Kirby 10Q 2018 Q3 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

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

For the quarterly period ended September 30, 2018

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

Commission File Number 1-7615

KIRBY CORPORATION

(Exact name of registrant as specified in its charter)

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

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

(713) 435-1000

(Registrant’s telephone number, including area code)

No Change

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

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulations S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ☒ No ☐

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

Large accelerated filer	☒	Accelerated filer	☐
Non-accelerated filer	☐	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 number of shares outstanding of the registrant’s Common Stock, $.10 par value per share, on November 2, 2018 was 59,866,000.

PART I – FINANCIAL INFORMATION

Item 1.

Financial Statements

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED BALANCE SHEETS

(Unaudited)

ASSETS

	September 30, 2018			December 31, 2017
	($ in thousands)
Current assets:
Cash and cash equivalents	$	3,617		$	20,102
Accounts receivable:
Trade – less allowance for doubtful accounts		400,870			452,222
Other		111,221			106,231
Inventories – net		453,173			315,729
Prepaid expenses and other current assets		85,639			62,798

Total current assets		1,054,520			957,082

Property and equipment		5,056,335			4,360,882
Less accumulated depreciation		(1,494,835	)		(1,401,617	)
Property and equipment – net		3,561,500			2,959,265

Goodwill		960,006			935,135
Other intangibles – net		228,958			232,808
Other assets		49,348			43,137

Total assets	$	5,854,332		$	5,127,427

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED BALANCE SHEETS

(Unaudited)

LIABILITIES AND STOCKHOLDERS’ EQUITY

	September 30, 2018			December 31, 2017
	($ in thousands)
Current liabilities:
Bank notes payable	$	508		$	3
Income taxes payable		3,765			191
Accounts payable		250,681			222,005
Accrued liabilities		237,129			209,760
Deferred revenues		75,843			48,347

Total current liabilities		567,926			480,306

Long-term debt – less current portion		1,399,423			992,403
Deferred income taxes		544,882			468,451
Other long-term liabilities		108,953			72,044

Total long-term liabilities		2,053,258			1,532,898

Contingencies and commitments		—			—

Equity:
Kirby stockholders’ equity:
Common stock, $.10 par value per share. Authorized 120,000,000 shares, issued 65,472,000 shares		6,547			6,547
Additional paid-in capital		820,805			802,961
Accumulated other comprehensive income – net		(39,544	)		(32,405	)
Retained earnings		2,748,029			2,646,937
Treasury stock – at cost, 5,595,000 shares at September 30, 2018 and 5,783,000 at December 31, 2017		(305,926	)		(313,220	)
Total Kirby stockholders’ equity		3,229,911			3,110,820
Noncontrolling interests		3,237			3,403
Total equity		3,233,148			3,114,223

Total liabilities and equity	$	5,854,332		$	5,127,427

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED STATEMENTS OF EARNINGS

(Unaudited)

	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
	($ in thousands, except per share amounts)
Revenues:
Marine transportation	$	382,040		$	318,810		$	1,100,606		$	993,727
Distribution and services		322,805			222,464			1,148,598			512,580
Total revenues		704,845			541,274			2,249,204			1,506,307

Costs and expenses:
Costs of sales and operating expenses		498,421			378,750			1,640,366			1,048,299
Selling, general and administrative		70,032			51,712			239,416			144,404
Taxes, other than on income		10,523			6,518			29,610			19,511
Depreciation and amortization		57,930			51,206			167,640			147,669
Loss (gain) on disposition of assets		(18	)		159			(2,358	)		199
Total costs and expenses		636,888			488,345			2,074,674			1,360,082

Operating income		67,957			52,929			174,530			146,225
Other income (expense)		1,454			320			4,586			(41	)
Interest expense		(12,345	)		(5,388	)		(34,665	)		(14,310	)

Earnings before taxes on income		57,066			47,861			144,451			131,874
Provision for taxes on income		(15,116	)		(19,072	)		(41,042	)		(49,468	)

Net earnings		41,950			28,789			103,409			82,406
Less: Net earnings attributable to noncontrolling interests		(134	)		(182	)		(520	)		(538	)

Net earnings attributable to Kirby	$	41,816		$	28,607		$	102,889		$	81,868

Net earnings per share attributable to Kirby common stockholders:
Basic	$	0.70		$	0.52		$	1.72		$	1.51
Diluted	$	0.70		$	0.52		$	1.72		$	1.50

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
	($ in thousands)

Net earnings	$	41,950		$	28,789		$	103,409		$	82,406
Other comprehensive income (loss), net of taxes:
Pension and postretirement benefits		438			507			855			15,393
Foreign currency translation adjustments		(60	)		(164	)		(69	)		(164	)
Reclassification to retained earnings of stranded tax effects from tax reform		—			—			(7,925	)		—
Total other comprehensive income (loss), net of taxes		378			343			(7,139	)		15,229

Total comprehensive income, net of taxes		42,328			29,132			96,270			97,635
Net earnings attributable to noncontrolling interests		(134	)		(182	)		(520	)		(538	)

Comprehensive income attributable to Kirby	$	42,194		$	28,950		$	95,750		$	97,097

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine months ended September 30,
	2018			2017
	($ in thousands)
Cash flows from operating activities:
Net earnings	$	103,409		$	82,406
Adjustments to reconcile net earnings to net cash provided by operations:
Depreciation and amortization		167,640			147,669
Provision for deferred income taxes		36,838			32,783
Amortization of unearned share-based compensation		16,649			8,991
Amortization of major maintenance costs		15,600			15,232
Amortization of debt issuance costs		898			786
Other		(2,023	)		180
Decrease in cash flows resulting from changes in operating assets and liabilities, net		(66,707	)		(28,592	)
Net cash provided by operating activities		272,304			259,455

Cash flows from investing activities:
Capital expenditures		(231,752	)		(133,437	)
Acquisitions of businesses and marine equipment, net of cash acquired		(499,227	)		(451,219	)
Proceeds from disposition of assets		27,806			29,743
Net cash used in investing activities		(703,173	)		(554,913	)

Cash flows from financing activities:
Borrowings (payments) on bank credit facilities		(88,392	)		298,424
Borrowings (payments) on long-term debt		499,295			(1,065	)
Payments of debt issue costs		(4,276	)		(1,243	)
Proceeds from exercise of stock options		13,264			2,076
Payments related to tax withholding for share-based compensation		(4,821	)		(2,899	)
Other		(686	)		(643	)
Net cash provided by financing activities		414,384			294,650
Decrease in cash and cash equivalents		(16,485	)		(808	)

Cash and cash equivalents, beginning of year		20,102			5,634
Cash and cash equivalents, end of period	$	3,617		$	4,826

Supplemental disclosures of cash flow information:
Cash paid during the period:
Interest paid	$	37,175		$	18,390
Income taxes	$	495		$	19,388
Capital expenditures included in accounts payable	$	(5,554	)	$	8,917
Non-cash investing activity:
Stock issued in acquisition	$	—		$	366,554
Cash acquired in acquisition	$	2,313		$	98
Debt assumed in acquisition	$	—		$	13,724

See accompanying notes to condensed financial statements.

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES

NOTES TO CONDENSED FINANCIAL STATEMENTS

(Unaudited)

(1)	BASIS FOR PREPARATION OF THE CONDENSED FINANCIAL STATEMENTS

The condensed financial statements included herein have been prepared by Kirby Corporation (the “Company”), without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Although the Company believes that the disclosures are adequate to make the information presented not misleading, certain information and footnote disclosures, including significant accounting policies normally included in annual financial statements, have been condensed or omitted pursuant to such rules and regulations. It is suggested that these condensed financial statements be read in conjunction with the Company’s Annual Report on Form 10-K for the year ended December 31, 2017.

(2)	ACCOUNTING STANDARDS ADOPTIONS

In August 2018, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2018-14, “Compensation – Retirement Benefits - Defined Benefit Plans – General (Subtopic 715-20): Disclosure Framework – Changes to the Disclosure Requirements for Defined Benefit Plans” which amends the annual disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans by removing certain requirements, providing clarification on existing requirements and adding new requirements including adding an explanation of the reasons for significant gains and losses related to changes in the benefit obligation for the period. The guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. Early adoption is permitted. The amendments in this update are required to be applied on a retrospective basis to all periods presented. The Company is currently evaluating this guidance to determine the impact on its disclosures.

In February 2018, the FASB issued ASU 2018-02, “Income Statement – Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income” which allows a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the recent federal tax reform legislation. ASU 2018-02 eliminates the stranded tax effects resulting from the recent federal tax reform legislation and will improve the usefulness of information reported to financial statement users. The amendments in ASU 2018-02 will be applied either in the period of adoption or retrospectively to each period (or periods) in which the effect of the change in the recent federal tax reform legislation is recognized. ASU 2018-02 is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2018. Early adoption is permitted, including adoption in any interim period, for which financial statements have not yet been made available for issuance. The Company elected to early adopt ASU 2018-02 in the 2018 first quarter, which resulted in the reclassification of $7,925,000 from accumulated other comprehensive income (loss) to retained earnings due to the change in the federal corporate tax rate.

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 adopted ASU 2017-07 on January 1, 2018 and applied the standard retrospectively. The other components of net benefit cost are shown in Note 13, Retirement Plans. As a result of the adoption, for the three months and nine months ended September 30, 2017, the Company reclassified income of $433,000 and $189,000, respectively, from operating expense into non-operating expense in the condensed statement of earnings.

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. Early adoption is permitted. The Company adopted ASU 2016-15 on January 1, 2018 and the adoption of the standard did not have a material impact on the consolidated financial statements.

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. The method of adoption may be a modified retrospective approach or an approach that utilizes recognizing a cumulative-effect adjustment to the opening balance of retained earnings as of the date of adoption. 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, including review of practical expedients available. The project team has also selected a software package and continued to load the lease population into the system. The Company has not selected a method of adoption and has not yet determined the effect of ASU 2016-02 on its ongoing financial reporting.

In May 2014, the FASB issued ASU 2014-09, “Revenue from Contracts with Customers (ASC Topic 606)” (“ASU 2014-09” or “ASC 606”). 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 replaces most existing revenue recognition guidance in United States Generally Accepted Accounting Principles and is effective for fiscal years, and interim periods within those years, beginning after December 15, 2017. ASU 2014-09 permits the use of either the retrospective, modified retrospective or prospective with a cumulative catch-up approach. The Company adopted ASU 2014-09 on January 1, 2018 under the modified retrospective approach with a cumulative adjustment that decreased the opening balance of retained earnings by $9,722,000. Prior period amounts were not adjusted and the prior period amounts continue to be reported under the accounting standards in effect for those periods. The cumulative adjustment primarily relates 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 previously recognized 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 recognizes the revenues on contract manufacturing activities upon shipment and transfer of control versus the percentage of completion method.

