent on 2018 market conditions. Historically, 75 to 150 older inland tank barges are retired from service each year industry-wide, with the extent of the retirements dependent on petrochemical and refinery production levels, and crude oil and natural gas condensate movements, both of which can have a direct effect on industry-wide tank barge utilization, as well as term and spot contract rates.

 

As of December 31, 2017, the Company estimated there were approximately 290 tank barges operating in the 195,000 barrel or less coastal industry fleet, the sector of the market in which the Company operates, and approximately 20 of those were over 30 years old. The Company is aware of seven announced coastal tank barge and tugboat units in the 195,000 barrel or less category under construction by competitors for delivery in 2018 and 2019.

 

For the distribution and services commercial and industrial market, the Company anticipates an improved marine market for 2018 as maintenance deferrals implemented by inland and coastal marine transportation customers for much of 2017 are no longer sustainable and should lead to higher demand for overhauls, new engines and parts sales as 2018 progresses.  The power generation market should remain stable, benefiting from engine-generator set upgrades and parts sales for both domestic and international customers, customized power generation systems, and the rental of generators.

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 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, a United States or global recession or other adverse economic condition 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 on vessels built for use on the inland waterways are charged to operating expense as incurred and includes the costs incurred in USCG inspections unless the shipyard extends the life or improves the operating capacity of the vessel which results in the costs being capitalized. 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 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 or 60 months, depending on the type of major maintenance performed. Drydocking expenditures that extend the life or improve the operating capability of the vessel result in the costs being capitalized. Routine repairs and maintenance on ocean-going vessels are expensed as incurred. Interest is capitalized on the construction of new ocean-going vessels.

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 is 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 an appropriate discount rate. 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.

Acquisitions

On February 14, 2018, the Company purchased Higman for approximately $419,692,000 in cash, subject to certain post-closing adjustments.  Higman’s fleet consisted of 159 inland tank barges, of which two are under construction and scheduled to be delivered in May 2018 and October 2018, with 4.8 million barrels of capacity, and 75 inland towboats, transporting petrochemicals, black oil, including crude oil and natural gas condensate, and refined petroleum products on the Mississippi River System and the Gulf Intracoastal Waterway.  Financing of the acquisition was through the issuance of $500,000,000 of 4.2% senior unsecured notes due March 1, 2028. The notes were issued on February 12, 2018 in preparation for closing of the acquisition.

 

On October 20, 2017, San Jac, a subsidiary of the Company, purchased certain assets of Sneed Shipbuilding, Inc. for $14,852,000 in cash including its Channelview, Texas shipyard. San Jac is a builder of marine vessels for both inland and offshore applications as well as providing repair and maintenance services. The Company intends to build inland towboats at the shipyard and use the facilities for routine maintenance. Financing of the acquisition was through borrowings under the Company’s revolving credit facility.

On September 13, 2017, the Company completed the acquisition of substantially all of the assets of S&S, a global manufacturer and distributor of products and services for the oil and gas, marine, construction, power generation, transportation, mining and agricultural industries. The acquired business, which the Company operates through a newly formed subsidiary renamed Stewart & Stevenson LLC after the closing of the acquisition, was founded in 1902 and serves domestic and global markets with equipment, rental solutions, and parts and service through a strategic network of sales and service centers in domestic and international locations.

The total value of the transaction was $758,245,000, before post-closing adjustments and excluding transaction fees, consisting of cash consideration of $377,967,000, the assumption of $13,724,000 of debt and $366,554,000 through the issuance of 5,696,259 shares of Company common stock valued at $64.35 per share, the Company’s closing share price on September 13, 2017. The debt assumed consisted of $12,135,000 of term debt and $1,589,000 of short-term secured loans related to the Company’s South American operations.  The term debt was paid off without penalty in the 2017 fourth quarter. Financing of the acquisition was through a combination of the Company’s revolving credit facility and the issuance of Company common stock.

S&S, headquartered in Houston, Texas with 42 branches across 12 states, is a distributor in certain geographic areas for Allison Transmission, MTU, Detroit Diesel, EMD, Deutz and several other manufacturers. S&S’ principal customers are oilfield service companies, oil and gas operators and producers, and companies in the marine, mining, power generation, on-highway and other industrial applications.

On July 10, 2017, the Company completed the purchase of certain inland marine assets from an undisclosed competitor for $68,000,000 in cash. The assets purchased consisted of nine specialty pressure tank barges, four 30,000 barrel tank barges and three 1320 horsepower inland towboats. The average age of the 13 inland tank barges was five years. The 13 tank barges transport petrochemicals and refined petroleum products on the Mississippi River System and the Gulf Intracoastal Waterway. Financing of the equipment acquisition was through borrowings under the Company’s revolving credit facility.

During July 2017, the Company purchased four inland tank barges for $1,450,000, as well as a barge fleeting and marine fueling operation business in Freeport, Texas for $3,900,000.  The Company had been leasing the barges prior to the purchase. Financing of the acquisitions was through the Company’s revolving credit facility.

On October 11, 2016, the Company purchased certain assets of Valley Power Systems, Inc. and Valley Power Systems Northwest, Inc. (collectively “VPS”) for $11,440,000 in cash. The assets purchased are mainly related to the EMD engine supply and repair business of VPS and include an EMD distributor agreement to sell engines in nine western states. Financing of the acquisition was through the Company’s revolving credit facility.

On June 30, 2016, the Company purchased an 80,000 barrel coastal tank barge from TD Equipment Finance, Inc. (“TD Equipment”) for $13,682,000 in cash. The Company had been leasing the barge from TD Equipment prior to its purchase. Financing of the equipment acquisition was through the Company’s revolving credit facility.

On June 2, 2016, the Company purchased four coastal tugboats from Crosby Marine Transportation LLC for $26,450,000 in cash. The four coastal tugboats have an average age of 13 years. Financing of the equipment acquisition was through borrowings under the Company’s revolving credit facility.

On April 15, 2016, the Company purchased the inland tank barge fleet of SEACOR Holdings Inc. (“Seacor”) from subsidiaries of Seacor for a total value of $89,181,000. The assets purchased consisted of 27 inland 30,000 barrel tank barges and 14 inland towboats. The purchase price was comprised of $85,500,000 in cash and the transfer to Seacor of a Florida-based ship docking tugboat with a value of $3,681,000. The average age of the 27 inland tank barges was ten years. Seacor, through its subsidiary, SCF Waxler Marine LLC, transported refined petroleum products, petrochemicals and black oil on the Mississippi River System and the Gulf Intracoastal Waterway. Financing of the acquisition was through the Company’s revolving credit facility.

Results of Operations

The Company reported 2017 net earnings attributable to Kirby of $313,187,000, or $5.62 per share, on revenues of $2,214,418,000, compared with 2016 net earnings attributable to Kirby of $141,406,000, or $2.62 per share, on revenues of $1,770,673,000, and 2015 net earnings attributable to Kirby of $226,684,000, or $4.11 per share, on revenues of $2,147,532,000.

Marine transportation revenues for 2017 were $1,324,106,000, or 60% of total revenues, compared with $1,471,893,000, or 83% of total revenues for 2016, and $1,663,090,000, or 77% of total revenues for 2015. Distribution and services revenues for 2017 were $890,312,000, or 40% of total revenues, compared with $298,780,000, or 17% of total revenues for 2016, and $484,442,000, or 23% of total revenues for 2015.

The 2017 year included $269,472,000 after taxes, or $4.83 per share, of deferred tax benefit, the result of recent federal tax reform legislation that resulted in the remeasurement of the Company’s United States deferred tax assets and liabilities. This was partially offset by $105,712,000 before taxes, $66,975,000 after taxes, or $1.20 per share, non-cash impairment of long-lived assets and $5,449,000 before taxes, $3,389,000 after taxes, or $.06 per share, charge for severance and early workforce retirements.

The 2017 results reflect the acquisition of S&S on September 13, 2017.The 2017 results were negatively impacted by S&S acquisition related costs of  $2,119,000, or $0.02 per share. The 2017 third quarter also included an estimated net $0.03 per share negative impact of Hurricane Harvey, which made landfall along the Texas Gulf Coast in late August 2017, impacting the marine transportation and distribution and services operations, and Hurricane Irma, which disrupted the coastal marine transportation and distribution and services operations along the East Coast.

The 2016 first quarter results included $5,605,000 before taxes, or $.06 per share, of severance charges which were reflected in the marine transportation and distribution and services businesses and corporate staff in order to reduce costs. The 2015 first and third quarters included $1,225,000 and $702,000, respectively, of severance charges which were mainly reflected in the distribution and services results.  Also, the 2015 first quarter results included a gain of $1,621,000 before taxes, or $.02 per share, on the sale of the assets of a small product line in the distribution and services segment.

