10-Q 1 form10q.htm KIRBY CORPORATION 10-Q 3-31-2013 form10q.htm


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Form 10-Q

 
x
Quarterly report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
 
For the quarterly period ended March 31, 2013
 
¨
Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
 
Commission File Number 1-7615

KIRBY CORPORATION
(Exact name of registrant as specified in its charter) 

 
Nevada
 
74-1884980
(State or other jurisdiction of incorporation or organization)
 
(IRS Employer Identification No.)
 
 
 
55 Waugh Drive, Suite 1000,
 
 
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  x    No  ¨
 
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulations S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    Yes  x    No   ¨
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “large accelerated filer” and “accelerated filer” in Rule 12b-2 of the Exchange Act.
 
Large accelerated filer
x
Accelerated filer
¨
 
 
 
 
Non-accelerated filer
¨
Smaller reporting company
¨
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes  ¨    No  x
 
The number of shares outstanding of the registrant’s Common Stock, $.10 par value per share, on May 3, 2013 was 56,754,000.
 


 
 

 

PART I – FINANCIAL INFORMATION
 
Item 1.
Financial Statements
 
KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONDENSED BALANCE SHEETS
(Unaudited)
 
ASSETS
 
 
 
March 31,
2013
 
 
December 31,
2012
 
 
 
($ in thousands)
 
Current assets:
 
 
 
 
 
 
Cash and cash equivalents
 
$
3,838
 
 
$
11,059
 
Accounts receivable:
 
 
 
 
 
 
 
 
Trade – less allowance for doubtful accounts
 
 
331,424
 
 
 
313,182
 
Other
 
 
35,327
 
 
 
43,074
 
Inventories – net
 
 
164,726
 
 
 
177,397
 
Prepaid expenses and other current assets
 
 
40,542
 
 
 
39,248
 
Deferred income taxes
 
 
9,929
 
 
 
12,296
 
 
 
 
 
 
 
 
 
 
Total current assets
 
 
585,786
 
 
 
596,256
 
 
 
 
 
 
 
 
 
 
Property and equipment
 
 
3,275,602
 
 
 
3,219,113
 
Less accumulated depreciation
 
 
(930,174
)
 
 
(903,948
)
 
 
 
 
 
 
 
 
 
Property and equipment – net
 
 
2,345,428
 
 
 
2,315,165
 
 
 
 
 
 
 
 
 
 
Goodwill
 
 
595,234
 
 
 
596,030
 
Other assets
 
 
171,637
 
 
 
145,677
 
 
 
 
 
 
 
 
 
 
Total assets
 
$
3,698,085
 
 
$
3,653,128
 
 
See accompanying notes to condensed financial statements.
 
 
2

 

KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONDENSED BALANCE SHEETS
(Unaudited)
 
LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
March 31,
 2013
 
 
December 31,
 2012
 
 
 
($ in thousands)
 
Current liabilities:
 
 
 
 
 
 
Current portion of long-term debt
 
$
71,500
 
 
$
65,000
 
Income taxes payable
 
 
6,003
 
 
 
2,369
 
Accounts payable
 
 
148,658
 
 
 
156,763
 
Accrued liabilities
 
 
105,200
 
 
 
114,031
 
Deferred revenues
 
 
32,565
 
 
 
16,857
 
 
 
 
 
 
 
 
 
 
Total current liabilities
 
 
363,926
 
 
 
355,020
 
 
 
 
 
 
 
 
 
 
Long-term debt – less current portion
 
 
1,031,960
 
 
 
1,070,110
 
Deferred income taxes
 
 
446,497
 
 
 
426,096
 
Other long-term liabilities
 
 
86,262
 
 
 
94,848
 
 
 
 
 
 
 
 
 
 
Total long-term liabilities
 
 
1,564,719
 
 
 
1,591,054
 
 
 
 
 
 
 
 
 
 
Contingencies and commitments
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equity:
 
 
 
 
 
 
 
 
Kirby stockholders’ equity:
 
 
 
 
 
 
 
 
Common stock, $.10 par value per share. Authorized 120,000,000 shares, issued 59,776,000 shares
 
 
5,978
 
 
 
5,978
 
Additional paid-in capital
 
 
398,880
 
 
 
397,785
 
Accumulated other comprehensive income – net
 
 
(58,771
)
 
 
(61,127
)
Retained earnings
 
 
1,495,657
 
 
 
1,439,079
 
Treasury stock – at cost, 3,044,000 at March 31, 2013 and 3,191,000 at December 31, 2012
 
 
(84,275
)
 
 
(86,747
)
Total Kirby stockholders’ equity
 
 
1,757,469
 
 
 
1,694,968
 
Noncontrolling interests
 
 
11,971
 
 
 
12,086
 
Total equity
 
 
1,769,440
 
 
 
1,707,054
 
 
 
 
 
 
 
 
 
 
Total liabilities and equity
 
$
3,698,085
 
 
$
3,653,128
 
 
See accompanying notes to condensed financial statements.
 