The following tables summarize the financial statement line items within the Company’s condensed consolidated financial statements impacted by ASU 2014-09 for the three months and nine months ended September 30, 2018 (in thousands):

	Three months ended September 30, 2018
	As Reported			Balances without Adoption of ASC 606			Effect of Change

Statements of earnings:
Distribution and services revenues	$	322,805		$	349,805		$	(27,000	)
Costs of sales and operating expenses	$	498,421		$	520,721		$	(22,300	)
Operating income	$	67,957		$	72,657		$	(4,700	)
Earnings before taxes on income	$	57,066		$	61,766		$	(4,700	)
Provision for taxes on income	$	(15,116	)	$	(16,282	)	$	1,166
Net earnings attributable to Kirby	$	41,816		$	45,350		$	(3,534	)
			��
Statements of comprehensive income:
Net earnings	$	41,950		$	45,484		$	(3,534	)
Comprehensive income attributable to Kirby	$	42,194		$	45,728		$	(3,534	)

	Nine months ended September 30, 2018
	As Reported			Balances without Adoption of ASC 606			Effect of Change

Statements of earnings:
Distribution and services revenues	$	1,148,598		$	1,154,398		$	(5,800	)
Costs of sales and operating expenses	$	1,640,366		$	1,645,166		$	(4,800	)
Operating income	$	174,530		$	175,530		$	(1,000	)
Earnings before taxes on income	$	144,451		$	145,451		$	(1,000	)
Provision for taxes on income	$	(41,042	)	$	(41,295	)	$	253
Net earnings attributable to Kirby	$	102,889		$	103,636		$	(747	)

Statements of comprehensive income:
Net earnings	$	103,409		$	104,156		$	(747	)
Comprehensive income attributable to Kirby	$	95,750		$	96,497		$	(747	)

Statements of cash flows:
Net earnings	$	103,409		$	104,156		$	(747	)
Provision for deferred income taxes	$	36,838		$	36,585		$	253
Decrease in cash flows resulting from changes in operating assets and liabilities, net	$	(66,707	)	$	(67,201	)	$	494

The following table summarizes the balance sheet line items within the Company’s condensed consolidated financial statements as of September 30, 2018 impacted by ASU 2014-09 (in thousands):

	September 30, 2018
	As Reported		Balances without Adoption of ASC 606		Effect of Change
Balance sheets:
Trade receivables	$	400,870	$	466,599	$	(65,729	)
Inventories – net	$	453,173	$	395,773	$	57,400
Total assets	$	5,854,332	$	5,862,661	$	(8,329	)
Deferred revenues	$	75,843	$	70,372	$	5,471
Deferred income taxes	$	544,882	$	548,235	$	(3,353	)
Retained earnings	$	2,748,029	$	2,758,476	$	(10,447	)
Total liabilities and equity	$	5,854,332	$	5,862,661	$	(8,329	)

(3)

REVENUES

The following table sets forth the Company’s revenues by major source for the three months and nine months ended September 30, 2018 and 2017 (in thousands):

	Three months ended September 30,				Nine months ended September 30,
	2018		2017		2018		2017
Marine transportation segment:
Inland transportation	$	288,573	$	220,177	$	827,848	$	681,879
Coastal transportation		93,467		98,633		272,758		311,848
	$	382,040	$	318,810	$	1,100,606	$	993,727
Distribution and services segment:
Oil and gas	$	201,475	$	159,492	$	780,825	$	350,295
Commercial and industrial		121,330		62,972		367,773		162,285
	$	322,805	$	222,464	$	1,148,598	$	512,580

The Company’s revenue is measured based on consideration specified in its contracts with its customers. The Company recognizes revenue as it satisfies performance obligations in its contracts which occur as the Company delivers a service over time to its customers, or transfers control over a part or product to its customer.

Marine Transportation Revenues. The Company’s marine transportation segment utilizes contracts with its customers to transport cargo from a designated origin to a designated destination at a set rate or at a daily rate. The Company uses a voyage accounting method of revenue recognition for its marine transportation revenues which allocates voyage revenue based on the percent of the voyage completed during the period. The performance of the service is invoiced as the transaction occurs and payment is required depending on each specific customer’s credit terms.

Distribution and Services Revenues. Distribution products and services are generally sold based upon purchase orders or preferential service agreements with the customer that include fixed or determinable prices. Parts sales are recognized when control transfers to the customer, generally when title passes upon shipment to customers. Service revenue is recognized over time as the service is provided using measures of progress utilizing hours worked or costs incurred as a percentage of estimated hours or expected costs. Revenue from rental agreements is recognized on a straight-line basis over the rental period. The Company recognizes the revenues on contract manufacturing activities upon shipment and transfer of control to the customer. The transactions in the distribution and services segment are typically invoiced as parts are shipped or upon the completion of the service job. Contract manufacturing activities are generally invoiced upon shipment and the Company will often get deposits from its customers prior to starting work, or progress payments during the project depending on the credit worthiness of the customer and the size of the project.

Prior to the adoption of ASU 2014-09, distribution and services manufacturing and assembly projects revenue was reported on the percentage of completion method of accounting using measurements of progress towards completion appropriate for the work performed. Upon the adoption of ASU 2014-09 on January 1, 2018, the Company recognizes the revenues on contract manufacturing activities upon shipment and transfer of control versus the percentage of completion method.

Contract Assets and Liabilities. Contract liabilities represent advance consideration received from customers, and are recognized as revenue over time as the related performance obligation is satisfied. The amount of revenue recognized in the 2018 first nine months that was included in the opening contract liability balance was $39,492,000. The Company has recognized all contract liabilities within the deferred revenues financial statement caption on the balance sheet. The Company expects to recognize revenue of $35,836,000 in the 2018 fourth quarter and $40,007,000 in 2019 related to deferred revenue as of September 30, 2018. The Company did not have any contract assets at September 30, 2018 or December 31, 2017.

Performance Obligations. The Company applies the practical expedient in ASC 606-10-50-14(a) and does not disclose information about remaining performance obligations that have original expected durations of one year or less.

(4)	ACQUISITIONS

On May 10, 2018, the Company completed the purchase of Targa Resources Corp.’s (“Targa”) inland tank barge business from a subsidiary of Targa for $69,250,000 in cash. Targa’s inland tank barge fleet consisted of 16 pressure barges with a total capacity of 258,000 barrels, many of which were under multi-year contracts that the Company assumed from Targa. The 16 tank barges transport petrochemicals on the Mississippi River System and the Gulf Intracoastal Waterway. As a result of the acquisition, the Company recorded $16,116,000 of goodwill and $11,000,000 of intangibles with an average amortization period of 15 years. The Company expects all of the goodwill to be deductible for tax purposes.

On March 15, 2018, the Company purchased two inland pressure tank barges from a competitor for $10,400,000 in cash. The average age of the two tank barges was five years.

On February 14, 2018, the Company completed the acquisition of Higman Marine, Inc. and its affiliated companies (“Higman”) for $421,922,000 in cash, subject to certain post-closing adjustments. Higman’s fleet consisted of 163 inland tank barges, including two barges to be leased upon completion of their construction in 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. The average age of the inland tank barges was approximately seven years and the inland towboats had an average age of approximately eight years. Financing of the acquisition was through the issuance of $500,000,000 of 4.2% senior unsecured notes due March 1, 2028 (the “2028 Notes”). The 2028 Notes were issued on February 12, 2018 in preparation for closing of the acquisition.

The Company considers Higman to be a natural extension of the current marine transportation segment, expanding the capabilities of the Company’s inland based marine transportation business and lowering the average age of its inland tank barge and towboat fleet.

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

Assets:
Cash	$	2,313
Accounts receivable		27,527
Prepaid expenses and other current assets		5,323
Property and equipment		497,951
Goodwill		8,134
Other assets		31
Total assets	$	541,279

Liabilities:
Accounts payable		17,012
Accrued liabilities		14,127
Deferred income taxes		42,392
Other long-term liabilities		45,826
Total liabilities	$	119,357
Net assets acquired	$	421,922

The analysis of the Higman fair values is substantially complete but all fair values have not been finalized pending obtaining the information necessary to complete the analysis. As additional information becomes known concerning the assets acquired and liabilities assumed, the Company may make adjustments to the opening balance sheet of Higman up to a one year period following the acquisition date.

As a result of the acquisition, the Company recorded $8,134,000 of goodwill of which the majority will be deductible for tax purposes. The Company also incurred $11,100,000 of intangible liabilities related to unfavorable contracts with a weighted average amortization period of approximately 4.9 years. Acquisition related costs of $3,379,000, consisting primarily of legal, audit and other professional fees plus other expenses, were expensed as incurred to selling, general and administrative expense in the 2018 first nine months.

Pro forma results of the acquisitions made in the 2018 first nine months have not been presented as the pro forma revenues, earnings before taxes on income, net earnings and net earnings per share would not be materially different from the Company’s actual results.

(5)	INVENTORIES

The following table presents the details of inventories as of September 30, 2018 and December 31, 2017 (in thousands):

	September 30, 2018		December 31, 2017

Finished goods	$	336,703	$	242,333
Work in process		116,470		73,396
	$	453,173	$	315,729

(6)	FAIR VALUE MEASUREMENTS

The estimated fair value of total debt outstanding at September 30, 2018 and December 31, 2017 was $1,369,932,000 and $984,017,000, respectively, which differs from the carrying amounts of $1,399,931,000 and $992,406,000, respectively, included in the consolidated financial statements. The fair value was determined using an income approach that relies on inputs such as yield curves. Cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities have carrying values that approximate fair value due to the short-term maturity of these financial instruments.

Certain assets are measured at fair value on a nonrecurring basis. These assets are adjusted to fair value when there is evidence of impairment. During the 2017 fourth quarter, the Company reduced certain vessels to fair value due to its decision to put certain older out-of-service vessels up for sale in its marine transportation segment. The fair value of these vessels was $12,550,000 at December 31, 2017, and is presented in prepaid expenses and other current assets.

(7)	LONG-TERM DEBT

On February 12, 2018, the Company issued $500,000,000 of 4.2% senior unsecured notes due March 1, 2028 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 was $11,608,000. The Company received cash proceeds of $495,019,000, net of the original issue discount of $705,000 and debt issuance costs of $4,276,000. 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 were used for the repayment of indebtedness under the Company’s bank credit facilities.

(8)	STOCK AWARD PLANS

The Company has share-based compensation plans which are described below. The compensation cost that has been charged against earnings for the Company’s stock award plans and the income tax benefit recognized in the statement of earnings for stock awards for the three months and nine months ended September 30, 2018 and 2017 were as follows (in thousands):

	Three months ended September 30,				Nine months ended September 30,
	2018		2017		2018		2017
Compensation cost	$	3,098	$	3,067	$	16,649	$	8,991
Income tax benefit	$	709	$	1,234	$	4,747	$	3,386

The Company has an employee stock award plan for selected officers and other key employees which provides for the issuance of stock options, restricted stock awards and performance awards. On February 19, 2018, the employee stock award plan was amended to also allow for the granting of restricted stock units (“RSUs”) to selected officers and other key employees. The amendment included a provision for the continued vesting of unvested stock options and RSUs for employees who meet certain years of service and age requirements at the time of their retirement. The vesting change resulted in shorter expense accrual periods on stock options and RSUs granted after February 19, 2018 to employees who are nearing retirement and meet the service and age requirements.

The exercise price for each option equals the fair market value per share of the Company’s common stock on the date of grant. Substantially all stock options outstanding under the plan have terms of seven years and vest ratably over three years. No performance awards payable in stock have been awarded under the plan. At September 30, 2018, 1,573,527 shares were available for future grants under the employee plan and no outstanding stock options under the employee plan were issued with stock appreciation rights.