Marine Transportation

The Company, through its marine transportation segment, is a provider of marine transportation services, operating tank barges and towing vessels transporting bulk liquid products throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise along all three United States coasts, and in Alaska and Hawaii. The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge. As of December 31, 2017, the Company operated 841 inland tank barges, including 31 leased barges, with a total capacity of 17.3 million barrels. This compares with 876 inland tank barges operated as of December 31, 2016, including 34 leased barges, with a total capacity of 17.9 million barrels. The Company operated an average of 224 inland towboats during 2017, of which an average of 70 were chartered, compared with 234 during 2016, of which an average of 73 were chartered. The Company’s coastal tank barge fleet as of December 31, 2017 consisted of 56 tank barges, including seven of which were leased, with 5.4 million barrels of capacity, and 53 tugboats, five of which were chartered. This compares with 69 coastal tank barges operated as of December 31, 2016, seven of which were leased, with 6.2 million barrels of capacity, and 75 coastal tugboats, eight of which were chartered. As of December 31, 2017, the Company owned five offshore dry-bulk cargo barge and tugboat units engaged in the offshore transportation of dry-bulk cargoes. This compares with six offshore dry-bulk barge and tugboat units as of December 31, 2016.  The Company also owns shifting operations and fleeting facilities for dry cargo barges and tank barges on the Houston Ship Channel and in Freeport, Texas, a shipyard for building towboats and performing routine maintenance near the Houston Ship Channel, as well as a two-thirds interest in Osprey, which transports project cargoes and cargo containers by barge.

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, 2017 (dollars in thousands):

		2017				2016				% Change 2016 to 2017				2015				% Change 2015 to 2016
Marine transportation revenues		$	1,324,106			$	1,471,893				(10	)%		$	1,663,090				(11	)%
Costs and expenses:
Costs of sales and operating expenses			866,602				900,766				(4	)			981,525				(8	)
Selling, general and administrative			116,830				108,917				7				112,193				(3	)
Taxes, other than on income			25,765				20,817				24				18,732				11
Depreciation and amortization			178,898				184,291				(3	)			175,798				5
			1,188,095				1,214,791				(2	)			1,288,248				(6	)
Operating income		$	136,011			$	257,102				(47	)%		$	374,842				(31	)%
Operating margins			10.3	%			17.5	%							22.5	%

The following table shows the marine transportation markets serviced by the Company, the marine transportation revenue distribution for 2017, products moved and the drivers of the demand for the products the Company transports:

Markets Serviced		2017 Revenue Distribution		Products Moved		Drivers
Petrochemicals		56%		Benzene, Styrene, Methanol, Acrylonitrile, Xylene, Naphtha, Caustic Soda, Butadiene, Propylene		Consumer non-durables —70% Consumer durables — 30%
Black Oil		23%		Residual Fuel Oil, Coker Feedstock, Vacuum Gas Oil, Asphalt, Carbon Black Feedstock, Crude Oil, Natural Gas Condensate, Ship Bunkers		Fuel for Power Plants and Ships, Feedstock for Refineries, Road Construction
Refined Petroleum Products		17%		Gasoline, No. 2 Oil, Jet Fuel, Heating Oil, Diesel Fuel, Ethanol		Vehicle Usage, Air Travel, Weather Conditions, Refinery Utilization
Agricultural Chemicals		4%		Anhydrous Ammonia, Nitrogen-Based Liquid Fertilizer, Industrial Ammonia		Corn, Cotton and Wheat Production, Chemical Feedstock Usage

2017 Compared with 2016

Marine Transportation Revenues

Marine transportation revenues for 2017 decreased 10% when compared with 2016 primarily due to the industry-wide oversupply of tank barges in both the inland and coastal markets, resulting in lower inland and coastal marine transportation term and spot contract pricing, and lower coastal equipment utilization. In addition, a continued increase in the number of coastal vessels operating in the spot market led to increased idle time and decreased revenues, partially offset by an increase in the average cost of marine diesel fuel which is largely passed through to the customer and the addition of the nine specialty pressure tank barges and four 30,000 barrel tank barges purchased in July 2017. The 2017 revenue decrease was also due to the loss of revenue in the inland and coastal marine transportation markets associated with Hurricanes Harvey and Irma. Operating conditions for the Company’s inland marine transportation markets deteriorated significantly after Hurricane Harvey made land-fall on the Texas Gulf Coast at the end of August. Unrelated and coinciding infrastructure repairs on the upper Mississippi River further decreased operating efficiency in September and the fourth quarter.  For 2017 and 2016, the inland tank barge fleet contributed 72% and 67%, respectively, and the coastal fleet 28% and 33%, respectively, of marine transportation revenues.

The effect after Hurricane Harvey was an increase in inland tank barge utilization levels from the mid-80% to the mid-90% range during the balance of third quarter compared to the mid-80% to high 80% range during the 2017 second quarter and the high 80% to low 90% range during the 2017 first quarter. As the third quarter concluded, recoveries from marine customers for delays, pent-up demand for liquid barge movements as the Gulf Coast petrochemical and refinery complex returned to normal operations and a stronger pricing environment for customers’ products partially mitigated the negative impact of the hurricanes. Utilization for the 2017 fourth quarter ranged from the low to mid-90%. The higher utilization during the fourth quarter reflected a continued favorable pricing environment for customers’ products, the addition of new petrochemical industry capacity and the continued retirement of older barges from the fleet. The decline in utilization from the 2017 first quarter to the 2017 second quarter was mainly due to better weather conditions along the Gulf Coast, which enhanced operating efficiency and thereby lowered tank barge utilization, and also due to seasonally weak demand for the transportation of agricultural chemicals.

Coastal tank barge utilization levels declined to the low 60% to mid-60% range during the 2017 third and fourth quarters from the high 60% to mid-70% range during the 2017 second quarter and the mid-70% to low 80% range during the 2017 first quarter. Utilization in the coastal marine fleet continued to be impacted by the industry-wide oversupply of tank barges in the coastal industry and weak demand for the transportation of refined petroleum products and crude oil.

The petrochemical market, the Company’s largest market, contributed 56% of marine transportation revenues for 2017, reflecting continued stable volumes from Gulf Coast petrochemical plants for both domestic consumption and to terminals for export destinations, and the addition of the nine specialty pressure tank barges and four 30,000 barrel tank barges purchased in July 2017. Low priced domestic natural gas, a basic feedstock for the United States petrochemical industry, provides the industry with a competitive advantage relative to naphtha-based foreign petrochemical producers.  In addition, favorable commodity prices and the addition of new petrochemical industry capacity in the 2017 second half benefited the segment.

The black oil market, which contributed 23% of marine transportation revenues for 2017, reflected higher fleet utilization in the inland market compared to 2016. The Company continued to transport crude oil and natural gas condensate produced from the Eagle Ford and Permian Basin shale formations in Texas both along the Gulf Intracoastal Waterway with inland vessels and in the Gulf of Mexico with coastal equipment, and continued to transport Utica natural gas condensate downriver from the Mid-Atlantic to the Gulf Coast, however, at much reduced levels compared with 2016. Demand for the transportation of black oil products in the coastal market for 2017 was lower when compared to 2016 due to the continued industry-wide oversupply of tank barges in the coastal industry.

The refined petroleum products market, which contributed 17% of marine transportation revenues for the 2017, reflected weaker demand in both the inland and coastal markets, primarily a result of the oversupply of tank barge capacity, as well as weak heating oil demand in the 2017 first quarter due to the unseasonably warm weather in the Northeast.

The agricultural chemical market, which contributed 4% of marine transportation revenues for 2017, saw typical seasonal demand for transportation of both domestically produced and imported products during the first, third and fourth quarters and a typical seasonal decline in demand in the second quarter.

For 2017, the inland operations incurred 7,577 delay days, 4% more than the 7,278 delay days that occurred during 2016. Delay days measure the lost time incurred by a tow (towboat and one or more tank barges) during transit when the tow is stopped due to weather, lock conditions or other navigational factors. The increase in delay days reflected lost time incurred during and after Hurricane Harvey in late August and September and during the unrelated and coinciding upper Mississippi River infrastructure repairs in September and during the fourth quarter.

During 2017 and the 2016 fourth quarter, approximately 75% of marine transportation inland revenues were under term contracts and 25% were spot contract revenues. For the 2016 first nine months, approximately 80% of inland revenues were under term contracts and 20% were spot contract revenues. These allocations provide the operations with a more predictable revenue stream. Inland time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delay and temporary market declines, represented 49% of inland revenues under term contracts during 2017 compared with 52% for 2016.

During 2017 and 2016, mainly due to lower revenues for equipment trading in the spot market, approximately 80% of the coastal marine transportation revenues were under term contracts and 20% were spot contract revenues. Coastal time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented approximately 85% of the coastal revenues under term contracts in 2017 and 2016.

Rates on inland term contracts renewed in 2017 continued to deteriorate due to excess industry capacity, decreasing in the 4% to 8% average range compared with term contracts renewed in 2016. Spot contract rates, which include the cost of fuel, were relatively consistent throughout the year but were below term contract rates. Effective January 1, 2017, annual escalators for labor and the producer price index on a number of inland multi-year contracts resulted in rate increases on those contracts of approximately 0.6%, excluding fuel.

Marine Transportation Costs and Expenses

Costs and expenses for 2017 decreased 2% compared with 2016. Costs of sales and operating expenses for 2017 decreased 4% compared with 2016, primarily due to fewer inland towboats operated and lower business activity levels, partially offset by higher fuel costs and costs and expenses associated with Hurricanes Harvey and Irma.