 
3

 
 
KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONDENSED STATEMENTS OF EARNINGS
(Unaudited)
 
 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
 
 
($ in thousands, except
per share amounts)
 
Revenues:
 
 
 
 
 
 
Marine transportation
 
$
418,518
 
 
$
335,957
 
Diesel engine services
 
 
140,267
 
 
 
230,978
 
Total revenues
 
 
558,785
 
 
 
566,935
 
 
 
 
 
 
 
 
 
 
Costs and expenses:
 
 
 
 
 
 
 
 
Costs of sales and operating expenses
 
 
369,274
 
 
 
384,359
 
Selling, general and administrative
 
 
44,156
 
 
 
53,100
 
Taxes, other than on income
 
 
4,478
 
 
 
3,914
 
Depreciation and amortization
 
 
40,996
 
 
 
36,474
 
Loss on disposition of assets
 
 
32
 
 
 
28
 
Total costs and expenses
 
 
458,936
 
 
 
477,875
 
 
 
 
 
 
 
 
 
 
Operating income
 
 
99,849
 
 
 
89,060
 
Other income
 
 
75
 
 
 
149
 
Interest expense
 
 
(7,988
)
 
 
(5,840
)
 
 
 
 
 
 
 
 
 
Earnings before taxes on income
 
 
91,936
 
 
 
83,369
 
Provision for taxes on income
 
 
(34,384
)
 
 
(31,490
)
 
 
 
 
 
 
 
 
 
Net earnings
 
 
57,552
 
 
 
51,879
 
Less: Net earnings attributable to noncontrolling interests
 
 
(974
)
 
 
(935
)
 
 
 
 
 
 
 
 
 
Net earnings attributable to Kirby
 
$
56,578
 
 
$
50,944
 
 
 
 
 
 
 
 
 
 
Net earnings per share attributable to Kirby common stockholders:
 
 
 
 
 
 
 
 
Basic
 
$
1.00
 
 
$
.91
 
Diluted
 
$
1.00
 
 
$
.91
 
 
See accompanying notes to condensed financial statements.
 
 
4

 
 
KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)
 
 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
 
 
($ in thousands)
 
 
 
 
 
 
 
 
Net earnings
 
$
57,552
 
 
$
51,879
 
Other comprehensive income (loss), net of taxes:
 
 
 
 
 
 
 
 
Pension and postretirement benefits
 
 
1,177
 
 
 
989
 
Foreign currency translation adjustments
 
 
205
 
 
295
 
Change in fair value of derivative instruments
 
 
974
 
 
 
1,080
 
Total comprehensive income (loss), net of taxes
 
 
2,356
 
 
 
2,364
 
 
 
 
 
 
 
 
 
 
Total comprehensive income, net of taxes
 
 
59,908
 
 
 
54,243
 
Net earnings attributable to noncontrolling interests
 
 
(974
)
 
 
(935
)
 
 
 
 
 
 
 
 
 
Comprehensive income attributable to Kirby
 
$
58,934
 
 
$
53,308
 
 
See accompanying notes to condensed financial statements.
 
 
 
5

 
 
KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONDENSED STATEMENTS OF CASH FLOWS
(Unaudited)
 
   
Three months ended
March 31,
 
   
2013
   
2012
 
   
($ in thousands)
 
Cash flows from operating activities:
 
 
   
 
 
Net earnings
  $ 57,552     $ 51,879  
Adjustments to reconcile net earnings to net cash provided by operations:
               
Depreciation and amortization
    40,996       36,474  
Provision for deferred income taxes
    21,497       18,183  
Amortization of unearned share-based compensation
    2,134       1,906  
Other
    2,155       1,211  
Decrease in cash flows resulting from changes in operating assets and liabilities, net
    (26,538 )     (36,285 )
Net cash provided by operating activities
    97,796       73,368  
                 
Cash flows from investing activities:
               