The following is a summary of the stock option activity under the employee plan described above for the nine months ended September 30, 2018:

	Outstanding Non- Qualified or Nonincentive Stock Awards			Weighted Average Exercise Price
Outstanding at December 31, 2017		654,655		$	66.45
Granted		115,797		$	75.50
Exercised		(283,886	)	$	67.71
Forfeited		(21,864	)	$	102.42
Outstanding at September 30, 2018		464,702		$	69.85

The following table summarizes information about the Company’s outstanding and exercisable stock options under the employee plan at September 30, 2018:

	Options Outstanding							Options Exercisable
Range of Exercise Prices	Number Outstanding		Weighted Average Remaining Contractual Life in Years		Weighted Average Exercise Price		Aggregate Intrinsic Value	Number Exercisable		Weighted Average Exercise Price		Aggregate Intrinsic Value
$51.23		90,975		4.3	$	51.23			57,438	$	51.23
$64.65 - $68.50		126,260		5.0	$	67.23			41,116	$	67.40
$70.65 - $75.50		207,156		4.7	$	74.56			91,359	$	73.36
$93.64 - $101.46		40,311		2.4	$	95.90			40,311	$	95.90
$51.23 - $101.46		464,702		4.5	$	69.85	$6,312,000		230,224	$	70.72	$3,204,000

The following is a summary of the restricted stock award activity under the employee plan described above for the nine months ended September 30, 2018:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share
Nonvested balance at December 31, 2017		364,121		$	65.84
Vested		(144,240	)	$	72.66
Forfeited		(3,949	)	$	64.68
Nonvested balance at September 30, 2018		215,932		$	64.73

The following is a summary of RSU activity under the employee plan described above for the nine months ended September 30, 2018:

	Unvested RSUs			Weighted Average Grant Date Fair Value Per Unit
Nonvested balance at December 31, 2017		—		$	—
Granted		143,890		$	75.59
Forfeited		(2,105	)	$	75.50
Nonvested balance at September 30, 2018		141,785		$	75.59

The Company has a stock award plan for nonemployee directors of the Company which provides for the issuance of stock options and restricted stock. The director plan provides for automatic grants of restricted stock to nonemployee directors after each annual meeting of stockholders. In addition, the director plan allows for the issuance of stock options or restricted stock in lieu of cash for all or part of the annual director fee at the option of the director. The exercise prices for all options granted under the plan are equal to the fair market value per share of the Company’s common stock on the date of grant. The terms of the options are ten years. The restricted stock issued after each annual meeting of stockholders vests six months after the date of grant. Options granted and restricted stock issued in lieu of cash director fees vest in equal quarterly increments during the year to which they relate. At September 30, 2018, 486,058 shares were available for future grants under the director plan. The director stock award plan is intended as an incentive to attract and retain qualified independent directors.

The following is a summary of the stock option activity under the director plan described above for the nine months ended September 30, 2018:

	Outstanding Non-Qualified or Nonincentive Stock Options			Weighted Average Exercise Price
Outstanding at December 31, 2017		157,617		$	67.54
Granted		2,640		$	85.30
Exercised		(29,153	)	$	57.47
Outstanding at September 30, 2018		131,104		$	70.14

The following table summarizes information about the Company’s outstanding and exercisable stock options under the director plan at September 30, 2018:

	Options Outstanding							Options Exercisable
Range of Exercise Prices	Number Outstanding		Weighted Average Remaining Contractual Life in Years		Weighted Average Exercise Price		Aggregate Intrinsic Value	Number Exercisable		Weighted Average Exercise Price		Aggregate Intrinsic Value
$29.60		6,000		0.6	$	29.60			6,000	$	29.60
$41.24 – $56.45		31,276		2.2	$	50.61			31,276	$	50.61
$61.89 – $62.48		28,000		3.8	$	62.27			28,000	$	62.27
$70.65 – $99.52		65,828		5.4	$	86.45			64,508	$	86.48
$29.60 – $99.52		131,104		4.1	$	70.14	$2,114,000		129,784	$	69.98	$2,114,000

The following is a summary of the restricted stock award activity under the director plan described above for the nine months ended September 30, 2018:

	Unvested Restricted Stock Award Shares			Weighted Average Grant Date Fair Value Per Share

Nonvested balance at December 31, 2017		319		$	70.65
Granted		21,373		$	85.70
Vested		(847	)	$	79.78
Nonvested balance at September 30, 2018		20,845		$	85.71

The total intrinsic value of all stock options exercised under all of the Company’s plans was $6,709,000 and $1,585,000 for the nine months ended September 30, 2018 and 2017, respectively. The actual tax benefit realized for tax deductions from stock option exercises was $1,912,000 and $597,000 for the nine months ended September 30, 2018 and 2017, respectively.

The total intrinsic value of all the restricted stock vestings under all of the Company’s plans was $11,454,000 and $7,046,000 for the nine months ended September 30, 2018 and 2017, respectively. The actual tax benefit realized for tax deductions from restricted stock vestings was $3,264,000 and $2,654,000 for the nine months ended September 30, 2018 and 2017, respectively.

There were no RSU vestings for the nine months ended September 30, 2018.

As of September 30, 2018, there was $2,770,000 of unrecognized compensation cost related to nonvested stock options, $10,296,000 related to nonvested restricted stock awards and $6,227,000 related to nonvested RSUs. The stock options are expected to be recognized over a weighted average period of approximately 1.7 years, restricted stock awards over approximately 2.3 years and RSUs over approximately 4.1 years. The total fair value of options vested was $3,170,000 and $2,511,000 during the nine months ended September 30, 2018 and 2017, respectively. The fair value of the restricted stock vested was $11,454,000 and $7,046,000 for the nine months ended September 30, 2018 and 2017, respectively.

The weighted average per share fair value of stock options granted during the nine months ended September 30, 2018 and 2017 was $23.53 and $20.72, respectively. The fair value of the stock options granted during the nine months ended September 30, 2018 and 2017 was $2,787,000 and $2,616,000, respectively. The Company currently uses treasury stock shares for restricted stock grants and stock option exercises. The fair value of each stock option was determined using the Black-Scholes option pricing model. The key input variables used in valuing the options during the nine months ended September 30, 2018 and 2017 were as follows:

	Nine months ended September 30,
	2018			2017
Dividend yield	None			None
Average risk-free interest rate		2.7	%		2.0	%
Stock price volatility		27	%		27	%
Estimated option term	Six years			Six years

(9)	OTHER COMPREHENSIVE INCOME

The Company’s changes in other comprehensive income for the three months and nine months ended September 30, 2018 and 2017 were as follows (in thousands):

	Three months ended September 30,
	2018									2017
	Gross Amount			Income Tax (Provision) Benefit			Net Amount			Gross Amount			Income Tax (Provision) Benefit			Net Amount
Pension and postretirement benefits (a):
Amortization of net actuarial loss	$	580		$	(142	)	$	438		$	822		$	(315	)	$	507
Foreign currency translation		(60	)		—			(60	)		(164	)		—			(164	)
Total	$	520		$	(142	)	$	378		$	658		$	(315	)	$	343

	Nine months ended September 30,
	2018									2017
	Gross Amount			Income Tax (Provision) Benefit			Net Amount			Gross Amount			Income Tax (Provision) Benefit			Net Amount
Pension and postretirement benefits (a):
Amortization of net actuarial loss	$	1,739		$	(423	)	$	1,316		$	2,939		$	(1,125	)	$	1,814
Actuarial gains (losses)		(609	)		148			(461	)		22,014			(8,435	)		13,579
Adoption of ASU 2018-02 – reclassification to retained earnings		—			(7,925	)		(7,925	)		—			—			—
Foreign currency translation		(69	)		—			(69	)		(164	)		—			(164	)
Total	$	1,061		$	(8,200	)	$	(7,139	)	$	24,789		$	(9,560	)	$	15,229

(a)

Actuarial gains/(losses) are amortized into other income (expense). (See Note 13 – Retirement Plans)

(10)	SEGMENT DATA

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

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

Distribution and Services — Provides after-market services and parts for engines, transmissions, reduction gears and related equipment used in oilfield service, marine, power generation, mining, 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’s two reportable business segments are managed separately based on fundamental differences in their operations. The Company evaluates the performance of its segments based on the contributions to operating income of the respective segments, and before income taxes, interest, gains or losses on disposition of assets, other nonoperating income, noncontrolling interests, accounting changes, and nonrecurring items. Intersegment revenues, based on market-based pricing, of the distribution and services segment from the marine transportation segment of $5,837,000 and $21,757,000 for the three months and nine months ended September 30, 2018, respectively, and $4,967,000 and $15,342,000 for the three months and nine months ended September 30, 2017, respectively, have been eliminated from the tables below. The related intersegment profit of $584,000 and $2,176,000 for the three months and nine months ending September 30, 2018, respectively, and $497,000 and $1,534,000 for the three months and nine months ending September 30, 2017, respectively, have also been eliminated from the tables below.

The following table sets forth the Company’s revenues and profit or loss by reportable segment for the three months and nine months ended September 30, 2018 and 2017 and total assets as of September 30, 2018 and December 31, 2017 (in thousands):

	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
Revenues:
Marine transportation	$	382,040		$	318,810		$	1,100,606		$	993,727
Distribution and services		322,805			222,464			1,148,598			512,580
	$	704,845		$	541,274		$	2,249,204		$	1,506,307
Segment profit (loss):
Marine transportation	$	48,517		$	35,649		$	102,925		$	106,992
Distribution and services		23,914			21,947			101,069			51,983
Other		(15,365	)		(9,735	)		(59,543	)		(27,101	)
	$	57,066		$	47,861		$	144,451		$	131,874

	September 30, 2018		December 31, 2017
Total assets:
Marine transportation	$	4,191,514	$	3,485,099
Distribution and services		1,601,407		1,567,085
Other		61,411		75,243
	$	5,854,332	$	5,127,427

The following table presents the details of “Other” segment loss for the three months and nine months ended September 30, 2018 and 2017 (in thousands):

	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
General corporate expenses	$	(4,492	)	$	(4,508	)	$	(31,822	)	$	(12,551	)
Gain (loss) on disposition of assets		18			(159	)		2,358			(199	)
Interest expense		(12,345	)		(5,388	)		(34,665	)		(14,310	)
Other income (expense)		1,454			320			4,586			(41	)
	$	(15,365	)	$	(9,735	)	$	(59,543	)	$	(27,101	)

General corporate expenses for the nine months ended September 30, 2018 include $18,057,000 of one-time non-deductible expense related to the retirement of the Company’s executive Chairman of the Board of Directors, effective April 30, 2018. He will continue to serve as Chairman of the Board in a non-executive role.

The following table presents the details of “Other” total assets as of September 30, 2018 and December 31, 2017 (in thousands):

	September 30, 2018		December 31, 2017
General corporate assets	$	59,229	$	73,353
Investment in affiliates		2,182		1,890
	$	61,411	$	75,243

(11)	TAXES ON INCOME

Earnings before taxes on income and details of the provision for taxes on income for the three months and nine months ended September 30, 2018 and 2017 were as follows (in thousands):

	Three months ended September 30,					Nine months ended September 30,
	2018			2017		2018			2017
Earnings (loss) before taxes on income:
United States	$	57,980		$	47,861	$	147,506		$	131,874
Foreign		(914	)		—		(3,055	)		—
	$	57,066		$	47,861	$	144,451		$	131,874
Provision for taxes on income:
Federal:
Current	$	—		$	3,617	$	—		$	13,605
Deferred		13,457			14,132		36,350			32,783
State and local:
Current		1,559			1,323		3,965			3,080
Deferred		—			—		488			—
Foreign - current		100			—		239			—
	$	15,116		$	19,072	$	41,042		$	49,468

(12)	EARNINGS PER SHARE

The following table presents the components of basic and diluted earnings per share for the three months and nine months ended September 30, 2018 and 2017 (in thousands, except per share amounts):

	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
Net earnings attributable to Kirby	$	41,816		$	28,607		$	102,889		$	81,868
Undistributed earnings allocated to restricted shares		(166	)		(213	)		(438	)		(599	)
Income available to Kirby common stockholders - basic		41,650			28,394			102,451			81,269
Undistributed earnings allocated to restricted shares		166			213			438			599
Undistributed earnings reallocated to restricted shares		(165	)		(213	)		(437	)		(599	)
Income available to Kirby common stockholders - diluted	$	41,651		$	28,394		$	102,452		$	81,269

Shares outstanding:
Weighted average common stock issued and outstanding		59,875			55,177			59,782			54,364
Weighted average unvested restricted stock		(237	)		(412	)		(255	)		(398	)
Weighted average common stock outstanding - basic		59,638			54,765			59,527			53,966
Dilutive effect of stock options and restricted stock units		146			38			141			55
Weighted average common stock outstanding - diluted		59,784			54,803			59,668			54,021

Net earnings per share attributable to Kirby common stockholders:
Basic	$	0.70		$	0.52		$	1.72		$	1.51
Diluted	$	0.70		$	0.52		$	1.72		$	1.50

Certain outstanding options to purchase approximately 189,000 and 548,000 shares of common stock were excluded in the computation of diluted earnings per share as of September 30, 2018 and 2017, respectively, as such stock options would have been antidilutive.