The inland marine transportation fleet operated an average of 224 towboats during 2017, of which an average of 70 towboats were chartered, compared with 234 towboats during 2016, of which an average of 73 towboats were chartered. As demand, or anticipated demand, increases or decreases, as new tank barges are added to the fleet or older tank barges are removed from the fleet, as chartered towboat availability changes, or as weather or water conditions dictate, such as the high wind and heavy fog conditions that occurred in the 2017 first and fourth quarters, 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 2017, the inland operations consumed 40.4 million gallons of diesel fuel compared to 40.0 million gallons consumed during 2016. The average price per gallon of diesel fuel consumed during 2017 was $1.79 per gallon compared with $1.46 per gallon for 2016. Fuel escalation and de-escalation clauses on term contracts are designed to rebate fuel costs when prices decline and recover additional fuel costs when fuel prices rise; however, there is generally a 30 to 90 day delay before the contracts are adjusted. Spot contracts do not have escalators for fuel.

Selling, general and administrative expenses for 2017 increased 7% compared with 2016, primarily due to salary increases effective August 1, 2016 and April 1, 2017, higher incentive compensation accruals and higher professional fees, partially offset by cost savings in 2017 from the reduction in force in early 2016.

Taxes, other than on income for 2017 increased 24% compared with 2016, mainly due to higher property taxes on marine transportation equipment, new state franchise taxes effective January 1, 2017 and the addition of S&S in September 2017.

Marine Transportation Operating Income and Operating Margins

Marine transportation operating income for 2017 decreased 47% compared with 2016. The operating margin was 10.3% for 2017 compared with 17.5% for 2016. The results primarily reflected lower inland and coastal term and spot contract pricing, lower coastal equipment utilization and a continued increase in coastal equipment operating in the spot market which added increased idle time and voyage costs, partially offset by savings in the coastal market from the release of chartered tugboats, idling owned barges and tugboats and reducing headcount accordingly, and a reduction in the average number of inland towboats operated. The 2017 operating income decrease was also due to the loss of revenue and additional operating expenses in the inland and coastal marine transportation markets associated with Hurricanes Harvey and Irma. As the third quarter concluded, recoveries from marine customers for delays, pent-up demand for liquid barge movements as the Gulf Coast petrochemical and refinery complex returned to normal operations and a stronger pricing environment for customers’ products partially mitigated the negative impact of the hurricanes.

2016 Compared with 2015

Marine Transportation Revenues

Marine transportation revenues for 2016 decreased 11% compared with 2015, primarily due to lower inland marine transportation term and spot contract pricing, lower inland and coastal equipment utilization, a 24% decline in the average cost of marine diesel fuel which is largely passed through to the customer, and an increase in the number of coastal vessels operating in the spot market which led to increased idle time and decreased revenues, partially offset by the addition of the Seacor tank barges acquired in April 2016. For 2016 and 2015, the inland tank barge fleet contributed 67% and 68%, respectively, and the coastal fleet contributed 33% and 32%, respectively, of marine transportation revenues.

Inland marine transportation equipment utilization declined to the high 80% range at the end of 2016, occasionally declining to the low-to-mid 80% range during the year, from the 90% to 95% range at the beginning of 2016 and throughout 2015. Coastal tank barge utilization levels also declined throughout 2016, from the high 80% to low 90% range in the first quarter to the low 80% level in the fourth quarter. Coastal utilization levels were generally in the 90% to 95% range throughout the majority of 2015.

The petrochemical market, the Company’s largest market, contributed 49% of marine transportation revenues for 2016, reflecting continued stable volumes from Gulf Coast petrochemical plants for both domestic consumption and to terminals for export destinations, aside from the negative impact of plant maintenance turnarounds. Also, demand for movements of certain upriver petrochemicals was strong in the 2016 second half. Low priced domestic natural gas, a basic feedstock for the United States petrochemical industry, provides the industry with a competitive advantage relative to naphtha-based foreign petrochemical producers.

The black oil market, which contributed 25% of marine transportation revenues for 2016, reflected lower fleet utilization due to commodity price volatility. During 2016, the Company continued to transport crude oil and natural gas condensate produced from the Eagle Ford and Permian Basin shale formations in Texas both along the Gulf Intracoastal Waterway with inland vessels and in the Gulf of Mexico with coastal equipment, and continued to transport Utica natural gas condensate downriver from the Mid-Atlantic to the Gulf Coast, however, at reduced levels compared with 2015.

The refined petroleum products market, which contributed 23% of marine transportation revenues for 2016, reflected increased volumes in the inland market as a result of the Seacor acquisition in April 2016, partially offset by soft demand in the coastal market, primarily a result of weak heating oil demand in the 2016 first quarter and the movement of vessels to the spot market at lower rates with increased idle time.

The agricultural chemicals market, which contributed 3% of marine transportation revenues for 2016, saw typical seasonal demand for transportation of both domestically produced and imported products during the first, third and fourth quarters and a decline in demand in the second quarter, primarily due to a shortened spring season.

For 2016, the inland operations incurred 7,278 delay days, 8% less than the 7,924 delay days that occurred during 2015. Delay days measure the lost time incurred by a tow (towboat and one or more tank barges) during transit when the tow is stopped due to weather, lock conditions or other navigational factors. Operating conditions during the 2016 first quarter were challenging due to periodic high wind and heavy fog along the Gulf Coast. Additionally, high water on the Mississippi River System led to tow size restrictions and added horsepower requirements, as well as slower transit times for most of the 2016 first quarter. During the 2016 second quarter, operating conditions were seasonally normal, although high cross currents at floodgates and river crossings on the Gulf Intracoastal Waterway led to congestion and added delays at certain points along the Gulf Coast. During the 2016 third quarter, operating conditions were seasonally normal, although there was significant flooding in Louisiana that caused some disruptions in the Gulf Intracoastal Waterway for a short period. During the 2016 fourth quarter, dense fog and high winds along the Gulf Coast created operating challenges and ice on the Illinois River presented some short-term challenges for upriver transit times and efficiency.

During the first nine months of 2016 and all of 2015, approximately 80% of the inland marine transportation revenues were under term contracts and 20% were spot contract revenues. During the 2016 fourth quarter, approximately 75% of inland marine transportation revenues were under term contracts and 25% were spot contract revenues. These allocations provide the operations with a more predictable revenue stream. Inland time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented 52% of the inland revenues under term contracts during 2016 compared with 55% during 2015.

During 2016 and the 2015 third and fourth quarters, approximately 80% of the coastal marine transportation revenues were under term contracts and 20% were spot contract revenues. During the 2015 first and second quarters, approximately 85% of the coastal marine transportation revenues were under term contracts and 15% were spot contract revenues. The decrease in term contract revenues in 2016 and the 2015 third and fourth quarters reflected the continued trend of non-renewal of certain term contracts which put increased equipment in the spot contract market, leading to increased idle time. However, the coastal revenues reflected the new 185,000 barrel ATB placed in service in the 2015 fourth quarter under a long-term contract. The second new 185,000 barrel ATB was placed in service in June 2016, also under a long-term contract. Coastal time charters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented approximately 85% of the coastal revenues under term contracts in 2016 as compared to 90% in 2015.

Rates on inland term contracts renewed in 2016 decreased in the 5% to 9% average range compared with term contracts renewed in 2015. Spot contract rates, which include the cost of fuel, were relatively flat in the 2016 first quarter when compared with the 2015 fourth quarter and at or below term contract pricing during the balance of 2016. Effective January 1, 2016, annual escalators for labor and the producer price index on a number of inland multi-year contracts resulted in rate increases on those contracts of approximately 1.5%, excluding fuel.

Rates on coastal term contracts renewed in 2016 were essentially flat when compared with term contracts renewed in 2015. Spot contract rates remained above term contract rates during the 2016 first quarter, fluctuated around term contract rates during the 2016 second quarter and fell below term contract rates during the 2016 third and fourth quarters.

Marine Transportation Costs and Expenses

Costs and expenses for 2016 decreased 6% compared with 2015. Costs of sales and operating expenses for 2016 decreased 8% compared with 2015, primarily reflecting lower business activity levels, lower fuel costs due to the decline in the price of diesel fuel and fewer inland towboats operated.

The inland marine transportation fleet operated an average of 234 towboats during 2016, of which an average of 73 towboats were chartered, compared with 248 during 2015, of which an average of 84 towboats were chartered. As demand, or anticipated demand, increases or decreases, as new tank barges are added to the fleet, as chartered towboat availability changes, or as weather or water conditions dictate, such as the heavy ice and high water conditions that occurred in the 2016 first and fourth quarters, 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 2016, the inland operations consumed 40.0 million gallons of diesel fuel compared to 42.9 million gallons consumed during 2015. The average price per gallon of diesel fuel consumed during 2016 was $1.46 compared with $1.92 for 2015. Fuel escalation and de-escalation clauses on term contracts are designed to rebate fuel costs when prices decline and recover additional fuel costs when fuel prices rise; however, there is generally a 30 to 90 day delay before the contracts are adjusted. Spot contracts do not have escalators for fuel.

Taxes, other than on income, for 2016 increased 11% compared with 2015. The increase is mainly due to higher property taxes on marine transportation equipment.

Selling, general and administrative expenses for 2016 decreased 3% compared with 2015, primarily a reflection of a $3,792,000 severance charge in the 2016 first quarter and the resulting cost savings in the 2016 second, third and fourth quarters, partially offset by salary increases effective August 1, 2016.