Capital expenditures
    (71,157 )     (61,867 )
Acquisition of businesses and marine equipment
    (2,111 )  
 
Proceeds from disposition of assets
    1,861       3,434  
Net cash used in investing activities
    (71,407 )     (58,433 )
                 
Cash flows from financing activities:
               
Payments on bank credit facilities, net
    (43,650 )     (22,510 )
Borrowings on long-term debt
    225,000    
 
Payments on long-term debt
    (213,000 )     (6,502 )
Proceeds from exercise of stock options
    2,262       1,001  
Payment of contingent liability
    (5,000 )  
 
Excess tax benefit from equity compensation plans
    1,866       2,337  
Other
    (1,088 )     (465 )
Net cash used in financing activities
    (33,610 )     (26,139 )
Decrease in cash and cash equivalents
    (7,221 )     (11,204 )
                 
Cash and cash equivalents, beginning of year
    11,059       16,249  
Cash and cash equivalents, end of period
  $ 3,838     $ 5,045  
                 
Supplemental disclosures of cash flow information:
               
Cash paid (received) during the period:
               
Interest
  $ 5,420     $ 5,342  
Income taxes
  $ (177 )   $ 749  
 
See accompanying notes to condensed financial statements.
 
 
6

 
 
 KIRBY CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
NOTES TO CONDENSED FINANCIAL STATEMENTS
(Unaudited)
 
In the opinion of management, the accompanying unaudited condensed financial statements of Kirby Corporation and consolidated subsidiaries (the “Company”) contain all adjustments (consisting of only normal recurring accruals) necessary to present fairly the financial position as of March 31, 2013 and December 31, 2012, and the results of operations for the three months ended March 31, 2013 and 2012.
 
(1)
BASIS FOR PREPARATION OF THE CONDENSED FINANCIAL STATEMENTS
 
The condensed financial statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Although the Company believes that the disclosures are adequate to make the information presented not misleading, certain information and footnote disclosures, including significant accounting policies normally included in annual financial statements, have been condensed or omitted pursuant to such rules and regulations. It is suggested that these condensed financial statements be read in conjunction with the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.
 
(2)
ACCOUNTING STANDARD ADOPTION
 
In February 2013, the Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2013-02, “Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income” (“ASU 2013-02”). ASU 2013-02 established the effective date for the requirement to present components of reclassifications out of accumulated other comprehensive income (“OCI”) on the face of the financial statements. The adoption of ASU 2013-02 in the first quarter of 2013 did not have an impact on the Company’s consolidated financial statements except the Company has applied these provisions to its presentation of consolidated financial statements.
 
 (3)
ACQUISITIONS
 
On December 28, 2012, the Company purchased the assets of Flag Service & Maintenance, Inc. (“Flag”) for $6,864,000 in cash. Flag was an East Coast high-speed diesel engine service provider, operating factory-authorized full service marine dealerships for Caterpillar, Cummins, MTU and John Deere diesel engines.

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

On November 1, 2012, the Company purchased from Allied Transportation Company (“Allied”) 10 coastal tank barges with a total capacity of 680,000 barrels, three offshore dry-bulk barges with a total capacity of 48,000 deadweight tons and seven coastal tugboats for $107,014,000 in cash, before post-closing adjustments and excluding transaction fees, including a provision for up to $10,000,000 that will be paid contingent on developments with the sugar provisions in the United States Farm Bill. The fair value of the contingent liability recorded at the acquisition date was $9,756,000. A payment of $5,000,000 was made in the 2013 first quarter on the contingent liability.  Allied provided coastal transportation of petrochemicals as well as dry sugar products in the Northeast, Atlantic and Gulf Coast regions of the United States.

(4)
INVENTORIES
 
The following table presents the details of inventories as of March 31, 2013 and December 31, 2012 (in thousands):
 
 
 
March 31,
2013
 
 
December 31,
2012
 
Finished goods
 
$
143,446
 
 
$
162,859
 
Work in process
 
 
21,280
 
 
 
14,538
 
 
 
$
164,726
 
 
$
177,397
 
 
 
7

 
 
(5)
FAIR VALUE MEASUREMENTS
 
 
The accounting guidance for using fair value to measure certain assets and liabilities establishes a three tier value hierarchy, which prioritizes the inputs to valuation techniques used in measuring fair value. These tiers include: Level 1, defined as observable inputs such as quoted prices in active markets for identical assets or liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little, if any, market data exists, therefore requiring an entity to develop its own assumptions about the assumptions that market participants would use in pricing the asset or liability.