(13)	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.

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 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 plan’s benefit obligations are based on a variety of demographic and economic assumptions, and the pension plan assets’ returns are subject to various risks, including market and interest rate risk, making an accurate prediction of the pension plan contribution difficult. Based on current pension plan assets and market conditions, the Company does not expect to make a contribution to its pension plan during 2018.

On February 14, 2018, with the acquisition of Higman, the Company assumed Higman’s pension plan for its inland vessel personnel and office staff. On March 27, 2018, the Company amended the Higman pension plan to close it to all new entrants and cease all benefit accruals for periods after May 15, 2018 for all participants. The Company did not incur any one-time charges related to this amendment but the Higman pension plan’s projected benefit obligation decreased by $3,692,000. The Company made a pension contribution to the Higman plan of $6,717,000 in March 2018 to complete all required funding for the 2016 and 2017 years and make its 2018 first quarter contribution. The Company expects to make additional contributions to the Higman pension plan of approximately $1,385,000 in the fourth quarter of 2018 for the 2018 year.

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

The components of net periodic benefit cost for the Company’s defined benefit plans for the three months and nine months ended September 30, 2018 and 2017 were as follows (in thousands):

	Pension Benefits
	Pension Plan						SERP
	Three months ended September 30,						Three months ended September 30,
Components of net periodic benefit cost:	2018			2017			2018		2017
Service cost	$	1,722		$	1,742		$	—	$	—
Interest cost		3,939			3,320			12		14
Expected return on plan assets		(5,696	)		(4,595	)		—		—
Amortization of actuarial loss		723			981			6		7
Net periodic benefit cost	$	688		$	1,448		$	18	$	21

	Pension Benefits
	Pension Plan						SERP
	Nine months ended September 30,						Nine months ended September 30,
Components of net periodic benefit cost:	2018			2017			2018		2017
Service cost	$	5,816		$	8,934		$	—	$	—
Interest cost		11,544			10,409			36		43
Expected return on plan assets		(16,712	)		(13,600	)		—		—
Amortization of actuarial loss		2,168			3,419			18		21
Net periodic benefit cost	$	2,816		$	9,162		$	54	$	64

The components of net periodic benefit cost for the Company’s postretirement benefit plan for the three months and nine months ended September 30, 2018 and 2017 were as follows (in thousands):

	Other Postretirement Benefits						Other Postretirement Benefits
	Postretirement Welfare Plan						Postretirement Welfare Plan
	Three months ended September 30,						Nine months ended September 30,
	2018			2017			2018			2017
Components of net periodic benefit cost:
Service cost	$	—		$	—		$	—		$	—
Interest cost		6			6			18			20
Amortization of actuarial gain		(149	)		(166	)		(447	)		(501	)
Net periodic benefit cost	$	(143	)	$	(160	)	$	(429	)	$	(481	)

(14)	CONTINGENCIES

On October 13, 2016, the tug Nathan E. Stewart and barge DBL 55, an articulated tank barge and tugboat unit (“ATB”), ran aground at the entrance to Seaforth Channel on Atholone Island, British Columbia. The grounding resulted in a breach of a portion of the Nathan E. Stewart’s fuel tanks causing a discharge of diesel fuel into the water. The USCG and the National Transportation Safety Board (“NTSB”) designated the Company as a party of interest in their investigation as to the cause of the incident. The Canadian authorities including Transport Canada and the Canadian Transportation Safety Board investigated the cause of the incident. On October 10, 2018, the Heiltsuk First Nation filed a civil action against a subsidiary of the Company, the master and pilot of the tug, the vessels and the Canadian government seeking unquantified damages as a result of the incident. On the same date, the Canadian government filed charges against the subsidiary and the vessels for violations of the Canadian Fisheries Act, the Migratory Birds Convention Act, the Pilotage Act and the Shipping Act of 2001. The Company is preparing its responses and is unable to estimate the potential exposure in either proceeding. The Company has various insurance policies covering liabilities including pollution, property, marine and general liability and believes that it has satisfactory insurance coverage for the cost of cleanup and salvage operations as well as other potential liabilities arising from the incident. The Company believes it has accrued adequate reserves for the incident and does not expect the incident to have a material adverse effect on its business or financial condition.

On March 22, 2014, two tank barges and a towboat (the M/V Miss Susan), owned by Kirby Inland Marine, LP, a wholly owned subsidiary of the Company, were involved in a collision with the M/S Summer Wind on the Houston Ship Channel near Texas City, Texas. The lead tank barge was damaged in the collision resulting in a discharge of intermediate fuel oil from one of its cargo tanks. The USCG and the NTSB named the Company and the Captain of the M/V Miss Susan, as well as the owner and the pilot of the M/S Summer Wind, as parties of interest in their investigation as to the cause of the incident. Sea Galaxy Ltd is the owner of the M/S Summer Wind. The Company is participating in the natural resource damage assessment and restoration process with federal and state government natural resource trustees. The Company believes it has adequate insurance coverage for pollution, marine and other potential liabilities arising from the incident. The Company believes it has accrued adequate reserves for the incident and does not expect the incident to have a material adverse effect on its business or financial condition.

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

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 $23,719,000 at September 30, 2018, including $8,857,000 in letters of credit and $14,862,000 in performance bonds. All of these instruments have an expiration date within three years. The Company does not believe demand for payment under these instruments is likely and expects no material cash outlays to occur regarding these instruments.

Item 2.

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

Statements contained in this Form 10-Q that are not historical facts, including, but not limited to, any projections contained herein, are forward-looking statements and involve a number of risks and uncertainties. Such statements can be identified by the use of forward-looking terminology such as “may,” “will,” “expect,” “anticipate,” “estimate” or “continue,” or the negative thereof or other variations thereon or comparable terminology. The actual results of the future events described in such forward-looking statements in this Form 10-Q could differ materially from those stated in such forward-looking statements. Among the factors that could cause actual results to differ materially are: adverse economic conditions, industry competition and other competitive factors, adverse weather conditions such as high water, low water, tropical storms, hurricanes, tsunamis, fog and ice, and tornadoes, marine accidents, lock delays, fuel costs, interest rates, construction of new equipment by competitors, government and environmental laws and regulations, and the timing, magnitude and number of acquisitions made by the Company. For a more detailed discussion of factors that could cause actual results to differ from those presented in forward-looking statements, see Item 1A-Risk Factors found in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017. Forward-looking statements are based on currently available information and the Company assumes no obligation to update any such statements.

For purposes of the Management’s Discussion, all net earnings per share attributable to Kirby common stockholders are “diluted earnings per share.” The weighted average number of common shares applicable to diluted earnings per share for the three months and nine months ended September 30, 2018 and 2017 were as follows (in thousands):

	Three months ended September 30,				Nine months ended September 30,
	2018		2017		2018		2017
Weighted average number of common stock - diluted		59,784		54,803		59,668		54,021

The increase in the weighted average number of common shares for the 2018 third quarter and first nine months compared with the 2017 third quarter and first nine months primarily reflected the issuance of 5,696,259 shares of common stock associated with the acquisition of Stewart & Stevenson LLC (“S&S”) on September 13, 2017, and 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 September 30, 2018, the Company operated a fleet of 981 inland tank barges with 21.6 million barrels of capacity, and operated an average of 282 inland towboats. The Company’s coastal fleet consisted of 54 tank barges with 5.1 million barrels of capacity and 50 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 the 2018 third quarter, net earnings attributable to Kirby were $41,816,000, or $0.70 per share, on revenues of $704,845,000, compared with 2017 third quarter net earnings attributable to Kirby of $28,607,000, or $0.52 per share, on revenues of $541,274,000. For the 2018 first nine months, net earnings attributable to Kirby were $102,889,000, or $1.72 per share, on revenues of $2,249,204,000, compared with 2017 first nine months net earnings attributable to Kirby of $81,868,000, or $1.50 per share, on revenues of $1,506,307,000. The 2018 third quarter and first nine months reflected the integration of Targa’s pressure barge fleet, acquired on May 10, 2018, and the integration of Higman, acquired on February 14, 2018. The 2018 second quarter included a one-time non-deductible expense of $18,057,000, or $0.30 per share, related to the retirement of Joseph H. Pyne as executive Chairman of the Board of Directors, effective April 30, 2018. The 2018 first quarter included $3,261,000 before taxes, or $0.04 per share, of one-time transaction costs associated with the Higman acquisition, as well as $2,912,000 before taxes, or $0.04 per share, of severance and retirement expenses, primarily related to cost reduction initiatives in the coastal marine transportation market and the integration of Higman. In addition, the 2018 first quarter included $3,938,000 before taxes, or $0.05 per share, of non-cash expenses related to an amendment to the employee stock award plan. The result of the amendment is shorter expense accrual periods on stock options and RSUs granted after February 19, 2018 to employees who are nearing retirement and meet certain years of service and age requirements. The 2017 third quarter and first nine months were negatively impacted by pre-tax expenses related to the acquisition of S&S of $764,000, or $0.01 per share, and $1,471,000, or $0.02 per share, respectively.

Marine Transportation

For the 2018 third quarter and first nine months, the Company’s marine transportation segment generated 54% and 49%, respectively, of the Company’s revenue. 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 the 2018 third quarter and first nine months increased 20% and 11%, respectively, when compared with the 2017 third quarter and first nine months revenues. The increases were primarily due to the addition of the Higman inland tank barges acquired on February 14, 2018 and the Targa pressure barges acquired on May 10, 2018, and improved barge utilization and spot contract pricing in the inland market. Partially offsetting these increases were lower term and spot contract pricing in the coastal market, weaker average term contract pricing in the inland market in the 2018 first half, poor seasonal weather conditions in the first four months of 2018, and fewer coastal tank barges available with the impairment and retirement of 12 tank barges in the 2017 fourth quarter. The segment’s operating income for the 2018 third quarter increased 36% compared with the 2017 third quarter due to the acquisitions of Higman and Targa’s pressure barge fleet, improved term and spot contract pricing in the inland market, and improved barge utilization in the inland market. The segment’s operating income decreased 4% for the 2018 first nine months compared with the 2017 first nine months primarily due to lower coastal term and spot contract pricing, weaker average inland term contract pricing in the 2018 first half, and poor seasonal weather conditions in the first four months of 2018. The 2018 first nine months were also impacted by the Higman transaction costs, severance and retirement costs, and the amendment to the employee stock award plan; all of which were incurred in the 2018 first quarter and are discussed above. For the 2018 and 2017 third quarters and first nine months, the inland tank barge fleet contributed 76% and 69%, respectively, and the coastal fleet contributed 24% and 31%, respectively, of marine transportation revenues.

Tank barge utilization levels of the Company’s inland marine transportation markets were in the low to mid-90% range during the 2018 third quarter compared with the high 80% to low 90% range during the 2018 second quarter and mid-80% to mid-90% range during the 2017 third quarter. Increasing volumes from petrochemical and black oil customers, lock infrastructure projects in Louisiana as well as on the Ohio River, and refinery turnarounds contributed to increased utilization during the 2018 third quarter compared to the 2018 second quarter. Lower utilization levels in the 2017 third quarter were due to deteriorated operating conditions for the Company’s inland marine transportation markets after Hurricane Harvey made land-fall on the Gulf Coast at the end of August 2017. Unrelated and coinciding infrastructure repairs on the upper Mississippi River further decreased operating efficiency in September 2017.

Coastal tank barge utilization levels were in the 80% range during the 2018 second and third quarters compared with the high 70% range during the 2018 first quarter and low 60% to mid-60% range during the 2017 third quarter. The improvement in utilization in 2018 primarily reflected the impairment and retirement of 12 out-of-service coastal barges during the 2017 fourth quarter. Utilization in the coastal marine fleet continued to be impacted by the oversupply of tank barges in the coastal industry.