Depreciation and amortization for 2016 increased 5% compared with 2015. The increases were primarily attributable to the Seacor acquisition and increased capital expenditures in both the inland and coastal fleets, including new inland tank barges and towboats, as well as a coastal 185,000 barrel ATB placed in service in the fourth quarter of 2015 and a second coastal 185,000 barrel ATB placed in service in the second quarter of 2016.

Marine Transportation Operating Income and Operating Margins

Marine transportation operating income for 2016 decreased 31% compared with 2015. The operating margin for 2016 was 17.5% compared with 22.5% for 2015. The results primarily reflected lower inland marine transportation term and spot contract pricing, lower coastal spot contract pricing, lower inland utilization levels, an increase in the number of coastal vessels operating in the spot market which led to increased idle time and voyage costs, higher depreciation expense and the 2016 first quarter severance charge of $3,792,000, partially offset by savings from a reduction in force in early 2016 and during 2015, and a reduction in the average number of inland towboats operated.

Distribution and Services

The Company, through its distribution and services segment, sells genuine replacement parts, provides service mechanics to overhaul and repair engines, transmissions, reduction gears and related oilfield services equipment, rebuilds component parts or entire diesel engines, transmissions and reduction gears, and related equipment used in oilfield services, marine, mining, power generation, on-highway and other industrial applications. The Company also rents equipment including generators, fork lifts, pumps and compressors for use in a variety of industrial markets, and manufactures and remanufactures oilfield service equipment, including pressure pumping units, for the oilfield service and oil and gas operator and producer markets.

The following table sets forth the Company’s distribution and services segment’s revenues, costs and expenses, operating income and operating margins for the three years ended December 31, 2017 (dollars in thousands):

		2017				2016				% Change 2016 to 2017				2015				% Change 2015 to 2016
Distribution and services revenues		$	890,312			$	298,780				198	%		$	484,442				(38	)%
Costs and expenses:
Costs of sales and operating expenses			690,962				226,186				205				380,841				(41	)
Selling, general and administrative			89,021				54,714				63				70,267				(22	)
Taxes, other than on income			3,357				1,861				80				1,915				(3	)
Depreciation and amortization			20,387				12,833				59				12,498				3
			803,727				295,594				172				465,521				(37	)
Operating income		$	86,585			$	3,186				2,618	%		$	18,921				(83	)%
Operating margins			9.7	%			1.1	%							3.9	%

The following table shows the markets serviced by the Company, the revenue distribution for 2017, and the customers for each market:

Markets Serviced		2017 Revenue Distribution		Customers
Oil and Gas		69%		Oilfield Services, Oil and Gas Operators and Producers
Commercial and Industrial		31%		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, Pleasure Crafts, On and Off-Highway Transportation, Power Generation, Standby Power Generation, Pumping Stations, Mining

2017 Compared with 2016

Distribution and Services Revenues

Distribution and services revenues for 2017 increased 198% compared with 2016, primarily attributable to the increased demand in the oil and gas market for the remanufacture of pressure pumping units and transmission overhauls, an improvement in the manufacturing of oilfield service equipment, including pressure pumping units, and an increase in the demand for the sale and distribution of engines, transmissions and related parts. The 2017 higher revenues also reflected the S&S acquisition on September 13, 2017. S&S benefited from healthy demand for service work, parts sales and the manufacturing of pressure pumping unit.   In the commercial and industrial marine sector, throughout the 2017 first nine months, customers deferred major maintenance projects largely due to the weak inland and coastal tank barge markets and inland dry cargo barge market, and experienced continued weakness in the Gulf of Mexico oilfield services market. During the 2017 fourth quarter, the marine sector experienced a modest turnaround in orders for new engines and overhauls on medium-speed engines that had been deferred, as well as higher demand for new parts in the Gulf Coast offshore drilling market. The power generation market was relatively stable with major generator set upgrades and parts sales for both domestic and international power generation customers. The commercial and industrial market of S&S benefited from elevated demand for rental equipment and increased service work as a result of pent-up demand following Hurricanes Harvey, Irma and Maria.

Distribution and Services Costs and Expenses

Costs and expenses for 2017 increased 172% compared with 2016. Costs of sales and operating expenses for 2017 increased 205% compared with 2016, reflecting the increased demand for the remanufacture of pressure pumping units and transmission overhauls, improvement in the manufacturing of oilfield service equipment, including pressure pumping units, an increase in the demand for the sale and distribution of engines, transmissions and related parts in the oil and gas market, and the S&S acquisition on September 13, 2017.

Selling, general and administrative expenses for 2017 increased 63% compared with 2016, primarily due to increased activity in the oil and gas market in 2017, as well as the S&S acquisition on September 13, 2017. The 2017 fourth quarter included a $1,581,000 severance charge in the marine sector, in response to the reduced activity, and S&S, associated with the integration of S&S and the Company.  The 2016 first quarter included a $1,436,000 severance charge, in response to the reduced activity in both oil and gas market and the commercial and industrial marine sector, which benefited the 2017 results.

Distribution and Services Operating Income and Operating Margins

Operating income for the distribution and services segment for 2017 increased 2,618% compared to 2016.  The operating margin for 2017 was 9.7% compared with 1.1% for 2016. The results primarily reflected continued strong demand for the remanufacture of pressure pumping units and transmission overhauls, the manufacturing of oilfield service equipment, the sale of new transmissions and related parts, and the earnings contribution of S&S.

2016 Compared with 2015

Distribution and Services Revenues

Distribution and services revenues for 2016 decreased 38% compared with 2015, primarily due to the lack of demand in the oil and gas market for the manufacture of pressure pumping units and other oilfield service equipment and for the sale and distribution of engines, transmissions and parts due to the impact of the decline in the price of crude oil and decreased drilling activity in North American shale formations. During 2016 third and fourth quarters, with the increase in the price of crude oil and resulting increase in drilling activity, the segment saw an increase in activity for the remanufacturing and servicing of pressure pumping units. The commercial and industrial marine sector remained at lower activity levels, primarily due to continued weakness in the Gulf of Mexico oilfield services market. In addition, customers continued to defer major maintenance projects in many regions of the marine sector largely due to the weaker barge market and, to a lesser extent, the general economy. The power generation sector was relatively stable during 2016, benefiting from major generator set upgrades and parts sales for both domestic and international power generation customers.

Distribution and Services Costs and Expenses

Costs and expenses for 2016 decreased 37% compared with 2016. Costs of sales and operating expenses for 2016 decreased 41% compared with 2015, reflecting a significant decrease in the number of pressure pumping units and other oilfield service equipment manufactured, decline in the sale and service of engines, transmissions and parts in the oil and gas market and continued weakness in the marine sector. The 2016 first quarter, the 2015 first quarter and the 2015 third quarter selling, general and administrative expenses included severance charges of $1,436,000, $1,111,000 and $702,000, respectively, in response to the reduced activity in both the oil and gas market and the marine sector.

Distribution and Services Operating Income and Operating Margins

Operating income for 2016 decreased 83% compared with 2015. The operating margin for 2016 was 1.1% compared with 3.9% for 2015. The results reflected continued weakness in the oil and gas market, the Gulf of Mexico marine oilfield services sector and customer deferrals of major maintenance projects throughout the marine sector.

General Corporate Expenses

General corporate expenses for 2017, 2016 and 2015 were $18,150,000, $14,966,000 and $14,773,000, respectively. The 21% increase for 2017 compared to 2016 was primarily due to $2,119,000 of S&S acquisition costs incurred during 2017.

Gain (Loss) on Disposition of Assets

The Company reported a net loss on disposition of assets of $4,487,000 in 2017 and $127,000 in 2016 compared with a net gain on disposition of assets of $1,672,000 in 2015. The 2017 loss was primarily from the retirement and sale of older and less efficient inland towboats during the 2017 fourth quarter. The net loss for 2016 and net gain for 2015 were predominantly from the sale or retirement of marine equipment and, in 2015, the sale of the assets of a small distribution and services product line.

Other Income and Expenses

The following table sets forth impairment of long-lived assets, equity in earnings of affiliates, other expense, noncontrolling interests and interest expense for the three years ended December 31, 2017 (dollars in thousands):

		2017				2016				% Change 2016 to 2017				2015				% Change 2015 to 2016
Impairment of long-lived assets		$	(105,712	)		$	—				N/A			$	—				N/A
Equity in earnings of affiliates			291				532				(45	)%			451				18	%
Other expense			(52	)			(291	)			(82	)%			(663	)			(56	)%
Noncontrolling interests			(716	)			(1,398	)			(49	)%			(1,286	)			9	%
Interest expense			(21,472	)			(17,690	)			21	%			(18,738	)			(6	)%

Impairment of Long-lived Assets

During the fourth quarter of 2017, the Company recorded a $105,712,000 non-cash pre-tax impairment charge.  The after-tax effect of the charge was $66,975,000 or $1.20 per share.  The impairment charge was to reduce certain vessels to a fair value of $12,550,000 as the Company decided to put certain older out-of-service vessels up for sale in its marine transportation segment in response to lower equipment utilization, pricing pressure and expensive ballast water treatment system installations required in the next few years on some of the coastal tank barges.    Retiring some of the older coastal marine vessels reduces the fleet’s age profile and improves the efficiency of the fleet.