The following table summarizes the assets and liabilities measured at fair value on a recurring basis as of March 31, 2013 and December 31, 2012 (in thousands):
 
March 31, 2013:
 
Quoted
Prices
in Active
Markets for
Identical
Assets
(Level 1)
 
 
Significant
Other
Observable
Inputs
(Level 2)
 
 
Significant
Unobservable
Inputs
(Level 3)
 
 
Total
Fair Value
Measurements
 
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives
 
$
 
 
$
 
 
$
 
 
$
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives
 
$
 
 
$
23
 
 
$
 
 
$
23
 
Contingent liabilities
 
 
 
 
 
 
 
 
18,866
 
 
 
18,866
 
 
 
$
 
 
$
23
 
 
$
18,866
 
 
$
18,889
 
 
December 31, 2012:
 
Quoted
Prices
in Active
Markets for
Identical
Assets
(Level 1)
 
 
Significant
Other
Observable
Inputs
(Level 2)
 
 
Significant
Unobservable
Inputs
(Level 3)
 
 
Total
Fair Value
Measurements
 
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives
 
$
 
 
$
 
 
$
 
 
$
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Derivatives
 
$
 
 
$
1,525
 
 
$
 
 
$
1,525
 
Contingent liabilities
 
 
 
 
 
 
 
 
28,067
 
 
 
28,067
 
 
 
$
 
 
$
1,525
 
 
$
28,067
 
 
$
29,592
 
 
The fair value of the Company’s derivative instruments is more fully described below in Note 6, Derivative Instruments.
 
    In connection with the acquisition of Allied on November 1, 2012, Allied’s former owners are eligible to receive up to an additional $10,000,000 payable in 2013 through 2015, contingent on developments with the sugar provisions in the United States Farm Bill. The fair value of the contingent liability recorded at the acquisition date was $9,756,000. The fair value of the contingent liability is based on a valuation of the estimated fair value of the liability after probability weighting and discounting various potential payments. A payment of $5,000,000 was made in the 2013 first quarter on the contingent liability. The increase in the fair value of the contingent liability of $99,000 for the three months ended March 31, 2013 was charged to selling, general and administrative expense. As of March 31, 2013, the Company had recorded a contingent liability of $4,866,000.

In connection with the acquisition of United on April 15, 2011, United’s former owners are eligible to receive a three-year earnout provision for up to an additional $50,000,000 payable in 2014, dependent on achieving certain financial targets. The fair value of the contingent earnout liability recorded at the acquisition date was $16,300,000. The fair value of the earnout is based on a valuation of the estimated fair value of the liability after probability weighting and discounting various potential payments. The decrease in the fair value of the earnout liability of $4,300,000 for the three months ended March 31, 2013 was credited to selling, general and administrative expense. As of March 31, 2013, the Company had recorded an earnout liability of $14,000,000.
 
The estimated fair value of total debt outstanding at March 31, 2013 and December 31, 2012 was $1,095,222,000 and $1,130,967,000, respectively, which differs from the carrying amounts of $1,103,460,000 and $1,135,110,000, respectively, included in the consolidated financial statements. The fair value was determined using an income approach that relies on inputs such as yield curves.  Cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities have carrying values that approximate fair value due to the short-term maturity of these financial instruments.

 
8

 
 
Certain assets are measured at fair value on a nonrecurring basis and therefore are not included in the table above. These assets are adjusted to fair value when there is evidence of impairment. During the three months ended March 31, 2013, there was no indication that the Company’s long-lived assets were impaired, and accordingly, measurement at fair value was not required.
 
(6)
DERIVATIVE INSTRUMENTS
 
The Company recognizes all derivative instruments at fair value in the balance sheet as either assets or liabilities. The accounting for changes in the fair value of a derivative instrument depends on the intended use of the derivative and the resulting designation, which is established at the inception date of a derivative. For derivative instruments designated as cash flow hedges, changes in fair value, to the extent the hedge is effective, are recognized in OCI until the hedged item is recognized in earnings. Hedge effectiveness is measured at least quarterly based on the cumulative difference between the fair value of the derivative contract and the hedged item over time. Any change in fair value resulting from ineffectiveness is recognized immediately in earnings.
 