During the 2018 third quarter and first nine months, approximately 65% of marine transportation inland revenues were under term contracts and 35% were spot contract revenues. For the 2017 third quarter and first nine months, approximately 75% of inland revenues were under term contracts and 25% were spot contract revenues. Inland time charters during the 2018 third quarter and first nine months represented 58% and 59%, respectively, of the revenues under term contracts compared with 48% in the 2017 third quarter and first nine months. Rates on inland term contracts renewed in the 2018 first quarter decreased in the 4% to 6% average range compared with term contracts renewed in the first quarter of 2017. Rates on inland term contracts renewed in the 2018 second quarter increased in the 1% to 3% average range compared with term contracts renewed in the second quarter of 2017. In the 2018 third quarter, rates on inland term contracts renewed increased in the 3% to 5% average range compared with term contracts renewed in the third quarter of 2017. Spot contract rates increased in the 3% to 5% range in the 2018 third quarter compared to the 2018 second quarter and increased in the 20% to 25% range compared to the 2017 third quarter. Effective January 1, 2018, 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 1.0%, excluding fuel.

During the 2018 and 2017 third quarters and first nine months, approximately 80% of the coastal revenues were under term contracts and 20% were spot contract revenues. Coastal time charters represented approximately 85% of coastal revenues under term contracts during the 2018 and 2017 third quarters and first nine months. Spot contract pricing for the 2018 third quarter was stable compared with pricing for the 2018 first half. Term contract pricing for the 2018 third quarter was modestly higher compared to the 2018 first half. However, compared with the 2017 third quarter and first nine months, both term and spot contract pricing declined in the 10% to 15% range, contingent on various factors including geographic location, vessel capacity, vessel type and product serviced.

The marine transportation operating margin was 12.7% for the 2018 third quarter compared with 11.2% for the 2017 third quarter and 9.4% for the 2018 first nine months compared with 10.8% for the 2017 first nine months.

Distribution and Services

For the 2018 third quarter and first nine months, the distribution and services segment generated 46% and 51%, respectively, of the Company’s revenue. For the 2018 third quarter and first nine months, 40% and 37% of the distribution and services segment revenue was generated from overhauls and service, 39% and 34% from direct parts sales and 21% and 29% from manufacturing, respectively. 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 the 2018 third quarter and first nine months increased 45% and 124%, respectively, when compared with the third quarter and first nine months of 2017. Operating income for the 2018 third quarter and first nine months increased 9% and 94%, respectively, when compared with the third quarter and first nine months of 2017. The higher revenues and operating income were primarily attributable to the acquisition of S&S, completed on September 13, 2017, as well as increased demand in the oil and gas market for the manufacturing of oilfield service equipment, including new pressure pumping units, the sale and distribution of engines and related parts, and improving market conditions in the commercial marine diesel engine repair business, partially offset by lower demand in the 2018 third quarter for new and overhauled transmissions and related parts and remanufactured pressure pumping units from some key oilfield customers. For the 2018 third quarter and first nine months, the oil and gas market contributed 62% and 68%, respectively, of the distribution and services revenues. However, the strong demand challenged the Company’s vendor supply chain throughout 2018, creating delays for the delivery of new engines, transmissions and parts required for the completion of both new and remanufactured oilfield service equipment, including pressure pumping units, and impacted the recognition of revenue. In the commercial and industrial market, which contributed 38% and 32% of the distribution and services revenues for the 2018 third quarter and first nine months, respectively, the marine sector experienced higher service levels for medium-speed diesel engine overhauls and related parts sales throughout the 2018 first nine months. The power generation sector saw increased demand from commercial customers for specialty rental units and back-up power systems in the 2018 second and third quarters in anticipation of and as a result of summer storms after the seasonal decline in the rental of stand-by power generators in the 2018 first quarter. Demand in the nuclear power generation market was stable compared to the 2017 third quarter and first nine months.

The distribution and services segment operating margin for the 2018 third quarter was 7.4% compared with 9.9% for the 2017 third quarter. For the 2018 first nine months, the operating margin was 8.8% compared with 10.1% for the first nine months of 2017.

Cash Flow and Capital Expenditures

Net cash provided by operating activities for the 2018 first nine months was $272,304,000 compared with $259,455,000 for the 2017 first nine months, a 5% increase, primarily due to a $21,003,000 increase in net earnings, a $19,971,000 increase in depreciation and amortization expense, a $7,658,000 increase in unearned compensation expense, and a $4,055,000 increase in deferred income taxes, partially offset by a $38,115,000 net decrease in cash flows resulting from changes in operating assets and liabilities for the 2018 first nine months. The net decrease in cash flows from the change in operating assets and liabilities was primarily due to higher inventories, including work in progress, in the distribution and services oil and gas market during the 2018 first nine months, primarily to support the increased business activity levels, partially offset by a decrease in trade receivables due to a decrease in revenues recognized in the distribution and services oil and gas market in the 2018 third quarter. In addition, during the 2018 and 2017 first nine months, the Company generated cash of $27,806,000 and $29,743,000, respectively, from proceeds from the disposition of assets, and $13,264,000 and $2,076,000, respectively, from proceeds from the exercise of stock options.

For the 2018 first nine months, cash generated and borrowings under the Company’s revolving credit facility were used for capital expenditures of $231,752,000, including $19,111,000 for inland tank barge and towboat construction, $29,910,000 for progress payments on six 5000 horsepower coastal ATB tugboats, $60,338,000 for a 155,000 barrel coastal ATB under construction purchased from a competitor that is scheduled to be delivered in the 2018 fourth quarter, $122,393,000 primarily for upgrading existing marine equipment and marine transportation and distribution and services facilities. The Company also used $499,227,000 for acquisitions of businesses and marine equipment.

The Company’s debt-to-capitalization ratio increased to 30.2% at September 30, 2018 from 24.2% at December 31, 2017, primarily due to borrowings under the 2028 Notes to purchase Higman in the 2018 first quarter and borrowings under the Company’s revolving credit facility for the acquisition of Targa’s pressure barge fleet and the purchase of the 155,000 barrel coastal ATB under construction in the 2018 second quarter, offset by the increase in total equity from net earnings attributable to Kirby for the 2018 first nine months of $102,889,000 and the exercise of stock options and the amortization of unearned equity compensation. As of September 30, 2018, the Company had $406,948,000 outstanding under its Revolving Credit Facility, $500,000,000 of senior notes outstanding and $500,000,000 of the 2028 Notes outstanding, offset by $7,525,000 in unamortized debt discount and issuance costs.

During the 2018 first nine months, the Company took delivery of one new inland tank barge with a capacity of approximately 29,000 barrels, acquired 161 inland tank barges with the Higman acquisition with a total capacity of approximately 4,714,000 barrels, acquired 16 pressure barges from Targa with a total capacity of approximately 258,000 barrels, acquired two inland tank barges with a total capacity of approximately 35,000 barrels, took delivery of a new inland tank barge with a capacity of 26,000 barrels, which is being leased, and retired 41 inland tank barges, reducing its capacity by approximately 736,000 barrels. The net result was an increase of 140 inland tank barges and approximately 4,326,000 barrels of capacity during the first nine months of 2018.

The Company projects that capital expenditures for 2018 will be in the $275,000,000 to $290,000,000 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 ten in 2019 and 2020, progress payments on the construction of six 5000 horsepower coastal ATB tugboats, two of which were placed in service in the 2018 third quarter, one of which will be placed in service in the 2018 fourth quarter and three in 2019, and total payments on a 155,000 barrel coastal ATB under construction that is scheduled to be delivered in the 2018 fourth quarter. 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 $30,000,000, 2018 progress payments on the construction of the six 5000 horsepower coastal ATB tugboats will be approximately $35,000,000 and total payments on the 155,000 barrel coastal ATB will be approximately $65,000,000. Approximately $135,000,000 to $145,000,000 is primarily capital upgrades and improvements to existing marine equipment and facilities. The balance of $10,000,000 to $15,000,000 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 built during 2016 and 2017, many of which were originally built for the movement of crude oil and natural gas condensate, resulted in excess industry-wide tank barge capacity and lower equipment utilization for both the inland and coastal marine transportation markets. This extra capacity placed inland and coastal tank barge utilization and rates under pressure.

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, inland utilization has improved and is anticipated to be in the low to mid-90% range for the fourth quarter of 2018. The 2018 fourth quarter inland utilization will also be helped by continued lock closures and seasonal weather impacts. With utilization in the inland market in the low to mid-90% range in the 2018 third quarter, the high 80% to low 90% range during the 2018 second quarter and the mid-90% level during the 2018 first quarter, which led to improved spot contract pricing during the 2018 first nine months and improved term contract pricing during the 2018 second and third quarters, the Company anticipates term contracts to continue to renew higher in the 2018 fourth quarter.

As of September 30, 2018, the Company estimated there were approximately 3,800 inland tank barges in the industry fleet, of which approximately 400 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, the expectation is that many older tank barges will be removed from service during 2018. The Company estimates that approximately 65 tank barges were ordered during 2017 and 2018 for delivery throughout 2018, three of which are for the Company, and many older tank barges, including an expected 44 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.

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 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. Throughout 2017, the Company released chartered tugboats, idled owned barges and tugboats and reduced headcount accordingly. With additional coastal industry tank barge capacity still under construction with deliveries scheduled for 2018 and 2019, and utilization rates in the mid-60% range, during the 2017 fourth quarter, the Company impaired and retired 12 out-of-service coastal tank barges and 21 inactive coastal tugboats. With its reduced coastal fleet, the Company expects coastal tank barge utilization to be in the 80% range for the 2018 fourth quarter, with a stabilized pricing environment. However, planned shipyards in the 2018 fourth quarter for a few large capacity vessels will negatively impact revenue and profit in the fourth quarter compared to the 2018 third quarter.

As of September 30, 2018, the Company estimated there were approximately 295 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. In June 2018, the Company purchased a 155,000 barrel coastal ATB under construction from a competitor that is scheduled to be delivered to the Company in the 2018 fourth quarter. The Company is aware of three announced coastal tank barge and tugboat units in the 195,000 barrel or less category under construction by competitors for delivery in the 2018 fourth quarter and 2019.

The results of the distribution and services segment are largely influenced by the economic cycles of the land-based oilfield service and oil and gas operator and producer markets, marine, mining, power generation, on-highway and other industrial markets. During 2015 and 2016, lower crude oil prices resulted in a decrease in the number of oil and gas wells being drilled. Oilfield service companies reduced their capital spending, resulting in decreased demand for new parts and equipment, including pressure pumping units, provided by the distribution and services segment. 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 had declined to an estimated 9.0 million. The Company also services offshore supply vessels and offshore drilling rigs operating in the Gulf of Mexico, as well as internationally. Low energy prices also negatively impacted the number of wells drilled in the Gulf of Mexico and international waters. These contributing factors resulted in a negative impact on the distribution and services segment’s revenues and profits in 2015 and 2016.

The United States land rig count improved in 2017 and the 2018 first nine months from the lows in 2016, oil prices traded in the $40 to $75 per barrel range, and service intensity in the well completion business increased. In addition, the condition of the industry’s inactive pressure pumping fleet remains poor. Based on these positive conditions, the Company experienced a better market in 2017 and the first nine months of 2018 and anticipates the trend to continue through the 2018 fourth quarter for the strong demand for pressure pumping unit remanufacturing and this demand is anticipated to generate orders for the manufacture of pressure pumping units and ancillary oilfield service support equipment. However, the strong demand has challenged the Company’s vendor supply chain throughout 2018, creating delays for the delivery of new engines, transmissions and parts required for the completion of both new and remanufactured oilfield service equipment, including pressure pumping units, and impacted the recognition of revenue. Additionally, temporary reductions in oilfield activity is expected to persist in the 2018 fourth quarter and result in lower demand for new and overhauled transmissions. As a result of these dynamics, the Company expects revenues and profits in the distribution and services oil and gas market for the 2018 fourth quarter to be flat to up modestly compared to the 2018 third quarter and reduced as compared to the 2018 first half.