The vessels that the Company has committed to dispose of include 12 out-of-service coastal tank barges, 21 inactive coastal tugboats and six inactive inland towboats. The tank barges will be scrapped or sold into international non-competing markets in 2018 and the tugboats and towboats will be sold or scrapped in domestic markets during 2018.   The fair market value of the vessels of $12,550,000 is presented in prepaid expenses and other current assets at December 31, 2017.

Equity in Earnings of Affiliates

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

Noncontrolling Interests

Noncontrolling interests for 2017 decreased 49% compared with 2016, primarily due to lower business levels at the Company’s 51% owned shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel with the Company acquiring the remaining 49% interest in December 2016.

Interest Expense

Interest expense for 2017 increased 21% compared with 2016, primarily due to borrowings under the revolving credit facility to finance the S&S acquisition and lower capitalized interest.  During 2017, 2016 and 2015, the average debt and average interest rate (excluding capitalized interest expense) were $774,058,000 and 3.0%, $750,499,000 and 2.7%, and $797,322,000 and 2.7%, respectively. Interest expense for 2017, 2016 and 2015 excludes capitalized interest of $1,731,000, $2,974,000 and $3,026,000, respectively.

Financial Condition, Capital Resources and Liquidity

Balance Sheet

Total assets at December 31, 2017 were $5,127,427,000 compared with $4,289,895,000 at December 31, 2016 and $4,140,558,000 at December 31, 2015. The December 31, 2017 total assets reflect the S&S acquisition in September 2017 for $758,245,000 and the purchase in July 2017 of tank barges and towboats from an undisclosed competitor for $68,000,000, both more fully described under Acquisitions above. The following table sets forth the significant components of the balance sheet as of December 31, 2017 compared with 2016 and 2016 compared with 2015 (dollars in thousands):

		2017				2016				% Change 2016 to 2017				2015				% Change 2015 to 2016
Assets:
Current assets		$	957,082			$	632,951				51	%		$	629,053				1	%
Property and equipment, net			2,959,265				2,921,374				1				2,778,980				5
Investment in affiliates			1,890				2,622				(28	)			2,090				25
Goodwill			935,135				598,131				56				586,718				2
Other intangibles, net			232,808				87,306				167				93,764				(7	)
Other assets			41,247				47,511				(13	)			49,953				(5	)
		$	5,127,427			$	4,289,895				20	%		$	4,140,558				4	%

Liabilities and stockholders’ equity:
Current liabilities		$	480,306			$	358,338				34	%		$	361,917				(1	)%
Long-term debt-less current portion			992,403				722,802				37				774,849				(7	)
Deferred income taxes			468,451				705,453				(34	)			658,085				7
Other long-term liabilities			72,044				90,435				(20	)			66,511				36
Total equity			3,114,223				2,412,867				29				2,279,196				6
		$	5,127,427			$	4,289,895				20	%		$	4,140,558				4	%

2017 Compared with 2016

Current assets as of December 31, 2017 increased 51% compared with December 31, 2016. Trade accounts receivable increased 52%, primarily reflecting the S&S acquisition, as well as an increase in business activity levels in the distribution and services oil and gas market, partially offset by decreased business activity levels in the marine transportation segment. Inventory in the distribution and services segment increased 70%, reflecting the inventory acquired with the S&S acquisition and the building of inventories in the oil and gas market to meet current business activity levels.  Prepaid expenses and other current assets increased 27% due to the S&S acquisition and to vessels with a fair value of $12,550,000 being committed to be sold in 2018, being reclassified from property and equipment to assets held for sale included in prepaid expenses and other current assets.

Property and equipment, net of accumulated depreciation, at December 31, 2017, increased 1% compared with December 31, 2016. The increase reflected $171,697,000 of capital expenditures for 2017 more fully described under Capital Expenditures Reflected on the Balance Sheet below, and the fair value of the property and equipment acquired in acquisitions of $228,066,000, less $191,584,000 of depreciation expense for 2017 and $57,458,000 of property disposals during 2017.  In addition, during 2017 the Company took an impairment charge of $105,712,000, more fully described under Impairment of Long-lived Assets above, and reclassified $112,770,000 of property and equipment to assets held for sale included in prepaid expenses and other current assets.

Goodwill as of December 31, 2017 increased 56% compared with December 31, 2016, predominantly reflecting the goodwill recorded in the S&S acquisition and the barge fleeting and marine fueling operation business acquisition.

 

Other intangibles, net, as of December 31, 2017, increased 167% compared with December 31, 2016, mainly due to $157,400,000 of intangibles other than goodwill associated with the acquisition of S&S. This increase was partially offset by amortization of $12,098,000.

 

Other assets at December 31, 2017 decreased 13% compared with December 31, 2016, primarily reflecting amortization of deferred major maintenance dry-dock expenditures on ocean-going vessels during 2017, net of additions.

Current liabilities as of December 31, 2017 increased 34% compared with December 31, 2016, primarily reflecting the current liabilities of S&S.  Accounts payable increased 65%, a reflection of the S&S acquisition, as well as increased business activity levels in the distribution and services oil and gas market. Accrued liabilities increased 14%, the majority of which was attributable to the S&S acquisition, partially offset by a reduction in insurance claims payable.  Deferred revenues increased 34%, primarily reflecting the S&S acquisition, offset by decreased advanced billings in the distribution and services oil and gas market and the coastal marine transportation market.

Long-term debt, less current portion, as of December 31, 2017 increased 37% compared with December 31, 2016, primarily reflecting the borrowings under the Company’s Revolving Credit Facility in September 2017 to finance the S&S acquisition and the purchase in July 2017 of tank barges and towboats from an undisclosed competitor.  Net deferred debt issue costs were $3,442,000 and $3,184,000 at December 31, 2017 and December 31, 2016, respectively.

 

Deferred income taxes as of December 31, 2017 decreased 34% compared with December 31, 2016. The decrease primarily reflected the 2017 deferred tax benefit of $256,263,000 driven by the remeasurement of deferred tax assets and liabilities due to tax reform, partially offset by an increase in deferred tax liabilities of $8,486,000 due to the adoption of ASU 2016-09 on January 1, 2017. The adoption reduced deferred tax assets by $8,486,000, which reflected the cumulative difference between the tax effect of stock-based compensation recognized for tax purposes and amounts recognized for financial reporting purposes, resulting in the recognition of a cumulative-effect adjustment to retained earnings of $8,486,000.

Other long-term liabilities as of December 31, 2017 decreased 20% compared with December 31, 2016.  The decrease was primarily due to a reduction in the pension liability related to a pension plan amendment on April 12, 2017 that lowered the projected benefit obligation of the pension plan by $33,433,000, partially offset by the accrual of pension expense during 2017.

Total equity as of December 31, 2017 increased 29% compared with December 31, 2016. The increase was the result of $313,187,000 of net earnings attributable to Kirby for 2017, an increase in accumulated other comprehensive income (“OCI”) of $18,602,000, stock issued with a fair value of $366,554,000 in connection with the S&S acquisition and a $7,128,000 decrease in treasury stock, partially offset by an $8,486,000 decrease in retained earnings due to the adoption of ASU 2016-09. The increase in accumulated OCI primarily resulted from the decrease in unrecognized losses related to the Company’s defined benefit plans driven by the pension plan amendment on April 12, 2017.  The decrease in treasury stock was due to the issuance of restricted stock and the exercise of stock options in connection with stock award plans.

2016 Compared with 2015

Current assets as of December 31, 2016 increased 1% compared with December 31, 2015. Trade accounts receivable increased 2% driven by slower collections at the Company’s marine transportation segment and several large projects billed late in 2016 fourth quarter in the distribution and services segment. Prepaid expenses and other assets increased 9% primarily due to an increase in prepaid fuel and prepaid insurance. Other accounts receivable decreased 7%, primarily due to a decrease in income tax receivable for income taxes overpaid in the 2015 fourth quarter partially offset by an increase in insurance claims receivables.

Property and equipment, net of accumulated depreciation, at December 31, 2016 increased 5% compared with December 31, 2015. The increase reflected $233,103,000 of capital expenditures for 2016, more fully described under Capital Expenditures Reflected on the Balance Sheet below, the fair value of the property and equipment acquired in acquisitions of $127,400,000, less $192,450,000 of depreciation expense for 2016 and $22,871,000 of property disposals during 2016.

Goodwill at December 31, 2016 increased 2% compared with December 31, 2015 mainly due to the purchases of the inland tank barge fleet of Seacor in April 2016 and VPS in October 2016.

 

Other assets at December 31, 2016 decreased 5% compared with December 31, 2015 primarily due to the amortization of major maintenance costs on ocean-going vessels, net of major maintenance drydock expenditures for 2016.

 

Current liabilities as of December 31, 2016 decreased 1% compared with December 31, 2015. The decrease was primarily due to a 28% decrease in employee compensation due to lower employee incentive compensation accruals for 2016 and a 13% decrease in deferred revenues reflecting decreased advanced billings in the coastal marine transportation market and in the distribution and services power generation sector. The decrease was partially offset by an increase of 14% in taxes other than on income due to the timing of property tax payments and an increase of 10% in accrued insurance premiums and claims.