Interest Rate Risk Management
 
From time to time, the Company has utilized derivative financial instruments with respect to a portion of its interest rate risks to achieve a more predictable cash flow by reducing its exposure to interest rate fluctuations. These transactions generally are interest rate swap agreements and are entered into with large multinational banks. On February 28, 2013, all of the Company’s outstanding interest rate swaps expired.  These interest rate swaps, with a total notional amount of $200,000,000, were designated as cash flow hedges.
 
Foreign Currency Risk Management
 
From time to time, the Company has utilized derivative financial instruments with respect to its forecasted foreign currency transactions to attempt to reduce the risk of its exposure to foreign currency rate fluctuations in its transactions denominated in foreign currency. These transactions, which relate to foreign currency obligations for the purchase of equipment from foreign suppliers or foreign currency receipts from foreign customers, generally are forward contracts or purchased call options and are entered into with large multinational banks.
 
As of March 31, 2013, the Company had a forward contract with a notional amount of $469,000 to hedge its exposure to foreign currency rate fluctuations in expected foreign currency transactions. This contract expires in the first quarter of 2014. This forward contract is designated as a cash flow hedge, therefore, the change in fair value, to the extent the forward contract is effective, is recognized in OCI until the forward contract expires and is recognized in cost of sales and operating expenses.
 
Fair Value of Derivative Instruments
 
The following table sets forth the fair value of the Company’s derivative instruments recorded as liabilities located on the consolidated balance sheet at March 31, 2013 and December 31, 2012 (in thousands):
 
Liability Derivatives
 
Balance Sheet
Location
   
March 31,
2013
   
December 31,
2012
 
Derivatives designated as hedging instruments under ASC 815:
 
 
   
 
   
 
 
 
 
 
   
 
   
 
 
Foreign currency contracts
 
Other accrued liabilities
    $ 23    
 
Foreign currency contracts
 
Other long-term liabilities
   
      39  
Interest rate contracts
 
Other accrued liabilities
   
      1,486  
   
 
                 
Total derivatives designated as hedging instruments under ASC 815
 
 
    $ 23     $ 1,525  
Total liability derivatives
 
 
    $ 23     $ 1,525  
 
Fair value amounts were derived as of March 31, 2013 and December 31, 2012 utilizing fair value models of the Company and its counterparties on the Company’s portfolio of derivative instruments. These fair value models use the income approach that relies on inputs such as yield curves, currency exchange rates and forward prices. The fair value of the Company’s derivative instruments is described above in Note 5, Fair Value Measurements.

 
9

 
 
Cash Flow Hedges
 
For derivative instruments that are designated and qualify as cash flow hedges, the effective portion of the gain or loss on the derivative is reported as a component of OCI and reclassified into earnings in the same period or periods during which the hedged transaction affects earnings. Gains and losses on the derivative representing either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness are recognized in current earnings. Any ineffectiveness related to the Company’s hedges was not material for any of the periods presented.
 
The following table sets forth the location and amount of gains and losses on the Company’s derivative instruments in the consolidated statements of earnings for the three months ended March 31, 2013 and 2012 (in thousands):
 
 
 
 
   
Amount of Gain (Loss)
   
Amount of Gain (Loss)
 
 
 
 
   
Recognized in OCI on
   
Reclassified from
 
 
 
 
   
Derivatives (Effective
   
Accumulated OCI into
 
 
 
 
   
Portion)
   
Income (Effective Portion)
 
   
Location of Gain (Loss)
             
 
  Reclassified from              
   
Accumulated OCI into
   
Three months ended
   
Three months ended
 
Derivatives in ASC 815 Cash
  Income    
March 31,
   
March 31,
 
Flow Hedging Relationships:
 
(Effective Portion)
   
2013
 
2012
   
2013
 
2012
 
Interest rate contracts
 
Interest expense
    $ 1,486     $ 1,593     $ (1,389 )   $ (2,044 )
   
 
                                 
Foreign exchange contracts
 
Cost and sales of operating expenses
      15       77    
      (2 )
Total
    $ 1,501     $ 1,670     $ (1,389 )   $ (2,046 )
 
The Company expects $23,000 of net losses on foreign currency contracts included in accumulated OCI will be transferred into earnings over the next year based on current spot rates.