For the distribution and services commercial and industrial market, the Company anticipates the 2018 fourth quarter to be flat to modestly down over the 2018 third quarter, primarily driven by seasonal declines in demand for standby power generation and other specialty equipment rentals following the hurricane season, as well as reduction in sales of refrigeration units following the summer peak.

Acquisitions

On May 10, 2018, the Company completed the purchase of Targa’s inland tank barge business from a subsidiary of Targa for $69,250,000 in cash. Targa’s inland tank barge fleet consisted of 16 pressure barges with a total capacity of 258,000 barrels, many of which were under multi-year contracts that the Company assumed from Targa. The 16 tank barges transport petrochemicals on the Mississippi River System and the Gulf Intracoastal Waterway. Financing of the business acquisition was through borrowings under the Company’s revolving credit facility.

On March 15, 2018, the Company purchased two inland pressure tank barges from a competitor for $10,400,000 in cash. The average age of the two tank barges was five years. Financing of the equipment acquisition was through borrowings under the Company’s revolving credit facility.

On February 14, 2018, the Company completed the acquisition of Higman for $421,922,000 in cash, subject to certain post-closing adjustments. Higman’s fleet consisted of 163 inland tank barges, including two barges to be leased upon completion of their construction in 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. The average age of the inland tank barges was approximately seven years and the inland towboats had an average age of approximately eight years. Financing of the acquisition was through the issuance of $500,000,000 under the 2028 Notes. The 2028 Notes were issued on February 12, 2018 in preparation for closing of the acquisition.

Results of Operations

The Company reported 2018 third quarter net earnings attributable to Kirby of $41,816,000, or $0.70 per share, on revenues of $704,845,000, compared with 2017 third quarter net earnings attributable to Kirby of $28,607,000, or $0.52 per share, on revenues of $541,274,000. Net earnings attributable to Kirby for the 2018 first nine months were $102,889,000, or $1.72 per share, on revenues of $2,249,204,000, compared with $81,868,000, or $1.50 per share, on revenues of $1,506,307,000 for the 2017 first nine months. The 2018 third quarter and first nine months reflected the integration of Targa’s pressure barge fleet, acquired on May 10, 2018, and the integration of Higman, acquired on February 14, 2018. The 2018 second quarter included a one-time non-deductible expense of $18,057,000, or $0.30 per share, related to the retirement of Joseph H. Pyne as executive Chairman of the Board of Directors, effective April 30, 2018. The 2018 first quarter included $3,261,000 before taxes, or $0.04 per share, of one-time transaction costs associated with the Higman acquisition, as well as $2,912,000 before taxes, or $0.04 per share, of severance and retirement expenses, primarily related to cost reduction initiatives in the coastal marine transportation market and the integration of Higman. In addition, the 2018 first quarter included $3,938,000 before taxes, or $0.05 per share, of non-cash expenses related to an amendment to the employee stock award plan. The result of the amendment is shorter expense accrual periods on stock options and RSUs granted after February 19, 2018 to employees who are nearing retirement and meet certain years of service and age requirements. The 2017 third quarter and first nine months were negatively impacted by pre-tax expenses related to the acquisition of S&S of $764,000, or $0.01 per share, and $1,471,000, or $0.02 per share, respectively.

The following table sets forth the Company’s marine transportation and distribution and services revenues for the 2018 third quarter compared with the third quarter of 2017, the first nine months of 2018 compared with the first nine months of 2017 and the percentage of each to total revenues for the comparable periods (dollars in thousands):

	Three months ended September 30,										Nine months ended September 30,
	2018		%			2017		%			2018		%			2017		%
Marine transportation	$	382,040		54	%	$	318,810		59	%	$	1,100,606		49	%	$	993,727		66	%
Distribution and services		322,805		46			222,464		41			1,148,598		51			512,580		34
	$	704,845		100	%	$	541,274		100	%	$	2,249,204		100	%	$	1,506,307		100	%

Marine Transportation

The Company, through its marine transportation segment, is a provider of marine transportation services, operating tank barges and towing vessels transporting bulk liquid products throughout the Mississippi River System, on the Gulf Intracoastal Waterway, coastwise along all three United States coasts and in Alaska and Hawaii. The Company transports petrochemicals, black oil, refined petroleum products and agricultural chemicals by tank barge. As of September 30, 2018, the Company operated 981 inland tank barges, including 32 leased barges, with a total capacity of 21.6 million barrels. This compares with 848 inland tank barges operated as of September 30, 2017, including 31 leased barges, with a total capacity of 17.4 million barrels. The Company operated an average of 282 inland towboats during the 2018 third quarter, of which an average of 75 were chartered, compared with 215 during the 2017 third quarter, of which an average of 59 were chartered. The Company’s coastal tank barge fleet as of September 30, 2018, consisted of 54 tank barges, six of which were leased, with 5.1 million barrels of capacity, and 50 tugboats, four of which were chartered. This compares with 67 coastal tank barges operated as of September 30, 2017, seven of which were leased, with 6.2 million barrels of capacity, and 70 tugboats, five of which were chartered. The Company owns and operates five offshore dry-bulk cargo barges and five offshore tugboats engaged in the offshore transportation of dry-bulk cargoes. 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 Line, L.L.C., 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 months and nine months ended September 30, 2018 compared with the three months and nine months ended September 30, 2017 (dollars in thousands):

	Three months ended September 30,									Nine months ended September 30,
	2018			2017			% Change			2018			2017			% Change
Marine transportation revenues	$	382,040		$	318,810			20	%	$	1,100,606		$	993,727			11	%

Costs and expenses:
Costs of sales and operating expenses		248,347			205,104			21			744,154			652,474			14
Selling, general and administrative		29,408			26,825			10			94,456			82,287			15
Taxes, other than on income		8,624			5,651			53			23,805			17,598			35
Depreciation and amortization		47,144			45,581			3			135,266			134,376			—
		333,523			283,161			18			997,681			886,735			13
Operating income	$	48,517		$	35,649			36	%	$	102,925		$	106,992			(4	)%
Operating margins		12.7	%		11.2	%					9.4	%		10.8	%

Marine Transportation Revenues

The following table shows the marine transportation markets serviced by the Company, the marine transportation revenue distribution for the 2018 third quarter and first nine months, products moved and the drivers of the demand for the products the Company transports:

Markets Serviced	2018 Third Quarter Revenue Distribution		2018 Nine Months Revenue Distribution		Products Moved	Drivers
Petrochemicals		57%		56%	Benzene, Styrene, Methanol, Acrylonitrile, Xylene, Naphtha, Caustic Soda, Butadiene, Propylene	Consumer non-durables – 70%, Consumer durables – 30%

Black Oil		22%		21%	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		18%		19%	Gasoline, No. 2 Oil, Jet Fuel, Heating Oil, Diesel Fuel, Ethanol	Vehicle Usage, Air Travel, Weather Conditions, Refinery Utilization

Agricultural Chemicals		3%		4%	Anhydrous Ammonia, Nitrogen – Based Liquid Fertilizer, Industrial Ammonia	Corn, Cotton and Wheat Production, Chemical Feedstock Usage

Marine transportation revenues for the 2018 third quarter and first nine months increased 20% and 11%, respectively, when compared with the 2017 third quarter and first nine months revenues. The increases were primarily due to the addition of the Higman inland tank barges acquired on February 14, 2018 and the Targa pressure barges acquired on May 10, 2018, and improved barge utilization and spot contract pricing in the inland market. Partially offsetting these increases were lower term and spot contract pricing in the coastal market, weaker average term contract pricing in the inland market in the 2018 first half, poor seasonal weather conditions in the first four months of 2018, and fewer coastal tank barges available with the impairment and retirement of 12 tank barges in the 2017 fourth quarter. Demand in the coastal markets continued to be impacted by the oversupply of tank barges in the coastal industry. For the 2018 and 2017 third quarters and first nine months, the inland tank barge fleet contributed 76% and 69%, respectively, and the coastal fleet contributed 24% and 31%, respectively, of marine transportation revenues. Tank barge utilization levels of the Company’s inland marine transportation markets were in the low to mid-90% range in the 2018 third quarter compared with the high 80% to low 90% range during the 2018 second quarter and mid-80% to mid-90% range during the 2017 third quarter. Increasing volumes from petrochemical and black oil customers, lock infrastructure projects in Louisiana as well as on the Ohio River, and refinery turnarounds contributed to increased utilization during the 2018 third quarter compared to the 2018 second quarter. Lower utilization levels in the 2017 third quarter were due to deteriorated operating conditions for the Company’s inland marine transportation markets after Hurricane Harvey made land-fall on the Gulf Coast at the end of August 2017. Unrelated and coinciding infrastructure repairs on the upper Mississippi River further decreased operating efficiency in September 2017. Coastal tank barge utilization levels were in the 80% range during the 2018 second and third quarters compared with the high 70% range during the 2018 first quarter and low 60% to mid-60% range during the 2017 third quarter. The coastal utilization improvement in 2018 was primarily due to the impairment and retirement of 12 coastal tank barges in the 2017 fourth quarter.

The petrochemical market, the Company’s largest market, contributed 57% and 56%, of marine transportation revenues for the 2018 third quarter and first nine months, respectively, reflecting stable volumes from Gulf Coast petrochemical plants for both domestic consumption and to terminals for export destinations, the addition of the Targa pressure barges in May 2018 and the addition of tank barges acquired 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 during 2017 and the 2018 first nine months benefited the market.

The black oil market, which contributed 22% and 21% of marine transportation revenues for the 2018 third quarter and first nine months, respectively, reflected higher revenues in the inland market primarily due to the addition of the Higman fleet. 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. Revenues for the transportation of black oil products in the coastal market during the 2018 third quarter and first nine months were lower compared with the 2017 third quarter and first nine months due to the continued industry-wide over supply of tank barges in the coastal industry.

The refined petroleum products market, which contributed 18% and 19% of marine transportation revenues for the 2018 third quarter and first nine months, respectively, reflected stronger volumes in the inland market primarily due to the addition of the Higman fleet, partially offset by lower utilization in the coastal market, primarily a result of the oversupply of coastal tank barge capacity.

The agricultural chemical market, which contributed 3% and 4% of marine transportation revenues for the 2018 third quarter and first nine months, respectively, saw typical seasonal demand for transportation of both domestically produced and imported products during the 2018 first nine months.

For the third quarter of 2018, the inland operations incurred 2,534 delay days, 29% more than the 1,965 delay days that occurred during the 2017 third quarter and 46% more than the 1,735 delay days that occurred during the 2018 second quarter. For the first nine months of 2018, 6,797 delay days occurred, 21% more than the 5,599 delay days that occurred during the 2017 first nine months. Delay days measure the lost time incurred by a tow (towboat and one or more tank barges) during transit when the tow is stopped due to weather, lock conditions or other navigational factors. The increase in delay days for the 2018 third quarter compared to the 2017 third quarter and the 2018 second quarter reflected lost time incurred due to periodic closures at two locks in Louisiana as well as one on the Ohio River during the 2018 third quarter. The increase in delay days for the 2018 first nine months compared to the 2017 first nine months reflected the lock infrastructure projects in the 2018 third quarter and the challenging operating conditions in the 2018 first quarter due to ice on the Illinois River, infrastructure issues on the Ohio River, seasonal fog and high winds, as well as lock delays along the Gulf Intracoastal Waterway. High water conditions on the Ohio and Mississippi Rivers in the first four months of 2018 also increased delay days.