Long-term debt, less current portion, as of December 31, 2016 decreased 7% compared with December 31, 2015, reflecting net payments of $52,848,000 on the revolving credit facility during 2016. Net deferred debt issue costs were $3,184,000 and $3,985,000 at December 31, 2016 and 2015, respectively.

Deferred income taxes as of December 31, 2016 increased 7% compared with December 31, 2015. The increase was primarily due to the 2016 deferred tax provision of $51,296,000, the result of bonus tax depreciation on qualifying expenditures due to the Protecting Americans from Tax Hikes Act (“PATH”) of 2015. PATH continued the bonus tax percentage of 50% for qualifying expenditures placed in service in 2015 through 2017.

Other long-term liabilities as of December 31, 2016 increased 36% compared with December 31, 2015. The increase was primarily due to an increase in the pension liability due to a lower discount rate and no contribution to the pension plan in 2016.

Total equity as of December 31, 2016 increased 6% compared with December 31, 2015. The increase was primarily the result of $141,406,000 of net earnings attributable to Kirby for 2016 and a $7,746,000 decrease in treasury stock, partially offset by a $2,324,000 decrease in additional paid-in capital due to the exercise of stock options at exercise prices below the cost of treasury stock issued and the issuance of restricted stock below the cost of treasury stock issued, a $6,321,000 decrease in accumulated OCI and a decrease in noncontrolling interests of $6,836,000. The decrease in treasury stock was mainly due to the issuance of restricted stock in connection with stock award plans, partially offset by purchases during 2016 of $1,827,000 of the Company’s common stock. The decrease in accumulated OCI primarily resulted from the increase in unrecognized losses related to the Company’s defined benefit plans and the decrease in noncontrolling interests was primarily due to the acquisition of the remaining interests in two partnerships in which the Company had the controlling interest.

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 is to make annual contributions in amounts equal to or greater than amounts necessary to meet minimum government funding requirements. No pension contribution was made in 2017 or 2016 for the 2017 and 2016 years and the pension contribution for the 2015 year was $10,000,000. The fair value of plan assets was $294,995,000 and $257,517,000 at December 31, 2017 and December 31, 2016, respectively.

On April 12, 2017, the Company amended its pension plan to cease all benefit accruals for periods after May 31, 2017 for certain participants. Participants grandfathered and not impacted were those, as of the close of business on May 31, 2017, who either (a) had completed 15 years of pension service or (b) had attained age 50 and completed 10 years of pension service. Participants non-grandfathered are eligible to receive discretionary 401(k) plan contributions. The Company did not incur any one-time charges related to this amendment but the pension plan’s projected benefit obligation decreased by $33,433,000.

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 used discount rates of 3.7% and 4.2 in 2017 and 2016, respectively, in determining its benefit obligations. The Company estimates that every 0.1% decrease in the discount rate results in an increase in the ABO of approximately $5,800,000. The Company assumed that plan assets would generate a long-term rate of return of 7.0% in 2017 and 2016. 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 February 12, 2018, the Company issued $500,000,000 of 4.2% senior unsecured notes due March 1, 2028 (the “2028 Notes”) with U.S. Bank National Association, as trustee.  Interest payments of $10,500,000 are due semi-annually on March 1 and September 1 of each year, with the exception of the first payment on September 1, 2018, which will be $11,550,000. The 2028 Notes are unsecured and rank equally in right of payment with the Company’s other unsecured senior indebtedness. The 2028 Notes contain certain covenants on the part of the Company, including covenants relating to liens, sale-leasebacks, asset sales and mergers, among others. The 2028 Notes also specify certain events of default, upon the occurrence of which the maturity of the notes may be accelerated, including failure to pay principal and interest, violation of covenants or default on other indebtedness, among others. The Company used the proceeds from the issuance of the 2028 Notes to fund the acquisition of Higman.  The remaining net proceeds of the sale of the 2028 Notes will be used for general corporate purposes, including working capital, the repayment of indebtedness and future acquisitions.

On June 26, 2017, the Company entered into an amendment of its Revolving Credit Facility with a syndicate of banks, with JPMorgan Chase Bank, N.A. as the administrative agent bank, that increases the borrowing limit from $550,000,000 to $850,000,000 and extends the maturity date to June 26, 2022.  In addition, the credit agreement allows for a $300,000,000 increase in the aggregate commitments of the banks in the form of revolving credit loans or term loans, subject to the consent of each bank that elects to participate in the increased commitment. The variable interest rate spread varies with the Company’s senior debt rating and is currently 1.00% over LIBOR or equal to an Alternate Base Rate calculated with reference to the agent bank’s prime rate, among other factors. The commitment fee is currently 0.10%. 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. The Company recognized additional interest expense of $187,000 in the 2017 second quarter due to the write-off of certain deferred issue costs in connection with the amendment of the Revolving Credit Facility.  As of December 31, 2017, the Company was in compliance with all Revolving Credit Facility covenants and had $495,845,000 of debt 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 $8,893,000 as of December 31, 2017.

The Company has $500,000,000 of unsecured senior notes (“Senior Notes Series A” and “Senior Notes Series B”) with a group of institutional investors, consisting of $150,000,000 of 2.72% Senior Notes Series A due February 27, 2020 and $350,000,000 of 3.29% Senior Notes Series B due February 27, 2023. No principal payments are required until maturity. The Senior Notes Series A and Series B contain certain covenants on the part of the Company, including an interest coverage covenant, a debt-to-capitalization covenant and covenants relating to liens, asset sales and mergers, among others. The Senior Notes Series A and Series B also specify certain events of default, upon the occurrence of which the maturity of the notes may be accelerated, including failure to pay principal and interest, violation of covenants or default on other indebtedness, among others. As of September 30, 2017, the Company was in compliance with all Senior Notes Series A and Series B covenants and had $150,000,000 of Senior Notes Series A outstanding and $350,000,000 of Senior Notes Series B outstanding.

The Company has a $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, 2019. The Credit Line allows the Company to borrow at an interest rate agreed to by Bank of America and the Company at the time each borrowing is made or continued. The Company had no borrowings outstanding under the Credit Line as of December 31, 2017. Outstanding letters of credit under the Credit Line were $1,117,000 as of December 31, 2017.

On September 13, 2017, as a result of the S&S acquisition, the Company assumed $12,135,000 of term debt, which was paid off without penalty in the 2017 fourth quarter.

Capital Expenditures Reflected on the Balance Sheet

Capital expenditures for 2017 were $171,697,000, including $17,906,000 for inland tank barge and towboat construction, $9,375,000 for progress payments on the construction of a 155,000 barrel coastal ATB placed in service in the 2017 third quarter, $17,842,000 for progress payments on the construction of two 4900 horsepower coastal tugboats, one placed  in service in the 2017 second quarter and the second placed in service in the 2017 fourth quarter, $25,917,000 for progress payments on six 5000 horsepower coastal ATB tugboats, $698,000 in final costs for the construction of a 35,000 barrel coastal petrochemical tank barge, and $99,959,000 primarily for upgrading existing marine equipment and marine transportation and distribution and services facilities.

Capital expenditures for 2016 were $233,103,000, including $10,676,000 for inland tank barge and towboat construction, $14,884,000 in final costs for the construction of two 185,000 barrel ATBs, one placed in service in late 2015 and the second in June 2016, $74,689,000 for progress payments on the construction of two 155,000 barrel ATBs, one placed in service in November 2016 and the second scheduled to be placed in service in the summer of 2017, $10,098,000 for progress payments on the construction of two 4900 horsepower coastal tugboats, $6,593,000 for progress payments on the construction of a 35,000 barrel coastal petrochemical tank barge placed in service in December 2016, $18,000 for progress payments on six 5000 horsepower coastal ATB tugboats, $116,145,000 primarily for upgrading existing marine equipment, and marine transportation and distribution and services facilities.

Financing of the construction of the inland tank barges and towboats, coastal tank barges and tugboats upgrades of existing equipment and marine transportation and distribution and services facilities was through operating cash flows and available credit under the Company’s Revolving Credit Facility.

During 2017, the Company took delivery of five new inland tank barges with a total capacity of approximately 144,000 barrels, acquired nine specialty pressure tank barges and four 30,000 barrel tank barges with a total capacity of 255,000 barrels, retired 54 inland tank barges, reducing its capacity by approximately 1,024,000 barrels, and net chartered one inland tank barge with a total capacity of approximately 11,000 barrels. The net result was a reduction of 35 inland tank barges and approximately 614,000 barrels of capacity during 2017.

The Company projects that capital expenditures for 2018 will be in the $195,000,000 to $215,000,000 range. The 2018 construction program will consist of one 30,000 barrel inland tank barge, progress payments on the construction of 15 inland towboats, five of which will be placed in service in 2018 and the remaining 10 in 2019 and 2020, and progress payments on the construction of six 5000 horsepower coastal ATB tugboats, three of which will be placed in service in 2018 and three in 2019. Based on current commitments, steel prices and projected delivery schedules, the Company’s 2018 payments on the new inland tank barge and towboats will be approximately $35,000,000 and 2018 progress payments on the construction of the six 5000 horsepower coastal ATB tugboats will be approximately $40,000,000.  Approximately $100,000,000 to $115,000,000 is primarily capital upgrades and improvements to existing marine equipment and facilities.  The balance of $20,000,000 to $25,000,000 will be for rental fleet growth, new machinery and equipment, and facilities improvements in the distribution and services segment.