During the 2018 third quarter and first nine months, approximately 65% of marine transportation inland revenues were under term contracts 35% were spot contract revenues. For the 2017 third quarter and first nine months, approximately 75% of inland revenues were under term contracts and 25% were spot contract revenues. Inland time charters during the 2018 third quarter and first nine months represented 58% and 59%, respectively, of the revenues under term contracts compared with 48% in the 2017 third quarter and first nine months. Rates on inland term contracts renewed in the 2018 first quarter decreased in the 4% to 6% average range compared with term contracts renewed in the first quarter of 2017. Rates on inland term contracts renewed in the 2018 second quarter increased in the 1% to 3% average range compared with term contracts renewed in the second quarter of 2017. In the 2018 third quarter, rates on inland term contracts renewed increased in the 3% to 5% average range compared with term contracts renewed in the third quarter of 2017. Spot contract rates increased in the 3% to 5% range in the 2018 third quarter compared to the 2018 second quarter and increased in the 20% to 25% range compared to the 2017 third quarter. Effective January 1, 2018, 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 1.0%, excluding fuel.

Marine Transportation Costs and Expenses

Costs and expenses for the 2018 third quarter and first nine months increased 18% and 13%, respectively, when compared with the 2017 third quarter and first nine months. Costs of sales and operating expenses for the 2018 third quarter and first nine months increased 21% and 14%, respectively, compared with the 2017 third quarter and first nine months, primarily due to the addition of the Higman fleet of inland tank barges and towboats in February 2018 and higher fuel costs.

The inland marine transportation fleet operated an average of 282 towboats during the 2018 second quarter, of which an average of 75 were chartered, compared with 215 during the 2017 third quarter, of which an average of 59 were chartered. During the 2018 first nine months, the inland operations operated an average of 275 towboats, of which an average of 73 towboats were chartered, compared with 224 towboats operated during the 2017 first nine months, of which an average of 68 were chartered. The increase was primarily due to the addition of inland towboats with the Higman acquisition on February 14, 2018. Generally 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, the Company charters in or releases chartered towboats in an effort to balance horsepower needs with current requirements. The Company has historically used chartered towboats for approximately one-third of its horsepower requirements.

During the 2018 third quarter, the inland operations consumed 12.9 million gallons of diesel fuel compared to 9.5 million gallons consumed during the 2017 third quarter, driven by the Higman acquisition. The average price per gallon of diesel fuel consumed during the 2018 third quarter was $2.23 per gallon compared with $1.61 per gallon for the 2017 third quarter. For the 2018 first nine months, the inland operations consumed 36.8 million gallons of diesel fuel compared to 30.0 million gallons consumed during the 2017 first nine months, driven by the Higman acquisition. The average price per gallon of diesel fuel consumed during the 2018 first nine months was $2.13 compared with $1.71 for the 2017 first nine months. Fuel escalation and de-escalation clauses on term contracts are designed to rebate fuel costs when prices decline and recover additional fuel costs when fuel prices rise; however, there is generally a 30 to 90 day delay before the contracts are adjusted. Spot contracts do not have escalators for fuel.

Selling, general and administrative expenses for the 2018 third quarter increased 10% compared with the 2017 third quarter, primarily due to the addition of Higman personnel and related expenses plus higher incentive compensation accruals. For the 2018 first nine months, selling, general and administrative expenses increased 15% compared with the 2017 first nine months. The increase included $3,261,000 of transaction costs, consisting primarily of legal, audit and other professional fees associated with the Higman acquisition, severance charges of $2,591,000 associated with the integration of Higman into the Company and further reduction in headcount in the coastal sector in order to manage costs, and $2,378,000 of non-cash expenses related to the amendment of the employee stock award plan; all of which were incurred in the 2018 first quarter.

Taxes, other than on income for the 2018 third quarter and first nine months increased 53% and 35%, respectively, compared with the 2017 third quarter and first nine months, mainly due to higher property taxes on marine transportation equipment, including the Higman and Targa fleets, and higher waterway use taxes due to higher business activity levels, mainly due to the Higman acquisition.

Marine Transportation Operating Income and Operating Margins

Marine transportation operating income for the 2018 third quarter increased 36% compared with the 2017 third quarter and decreased 4% for the 2018 first nine months compared with the 2017 first nine months. The operating margin was 12.7% for the 2018 third quarter compared with 11.2% for the 2017 third quarter and 9.4% for the 2018 first nine months compared with 10.8% for the 2017 first nine months. The operating income increase in the 2018 third quarter, compared to the 2017 third quarter, was primarily due to the acquisitions of Higman and Targa’s pressure barge fleet, improved term and spot contract pricing in the inland market, and improved barge utilization in the inland market. The operating income decrease in the 2018 first nine months, compared with the 2017 first nine months, was primarily due to lower coastal term and spot contract pricing, weaker average inland term contract pricing in the 2018 first half, and poor seasonal weather conditions in the first four months of 2018. Higman transaction costs, severance and retirement charges, and expenses related to the amendment of the employee stock award plan also negatively impacted the 2018 first quarter.

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 months and nine months ended September 30, 2018 compared with the three months and nine months ended September 30, 2017 (dollars in thousands):

	Three months ended September 30,									Nine months ended September 30,
	2018			2017			% Change			2018			2017			% Change
Distribution and services revenues	$	322,805		$	222,464			45	%	$	1,148,598		$	512,580			124	%

Costs and expenses:
Costs of sales and operating expenses		250,074			173,646			44			896,212			395,825			126
Selling, general and administrative		36,965			21,242			74			115,682			52,336			121
Taxes, other than on income		1,888			856			121			5,762			1,879			207
Depreciation and amortization		9,964			4,773			109			29,873			10,557			183
		298,891			200,517			49			1,047,529			460,597			127
Operating income	$	23,914		$	21,947			9	%	$	101,069		$	51,983			94	%
Operating margins		7.4	%		9.9	%					8.8	%		10.1	%

Distribution and Services Revenues

The following table shows the markets serviced by the Company’s distribution and services segment, the revenue distribution for the 2018 third quarter and first nine months, and the customers for each market:

Markets Serviced	2018 Third Quarter Revenue Distribution		2018 Nine Months Revenue Distribution		Customers
Oil and Gas		62%		68%	Oilfield Services, Oil and Gas Operators and Producers

Commercial and Industrial		38%		32%	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

Distribution and services revenues for the 2018 third quarter and first nine months increased 45% and 124%, respectively, when compared with the third quarter and first nine months of 2017. The higher revenues and operating income were primarily attributable to the acquisition of S&S, completed on September 13, 2017, as well as increased demand in the oil and gas market for the manufacturing of oilfield service equipment, including new pressure pumping units, the sale and distribution of engines and related parts, and improving market conditions in the commercial marine diesel engine repair business, partially offset by reduced demand in the 2018 third quarter for new and overhauled transmissions and related parts and remanufactured pressure pumping units from some key oilfield customers. For the 2018 third quarter and first nine months, the oil and gas market contributed 62% and 68%, respectively, of the distribution and services revenues. However, the strong demand challenged the Company’s vendor supply chain throughout 2018, creating delays for the delivery of new engines, transmissions and parts required for the completion of both new and remanufactured oilfield service equipment, including pressure pumping units, and impacted the recognition of revenue. In the commercial and industrial market, which contributed 38% and 32% of the distribution and services revenues for the 2018 third quarter and first nine months, respectively, the marine sector experienced higher service levels for medium-speed diesel engine overhauls and related parts sales throughout the 2018 first nine months. The power generation sector saw increased demand from commercial customers for specialty rental units and back-up power systems in the 2018 second and third quarters in anticipation of and as a result of summer storms after the seasonal decline in the rental of stand-by power generators in the 2018 first quarter. Demand in the nuclear power generation market was stable compared to the 2017 third quarter and first nine months.

Distribution and Services Costs and Expenses

Costs and expenses for the 2018 third quarter and first nine months increased 49% and 127%, respectively, compared with the 2017 third quarter and first nine months. Costs of sales and operating expenses for the 2018 third quarter and first nine months increased 44% and 126%, respectively, compared with the 2017 third quarter and first nine months, reflecting the acquisition of S&S on September 13, 2017, as well as increased demand for the remanufacture of pressure pumping units and transmission overhauls, improvement in the manufacturing of oilfield service equipment, including pressure pumping units, and an increase in demand for the sale and distribution of engines, transmissions and related parts in the oil and gas market.

Selling, general and administrative expenses for the 2018 third quarter and first nine months increased 74% and 121%, respectively, compared with the 2017 third quarter and first nine months, primarily due to the S&S acquisition, as well as increased activity in the oil and gas market. The 2018 first nine months included a $171,000 severance charge incurred in the 2018 first quarter associated with the integration of S&S into the Company and $1,168,000 of non-cash expenses, also incurred in the 2018 first quarter, related to the amendment of the employee stock award plan.

Distribution and Services Operating Income and Operating Margins

Operating income for the distribution and services segment for the 2017 third quarter and first nine months increased 9% and 94%, respectively, compared with the 2017 third quarter and first nine months. The operating margin for the 2018 third quarter was 7.4% compared with 9.9% for the 2017 third quarter and 8.8% for the 2018 first nine months compared with 10.1% for the 2017 first nine months. The results primarily reflected the earnings contribution of S&S and continued strong demand for the remanufacture of pressure pumping units and transmission overhauls, the manufacturing of oilfield service equipment, and the sale of new transmissions and related parts.

General Corporate Expenses

General corporate expenses for the 2018 third quarter were $4,492,000 compared with $4,508,000 for the 2017 third quarter. For the 2018 first nine months, general corporate expenses were $31,822,000, a 154% increase compared with $12,551,000 for the 2017 first nine months, primarily due to a one-time non-deductible expense of $18,057,000 in the 2018 second quarter related to the retirement of the Company’s executive Chairman, effective April 30, 2018, and higher incentive compensation accruals. The Company's retired executive Chairman continues to serve as Chairman of the Board in a non-executive role. The 2018 first nine months included $392,000 incurred in the 2018 first quarter due to the corporate portion of the amendment of the employee stock award plan.

Gain (Loss) on Disposition of Assets

The Company reported a net gain on disposition of assets of $18,000 for the 2018 third quarter compared with a net loss of $159,000 for the 2017 third quarter. For the 2018 first nine months, the Company reported a net gain on disposition of assets of $2,358,000 compared with a net loss of $199,000 for the 2017 first nine months. The net gains and losses were predominantly from the sale or retirement of marine equipment and the sale of distribution and services’ properties.

Other Income and Expenses

The following table sets forth other income (expense), noncontrolling interests and interest expense for the three months and nine months ended September 30, 2018 compared with the three months and nine months ended September 30, 2017 (dollars in thousands):

	Three months ended September 30,									Nine months ended September 30,
							%									%
	2018			2017			Change			2018			2017			Change
Other income (expense)	$	1,454		$	320			354	%	$	4,586		$	(41	)		n/a
Noncontrolling interests	$	(134	)	$	(182	)		(26	)%	$	(520	)	$	(538	)		(3	)%
Interest expense	$	(12,345	)	$	(5,388	)		129	%	$	(34,665	)	$	(14,310	)		142	%

Other Income (Expense)

Due to the Company’s adoption of ASU 2017-07 on January 1, 2018, other income for the 2018 third quarter and first nine months includes income of $1,159,000 and $3,375,000, respectively, for all components of net benefit costs except the service cost component related to the Company’s defined benefit plans. The standard was applied retrospectively resulting in a reclassification of income for the three months and nine months ended September 30, 2017 of $433,000 and $189,000, respectively, from operating expense to non-operating expense.

Interest Expense

Interest expense for the 2018 third quarter and first nine months increased 129% and 142%, respectively, compared with the 2017 third quarter and first nine months, primarily due to borrowings to finance the cash portion of the S&S acquisition in September 2017, the Higman acquisition in February 2018, the acquisition of Targa’s pressure barge fleet in May 2018 and the purchase of the 155,000 barrel coastal ATB under construction in June 2018. During the 2018 and 2017 third quarters, the average debt and average interest rate (excluding capitalized interest) were $1,421,613,000 and 3.6%, and $724,389,000 and 3.0%, respectively. For the first nine months of 2018 and 2017, the average debt and average interest rate (excluding capitalized interest) were $1,366,546,000 and 3.5%, and $691,374,000 and 3.0%, respectively. Interest expense excludes capitalized interest for the 2018 and 2017 third quarters of $808,000 and $208,000, respectively, and for the 2018 and 2017 first nine months of $1,317,000 and $1,522,000, respectively.