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 2017. As of February 23, 2018, the Company had approximately 1,411,000 shares available under its existing repurchase authorizations. 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 $353,378,000, $415,794,000 and $524,280,000 for the years ended December 31, 2017, 2016 and 2015, respectively. The 2017 and 2016 years experienced net decreases in cash flows from changes in operating assets and liabilities of $51,951,000 and $10,696,000, respectively.  The 2015 year experienced a net increase in cash flows from changes in operating assets and liabilities of $6,505,000.

Funds generated from operations are available for acquisitions, capital expenditure projects, common stock repurchases, repayments of borrowings and for other corporate and operating requirements. In addition to net cash flow provided by operating activities, the Company also had available as of February 23, 2018, $434,452,000 under its Revolving Credit Facility and $8,854,000 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.

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 $850,000,000 and expires June 26, 2022. As of December 31, 2017, the Company had $345,262,000 available under the Revolving Credit Facility. The Senior Notes Series A and Senior Notes Series B do not mature until February 27, 2020 and February 27, 2023, respectively, and require no prepayments.  The 2028 Notes do not mature until March 1, 2028 and require no prepayments.

There are numerous factors that may negatively impact the Company’s cash flow in 2018. For a list of significant risks and uncertainties that could impact cash flows, see Note 14, Contingencies and Commitments in the financial statements, and Item 1A — Risk Factors. Amounts available under the Company’s existing financing 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 $21,554,000 at December 31, 2017, including $10,238,000 in letters of credit and $11,316,000 in performance bonds. All of these instruments have an expiration date within four 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 distribution and services segment is based on prevailing current market rates.

Contractual Obligations

The contractual obligations of the Company and its subsidiaries at December 31, 2017 consisted of the following (in thousands):

		Payments Due By Period
		Total				Less Than 1 Year				2-3 Years				4-5 Years				After 5 Years
Long-term debt		$	995,848			$	3			$	150,000			$	495,845			$	350,000
Non-cancelable operating leases — barges			21,120				8,711				8,379				3,134				896
Non-cancelable operating leases — towing vessels			88,535				59,185				11,305				5,156				12,889
Non-cancelable operating leases — land, buildings and equipment			140,675				18,888				27,585				20,820				73,382
Barge and towing vessel construction contracts			77,503				65,572				11,931				—				—
		$	1,323,681			$	152,359			$	209,200			$	524,955			$	437,167

Approximately 75% 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.

The Company’s pension plan funding strategy is to make annual contributions in amounts equal to or greater than amounts necessary to meet minimum government funding requirements. 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 resulting in the Company electing to only make an expected pension contribution forecast of one year. As of December 31, 2017, the pension plan was funded at 91% of the ABO.

Accounting Standards

 

In March 2017, the FASB issued ASU 2017-07, “Compensation – Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost” (“ASU 2017-07”) which requires employers to include only the service cost component of net periodic pension cost and net periodic postretirement benefit cost in operating expenses. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations. The standard allows only the service cost component to be eligible for capitalization when applicable. ASU 2017-07 is effective for annual and interim periods beginning after December 15, 2017 with early adoption permitted. This standard shall be applied retrospectively for the presentation of the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost benefit in assets. The Company will adopt the provisions of ASU 2017-07 on January 1, 2018 and the Company does not expect the adoption of ASU 2017-07 to have a material impact on its consolidated financial statements.

In January 2017, the FASB issued ASU 2017-04, “Intangibles – Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment” (“ASU 2017-04”) which simplifies the subsequent measurement of goodwill by eliminating Step 2 in the goodwill impairment test that required an entity to perform procedures to determine the fair value of its assets and liabilities at the testing date. An entity instead will perform its annual, or interim, goodwill impairment test by comparing the fair value of a reporting unit with its carrying value and record an impairment charge based on the excess of a reporting unit’s carrying amount over its fair value. An entity still has the option to perform the qualitative assessment for a reporting unit to determine if the quantitative impairment test is necessary. ASU 2017-04 will be applied prospectively and is effective for annual and interim goodwill impairment tests conducted in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment testing dates after January 1, 2017. The Company is currently evaluating the impact, if any, that the adoption of this standard will have on its consolidated financial statements.

In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments” (“ASU 2016-15”) to create consistency in practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows. ASU 2016-15 is effective for annual and interim periods beginning after December 15, 2017. The Company will adopt the provisions of ASU 2016-15 on January 1, 2018 and the Company does not expect the adoption of ASU 2016-15 to have a material impact on its consolidated financial statements.

In March 2016, the FASB issued ASU 2016-09, “Compensation – Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting” (“ASU 2016-09”) which simplifies several aspects of the accounting for share-based payment transactions, including income tax consequences, forfeitures, minimum statutory tax withholding requirements, classification as either equity or liabilities, and classification on the statement of cash flows. The Company adopted the provisions of ASU 2016-09 on January 1, 2017. ASU 2016-09 requires all excess tax benefits and tax deficiencies be recognized as income tax expense or benefit in the income statement, thus eliminating additional paid-in capital pools. The Company recognized a cumulative effect adjustment of $8,486,000 to retained earnings on a modified retrospective basis as of January 1, 2017 and will apply the new standard guidance prospectively to all excess tax benefits and tax deficiencies resulting from settlements after January 1, 2017. The standard also requires a policy election to either estimate the number of awards that are expected to vest or account for forfeitures when they occur. The Company will elect to account for forfeitures when they occur. Also, the standard requires that excess tax benefits should be classified along with other income tax cash flows as an operating activity on the statement of cash flows, which differs from the Company’s historical classification of excess tax benefits as cash inflows from financing activities. The Company elected to apply this provision using the prospective transition method. Additionally, the standard requires cash paid by an employer when directly withholding shares for tax withholding purposes to be classified in the statement of cash flows as a financing activity, which differs from the Company’s previous method of classification of such cash payments as an operating activity. The Company applied this provision retrospectively and reclassified $1,756,000 and $2,975,000 during 2016 and 2015, respectively, which increased net cash provided by operating activities and net cash used in financing activities.

In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842)” (“ASU 2016-02”) to increase transparency and comparability among organizations by requiring recognition of lease assets and lease liabilities on the balance sheet and disclosure of key information about leasing arrangements. ASU 2016-02 is effective for annual and interim periods beginning after December 15, 2018, with early adoption permitted. A modified retrospective approach is required. The Company has formed a project team to evaluate the impact that the adoption of this standard will have on its consolidated financial statements and disclosures. The project team has completed training on the new standard and has started lease review and documentation, but the Company has not yet determined the effect of ASU 2016-02 on its ongoing financial reporting.

In November 2015, the FASB issued ASU 2015-17, “Balance Sheet Classification of Deferred Taxes” (“ASU 2015-17”) which requires that deferred tax liabilities and assets be classified as noncurrent on the balance sheet. The current requirement that deferred tax liabilities and assets of a tax-paying component of an entity be offset and presented as a single amount is not affected by this guidance. The guidance may be applied either prospectively to all deferred tax liabilities and assets or retrospectively to all periods presented. The Company adopted the provisions of ASU 2015-17 on January 1, 2017 on a retrospective basis. The December 31, 2016 current deferred tax assets of $13,604,000 have been reclassified in the consolidated balance sheet from current deferred income taxes asset to noncurrent deferred income taxes liability.

In July 2015, the FASB issued ASU 2015-11, “Inventory (Topic 330): Simplifying the Measurement of Inventory” (“ASU 2015-11”) which applies to inventory that is measured using first-in, first-out (“FIFO”) or average cost. Under the guidance, an entity should measure inventory that is within the scope of this update at the lower of cost and net realizable value. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. ASU 2015-11 is effective for annual and interim periods beginning after December 15, 2016, and should be applied prospectively with early adoption permitted at the beginning of an interim period or annual reporting period. The Company adopted the provisions of ASU 2015-11 on January 1, 2017 and, based on a lower of cost and net realizable value inventory analysis as of December 31, 2016, no adjustments to inventory value were required. The analysis reflected the inventory values are proper within the guidance of ASU 2015-11.

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”). ASU 2014-09 requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. ASU 2014-09 will replace most existing revenue recognition guidance in United States Generally Accepted Accounting Principles when it becomes effective. In July 2015, the FASB voted to delay the effective date of ASU 2014-09 by one year, making it effective for fiscal years, and interim periods within those years, beginning after December 15, 2017, with early adoption permitted as of the original effective date. ASU 2014-09 permits the use of either the retrospective, modified retrospective or prospective with a cumulative catch-up approach. The Company will adopt ASU 2014-09 on January 1, 2018 with a cumulative adjustment that will decrease retained earnings by approximately $10,000,000 rather than restating previously reported results.  The cumulative adjustment will primarily relate to recognition of revenue on certain contract manufacturing activities, primarily construction of new pressure pumping units in the Company’s distribution and services segment.  The Company currently recognizes revenue on manufacturing and assembly projects on a percentage of completion method using measurements of progress towards completion appropriate for the work performed.  Upon the adoption of ASU 2014-09, the Company will recognize the revenues on contract manufacturing activities upon shipment and transfer of control versus the percentage of completion method.

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 2018 interest expense by $715,000 based on balances outstanding at December 31, 2017, and would change the fair value of the Company’s debt by less than 1%.

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 104).

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 (“Exchange Act”)), as of December 31, 2017, as required by Rule 13a-15(b) under the Exchange Act. Based on that evaluation, the Chief Executive Officer and the Chief Financial Officer concluded that, as of December 31, 2017, 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 (i) is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and (ii) is accumulated and communicated to the Company’s management, including the Chief Executive Officer and the Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

 

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, 2017 using the framework in Internal Control — Integrated Framework (2013) 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, 2017. 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. Management’s evaluation of the effectiveness of the Company’s internal control over financial reporting as of December 31, 2017 excluded the internal control over financial reporting of S&S, which was acquired on September 13, 2017.  S&S represents $901 million of the Company’s total consolidated assets and $232 million of the Company’s total consolidated revenues as of and for the year ended December 31, 2017.

Changes in Internal Control Over Financial Reporting. There were no changes in the Company’s internal control over financial reporting during the quarter ended December 31, 2017 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

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, 2017, except for the information regarding executive officers which is provided under Item 1.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

 

CONSOLIDATED BALANCE SHEETS

December 31, 2017 and 2016

		2017				2016
		($ in thousands)
ASSETS
Current assets:
Cash and cash equivalents		$	20,102			$	5,634
Accounts receivable:
Trade — less allowance for doubtful accounts of $8,930 ($7,240 in 2016)			452,222				297,177
Other			106,231				95,327
Inventories — at lower of average cost or market			315,729				185,402
Prepaid expenses and other current assets			62,798				49,411
Total current assets			957,082				632,951
Property and equipment:
Marine transportation equipment			3,941,379				4,071,972
Land, buildings and equipment			419,503				256,925
			4,360,882				4,328,897
Accumulated depreciation			1,401,617				1,407,523
Property and equipment — net			2,959,265				2,921,374
Investment in affiliates			1,890				2,622
Goodwill			935,135				598,131
Other intangibles, net			232,808				87,306
Other assets			41,247				47,511
Total assets		$	5,127,427			$	4,289,895
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Bank notes payable		$	3			$	—
Income taxes payable			191				3,288
Accounts payable			222,005				134,571
Accrued liabilities:
Interest			6,099				5,397
Insurance premiums and claims			108,651				123,371
Employee compensation			45,193				26,916
Taxes — other than on income			22,791				15,481
Other			27,026				13,313
Deferred revenues			48,347				36,001
Total current liabilities			480,306				358,338
Long-term debt — less current portion			992,403				722,802
Deferred income taxes			468,451				705,453
Other long-term liabilities			72,044				90,435
Total long-term liabilities			1,532,898				1,518,690
Contingencies and commitments			—				—
Equity:
Kirby stockholders’ equity:
Common stock, $.10 par value per share. Authorized 120,000,000 shares, issued 65,472,000 in 2017 and 59,776,000 in 2016			6,547				5,978
Additional paid-in capital			802,961				432,459
Accumulated other comprehensive income — net			(32,405	)			(51,007	)
Retained earnings			2,646,937				2,342,236
Treasury stock — at cost, 5,783,000 shares in 2017 and 5,921,000 shares in 2016			(313,220	)			(320,348	)
Total Kirby stockholders’ equity			3,110,820				2,409,318
Noncontrolling interests			3,403				3,549
Total equity			3,114,223				2,412,867
Total liabilities and equity		$	5,127,427			$	4,289,895

See accompanying notes to consolidated financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

 

CONSOLIDATED STATEMENTS OF EARNINGS

For the Years Ended December 31, 2017, 2016 and 2015

		2017				2016				2015
		($ in thousands, except per share amounts)
Revenues:
Marine transportation		$	1,324,106			$	1,471,893			$	1,663,090
Distribution and services			890,312				298,780				484,442
Total revenues			2,214,418				1,770,673				2,147,532
Costs and expenses:
Costs of sales and operating expenses			1,557,564				1,126,952				1,362,366
Selling, general and administrative			220,364				174,752				193,237
Taxes, other than on income			29,163				22,730				20,699
Depreciation and amortization			202,881				200,917				192,240
Impairment of long-lived assets			105,712				—				—
Loss (gain) on disposition of assets			4,487				127				(1,672	)
Total costs and expenses			2,120,171				1,525,478				1,766,870
Operating income			94,247				245,195				380,662
Equity in earnings of affiliates			291				532				451
Other expense			(52	)			(291	)			(663	)
Interest expense			(21,472	)			(17,690	)			(18,738	)
Earnings before taxes on income			73,014				227,746				361,712
Benefit (provision) for taxes on income			240,889				(84,942	)			(133,742	)
Net earnings			313,903				142,804				227,970
Less: Net earnings attributable to noncontrolling interests			(716	)			(1,398	)			(1,286	)
Net earnings attributable to Kirby		$	313,187			$	141,406			$	226,684
Net earnings per share attributable to Kirby common stockholders:
Basic		$	5.62			$	2.63			$	4.12
Diluted		$	5.62			$	2.62			$	4.11

See accompanying notes to consolidated financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

 

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

For the Years Ended December 31, 2017, 2016 and 2015

		2017				2016				2015
		($ in thousands)
Net earnings		$	313,903			$	142,804			$	227,970
Other comprehensive income (loss), net of taxes:
Pension and postretirement benefits			18,748				(6,321	)			16,322
Foreign currency translation adjustments			(146	)			—				29
Total other comprehensive income (loss), net of taxes			18,602				(6,321	)			16,351
Total comprehensive income, net of taxes			332,505				136,483				244,321
Net earnings attributable to noncontrolling interests			(716	)			(1,398	)			(1,286	)
Comprehensive income attributable to Kirby		$	331,789			$	135,085			$	243,035

See accompanying notes to consolidated financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

 

CONSOLIDATED STATEMENTS OF CASH FLOWS

For the Years Ended December 31, 2017, 2016 and 2015

		2017				2016				2015
		($ in thousands)
Cash flows from operating activities:
Net earnings		$	313,903			$	142,804			$	227,970
Adjustments to reconcile net earnings to net cash provided by operations:
Depreciation and amortization			202,881				200,917				192,240
Provision (credit) for doubtful accounts			224				(467	)			1,426
Provision (benefit) for deferred income taxes			(256,263	)			51,296				62,755
Loss (gain) on disposition of assets			4,487				127				(1,672	)
Equity in earnings of affiliates, net of distributions and contributions			732				(532	)			449
Impairment of long-lived assets			105,712				—				—
Amortization of unearned share-based compensation			11,460				11,675				11,104
Amortization of major maintenance costs			21,207				19,869				22,126
Amortization of debt issuance costs			986				801				1,377
Increase (decrease) in cash flows resulting from changes in:
Accounts receivable			(60,405	)			(12,750	)			129,908
Inventory			19,673				3,182				(7,320	)
Other assets			(17,049	)			(30,853	)			(15,551	)
Income taxes payable			(11,823	)			15,413				477
Accounts payable			20,758				(1,739	)			(81,808	)
Accrued and other liabilities			(3,105	)			16,051				(19,201	)
Net cash provided by operating activities			353,378				415,794				524,280
Cash flows from investing activities:
Capital expenditures			(177,222	)			(231,066	)			(345,475	)
Acquisitions of businesses and marine equipment, net of cash acquired			(470,101	)			(137,072	)			(41,250	)
Proceeds from disposition of assets			54,229				18,617				24,429
Net cash used in investing activities			(593,094	)			(349,521	)			(362,296	)
Cash flows from financing activities:
Borrowings (payments) on bank credit facilities, net			268,616				(52,848	)			160,784
Payments on long-term debt			(13,721	)			—				(100,000	)
Return of investment to noncontrolling interests			(862	)			(1,976	)			(1,778	)
Proceeds from exercise of stock options			3,039				321				3,712
Purchase of treasury stock			—				(1,827	)			(241,105	)
Payments related to tax withholding for share-based compensation			(2,881	)			(1,756	)			(2,975	)
Acquisitions of noncontrolling interest			(7	)			(8,438	)			—
Excess tax benefit from equity compensation plans			—				—				964
Net cash provided by (used in) financing activities			254,184				(66,524	)			(180,398	)
Increase (decrease) in cash and cash equivalents			14,468				(251	)			(18,414	)
Cash and cash equivalents, beginning of year			5,634				5,885				24,299
Cash and cash equivalents, end of year		$	20,102			$	5,634			$	5,885
Supplemental disclosures of cash flow information:
Cash paid during the period:
Interest paid		$	21,663			$	19,878			$	20,586
Income taxes paid		$	27,196			$	18,162			$	69,584
Capital expenditures included in accounts payable		$	5,525			$	(2,037	)		$	2,206
Non-cash investing activity:
Fair value of property transferred in acquisition		$	—			$	3,681			$	—
Stock issued in acquisition		$	366,554			$	—			$	—
Cash acquired in acquisition		$	98			$	—			$	—
Debt assumed in acquisition		$	13,724			$	—			$	—