Financial Condition, Capital Resources and Liquidity

Balance Sheet

Total assets as of September 30, 2018 were $5,854,332,000 compared with $5,127,427,000 as of December 31, 2017. The following table sets forth the significant components of the balance sheet as of September 30, 2018 compared with December 31, 2017 (dollars in thousands):

	September 30, 2018		December 31, 2017		% Change
Assets:
Current assets	$	1,054,520	$	957,082		10	%
Property and equipment, net		3,561,500		2,959,265		20
Goodwill		960,006		935,135		3
Other intangibles, net		228,958		232,808		(2	)
Other assets		49,348		43,137		14
	$	5,854,332	$	5,127,427		14	%
Liabilities and stockholders’ equity:
Current liabilities	$	567,926	$	480,306		18	%
Long-term debt – less current portion		1,399,423		992,403		41
Deferred income taxes		544,882		468,451		16
Other long-term liabilities		108,953		72,044		51
Total equity		3,233,148		3,114,223		4
	$	5,854,332	$	5,127,427		14	%

Current assets as of September 30, 2018 increased 10% compared with December 31, 2017. Inventories, net, increased 44%, primarily reflecting higher inventories, including work in progress, in the distribution and services oil and gas market due to the adoption of ASU 2014-09 and to meet current business activity levels. Prepaid expenses and other current assets increased 36% primarily due to a building acquired with the Higman acquisition being reclassified to assets held for sale, partially offset by the sale of marine vessels in the 2018 first nine months that were classified as assets held for sale in the 2017 fourth quarter. Trade accounts receivable decreased 11%, primarily reflecting decreased business activity levels in the distribution and services oil and gas market and lower revenue recognized due to the adoption of ASU 2014-09.

Property and equipment, net of accumulated depreciation, at September 30, 2018 increased 20% compared with December 31, 2017. The increase reflected $237,306,000 of capital expenditures for the 2018 first nine months, more fully described under Capital Expenditures Reflected on the Balance Sheet below, the fair value of the property and equipment acquired in the Higman acquisition of $480,451,000, the two inland pressure tank barges purchased in March 2018 of $10,400,000 and the fair value of the property acquired in the Targa acquisition of $42,134,000, less $155,656,000 of depreciation expense and $20,070,000 of property disposals during the 2018 first nine months.

Goodwill as of September 30, 2018 increased 3% compared with December 31, 2017, predominantly reflecting the goodwill recorded in the Higman and Targa acquisitions.

Other intangibles, net, as of September 30, 2018 decreased 2% compared with December 31, 2017, reflecting intangible assets other than goodwill recorded in the Targa acquisition, less amortization of $14,851,000.

Other assets at September 30, 2018 increased 14% compared with December 31, 2017 primarily due to the addition of deferred major maintenance dry-dock expenditures on ocean-going vessels, net of amortization.

Current liabilities as of September 30, 2018 increased 18% compared with December 31, 2017. Accounts payable increased 13%, primarily due to increased business activity levels in the distribution and services segment, the acquisition of Higman and higher accrued capital expenditures. Accrued liabilities increased 13% primarily due to accrued liabilities assumed in the Higman acquisition including an increase in taxes other than on income, primarily waterway use taxes and property taxes, and an increase in insurance claims payable, partially offset by payments during the 2018 first nine months of employee incentive compensation accrued during 2017. Deferred revenues increased 57%, primarily in the distribution and services segment, reflecting changes in revenue recognition with the adoption of ASU 2014-09.

Long-term debt, less current portion, as of September 30, 2018 increased 41% compared with December 31, 2017, primarily reflecting the issuance on February 12, 2018 of $500,000,000 under the 2028 Notes to fund the acquisition of Higman, partially offset by payments of $88,392,000 on the revolving credit facilities during the 2018 first nine months. Net debt discount and deferred issuance costs were $7,525,000 and $3,442,000 at September 30, 2018 and December 31, 2017, respectively.

Deferred income taxes as of September 30, 2018 increased 16% compared with December 31, 2017, primarily reflecting $42,392,000 of deferred income taxes recorded with the Higman acquisition and the 2018 first nine months deferred tax provision of $36,838,000.

Other long-term liabilities as of September 30, 2018 increased 51% compared with December 31, 2017. The increase was primarily due to $11,100,000 of intangible liabilities related to unfavorable contracts of the Higman acquisition and the pension plan liability assumed with the Higman acquisition of $34,726,000, partially offset by a $6,717,000 contribution to the Higman pension plan during the 2018 first quarter.

Total equity as of September 30, 2018 increased 4% compared with December 31, 2017. The increase was primarily the result of $102,889,000 of net earnings attributable to Kirby for the first nine months of 2018, an increase in additional paid-in capital of $17,844,000, primarily due to the employee stock award plan amendment which resulted in shorter expense accrual periods on stock options and RSUs granted after February 19, 2018 to employees who are nearing retirement and meet certain years of service and age requirements, a $7,294,000 increase in treasury stock and a $9,722,000 decrease in the opening balance of retained earnings with the adoption of ASU 2014-09.

Long-Term Financing

On February 12, 2018, the Company issued $500,000,000 of 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 was $11,608,000. The Company received cash proceeds of $495,019,000, net of the original issue discount of $705,000 and debt issuance costs of $4,276,000. 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 were used for the repayment of indebtedness under the Company’s bank credit facilities. As of September 30, 2018, the Company was in compliance with all the 2028 Notes covenants and had $500,000,000 outstanding under the 2028 Notes.

The Company has an $850,000,000 unsecured revolving credit facility (“Revolving Credit Facility”) with a syndicate of banks, with JPMorgan Chase Bank, N.A. as the administrative agent bank, with a maturity date of 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, effective February 20, 2018, due to a change in one of the Company’s credit ratings, the spread over LIBOR increased from 1.00% to 1.125% and the Alternate Base Rate spread is currently 0.125% over the agent bank’s prime rate. The commitment fee increased as well from 0.10% to 0.15%. The Revolving Credit Facility contains certain restrictive financial covenants including an interest coverage ratio and a debt-to-capitalization ratio. In addition to financial covenants, the Revolving Credit Facility contains covenants that, subject to exceptions, restrict debt incurrence, mergers and acquisitions, sales of assets, dividends and investments, liquidations and dissolutions, capital leases, transactions with affiliates and changes in lines of business. Borrowings under the Revolving Credit Facility may be used for general corporate purposes, the purchase of existing or new equipment, the purchase of the Company’s common stock, or for business acquisitions. As of September 30, 2018, the Company was in compliance with all Revolving Credit Facility covenants and had $406,948,000 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 $7,436,000 as of September 30, 2018.

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, 2018, 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 September 30, 2018. Outstanding letters of credit under the Credit Line were $1,201,000 as of September 30, 2018.

Capital Expenditures Reflected on the Balance Sheet

Capital expenditures for the 2018 first nine months were $237,306,000, including $19,111,000 for inland tank barge and towboat construction, $29,910,000 for progress payments on six 5000 horsepower coastal ATB tugboats, $60,338,000 for a 155,000 barrel coastal ATB under construction purchased from a competitor that is scheduled to be delivered in the 2018 fourth quarter, and $127,947,000 primarily for upgrading existing marine equipment and marine transportation and distribution and services facilities.

Financing of the construction of the inland tank barge and towboats, coastal tugboats and the 155,000 barrel coastal ATB, plus upgrades of existing marine equipment and marine transportation and distribution and services facilities was through operating cash flows and available credit under the Company’s Revolving Credit Facility.

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

During October 2018, the Company purchased 11,000 shares of its common stock for $776,000, for an average price of $69.61 per share pursuant to a stock trading plan entered into with a brokerage firm pursuant to Rule 10b5-1 under the Securities Exchange Act of 1934 (“Exchange Act”). As of November 2, 2018, the Company had approximately 1,400,000 shares available under its existing repurchase authorization. Historically, treasury stock purchases have been financed through operating cash flows and borrowing under the Company’s Revolving Credit Facility. The Company is authorized to purchase its common stock on the New York Stock Exchange and in privately negotiated transactions. When purchasing its common stock, the Company is subject to price, trading volume and other market considerations. Shares purchased may be used for reissuance upon the exercise of stock options or the granting of other forms of incentive compensation, in future acquisitions for stock or for other appropriate corporate purposes.

Liquidity

The Company generated net cash provided by operating activities of $272,304,000 for the 2018 first nine months compared with $259,455,000 for the 2017 first nine months. The 2018 first nine months experienced a net decrease in cash flows from changes in operating assets and liabilities of $66,707,000 compared with a net decrease in the 2017 first nine months of $28,592,000. The net decrease in cash flows from the change in operating assets and liabilities was primarily due to higher inventories, including work in progress, in the distribution and services oil and gas market during the 2018 first nine months, primarily to support the increased business activity levels, partially offset by a decrease in trade receivables due to a decrease in revenues recognized in the distribution and services oil and gas market in the 2018 third quarter.

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 November 2, 2018, $475,520,000 under its Revolving Credit Facility and $8,799,000 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 the pricing grid 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 September 30, 2018, the Company had $435,616,000 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, in the financial statements, and Item 1A — Risk Factors and Note 14, Contingencies and Commitments, in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017. Amounts available under the Company’s existing financial arrangements are subject to the Company continuing to meet the covenants of the credit facilities as described in Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations under Long-Term Financing.

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.

Item 3.

Quantitative and Qualitative Disclosures about Market Risk

The Company is exposed to risk from changes in interest rates on certain of its outstanding debt. The outstanding loan balances under the Company’s bank credit facilities bear interest at variable rates based on prevailing short-term interest rates in the United States and Europe. A 10% change in variable interest rates would impact the 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 4.

Controls and Procedures

The Company’s management, with the participation of the Chief Executive Officer and the Chief Financial Officer, has evaluated the Company’s disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act), as of September 30, 2018, 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 September 30, 2018, 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. There were no changes in the Company’s internal control over financial reporting during the quarter ended September 30, 2018 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

PART II – OTHER INFORMATION

Item 1.

Legal Proceedings

The Company has previously disclosed an incident involving the grounding on October 13, 2016 of the tug Nathan E. Stewart and the barge DBL 55 at the entrance to the Seaforth Channel on Atholone Island, British Columbia that resulted in a discharge of diesel fuel into the water. On October 10, 2018, the Heiltsuk First Nation filed a civil action in the Supreme Court of British Columbia, Vancouver Registry, against a subsidiary of the Company, the master and pilot of the tug, the vessels and the Canadian government seeking unquantified damages as a result of the incident. On the same date, the Canadian government filed charges in British Columbia Provincial Court (Vancouver) against the subsidiary and the vessels for violations of the Canadian Fisheries Act, the Migratory Birds Convention Act, the Pilotage Act and the Shipping Act of 2001. The Company is preparing its responses and is unable to estimate the potential exposure in either proceeding. The Company has various insurance policies covering liabilities including pollution, property, marine and general liability and believes that it has satisfactory insurance coverage for the cost of cleanup and salvage operations as well as other potential liabilities arising from the incident. The Company believes it has accrued adequate reserves for the incident and does not expect the incident to have a material adverse effect on its business or financial condition.

Item 1A.

Risk Factors

The Company continues to be subject to the risk factors previously disclosed in its “Risk Factors” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017.

Item 6.

Exhibits

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

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

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	KIRBY CORPORATION
	(Registrant)

	By:	/s/ WILLIAM G. HARVEY
		William G. Harvey
		Executive Vice President and
		Chief Financial Officer

Dated: November 5, 2018

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Kirby (KEX) 10-Q2018 Q3 Quarterly report

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