(7)
STOCK AWARD PLANS
 
The Company has share-based compensation plans which are described below. The compensation cost that has been charged against earnings for the Company’s stock award plans and the income tax benefit recognized in the statement of earnings for stock awards for the three months ended March 31, 2013 and 2012 were as follows (in thousands):
 
 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
Compensation cost
 
$
2,134
 
 
$
1,906
 
Income tax benefit
 
$
807
 
 
$
728
 
 
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 and performance awards. The exercise price for each option equals the fair market value per share of the Company’s common stock on the date of grant. The terms of the options granted prior to January 25, 2010 are five years and vest ratably over three years. Options granted on or after January 25, 2010 have terms of seven years and vest ratably over three years. No performance awards payable in stock have been awarded under the Plan.  At March 31, 2013, 2,673,605 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 three months ended March 31, 2013:
 
 
 
Outstanding
Non-
Qualified or
Nonincentive
Stock
Awards
 
 
Weighted
Average
Exercise
Price
 
Outstanding at December 31, 2012
 
 
351,173
 
 
$
45.54
 
Granted
 
 
109,560
 
 
$
70.65
 
Exercised
 
 
(36,800)
 
 
$
29.61
 
Outstanding at March 31, 2013
 
 
423,933
 
 
$
53.41
 
 
 
10

 
 
The following table summarizes information about the Company’s outstanding and exercisable stock options under the employee plan at March 31, 2013:
 
 
 
Options Outstanding
 
 
Options Exercisable
 
Range of Exercise
Prices
 
Number
Outstanding
 
Weighted
Average
Remaining
Contractual
Life in
Years
 
 
Weighted
Average
Exercise
Price
 
 
Aggregate
Intrinsic
Value
 
 
Number
Exercisable
 
 
Weighted
Average
Exercise
Price
 
 
Aggregate
Intrinsic
Value
 
$23.98 - $32.56
 
99,898
 
 
3.5
 
 
$
31.43
 
 
 
 
 
 
99,898
 
 
$
31.43
 
 
 
 
$34.40 - $36.35
 
14,000
 
 
1.6
 
 
$
34.96
 
 
 
 
 
 
14,000
 
 
$
34.96
 
 
 
 
$46.74
 
100,569
 
 
4.8
 
 
$
46.74
 
 
 
 
 
 
67,039
 
 
$
46.74
 
 
 
 
$65.28 - $70.65
 
209,466
 
 
6.4
 
 
$
68.34
 
 
 
 
 
 
33,299
 
 
$
65.80
 
 
 
 
$23.98 - $70.65
 
423,933
 
 
5.2
 
 
$
53.41
 
 
$
9,914,000
 
 
 
214,236
 
 
$
41.79
 
 
$
7,500,000
 
 
The following is a summary of the restricted stock award activity under the employee plan described above for the three months ended March 31, 2013:
 
 
 
Unvested
Restricted Stock
Award Shares
 
 
Weighted
Average
Grant Date
Fair Value
Per Share
 
Nonvested balance at December 31, 2012
 
 
418,128
 
 
$
45.39
 
Granted
 
 
128,125
 
 
$
68.28
 
Vested
 
 
(138,794
)
 
$
40.69
 
Forfeited
 
 
(1,832
)
 
$
60.09
 
Nonvested balance at March 31, 2013
 
 
405,627
 
 
$
54.16
 
 
The Company has a director stock award plan for nonemployee directors of the Company which provides for the issuance of stock options and restricted stock.  The director plan provides for the automatic grants of stock options and restricted stock to nonemployee directors on the date of first election as a director and after each annual meeting of stockholders. In addition, the director plan allows for the issuance of stock options or restricted stock in lieu of cash for all or part of the annual director fee at the option of the director. The exercise prices for all options granted under the plan are equal to the fair market value per share of the Company’s common stock on the date of grant. The terms of the options are ten years. The options granted to a director when first elected vest immediately. The options granted and restricted stock issued after each annual meeting of stockholders vest six months after the date of grant. Options granted and restricted stock issued in lieu of cash director fees vest in equal quarterly increments during the year to which they relate. At March 31, 2013, 675,535 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 three months ended March 31, 2013:
 
 
 
Outstanding
Non-
Qualified or
Nonincentive
Stock
Awards
 
 
Weighted
Average
Exercise
Price
 
Outstanding at December 31, 2012
 
 
345,938
 
 
$
45.84
 
Exercised
 
 
(24,000
)
 
$
48.83
 
Outstanding at March 31, 2013
 
 
321,938
 
 
$
45.62
 
 
 
11

 
 
The following table summarizes information about the Company’s outstanding and exercisable stock options under the director plan at March 31, 2013:

   
 
Options Outstanding
 
 
Options Exercisable
 
Range of Exercise Prices
 
 
Number
Outstanding
 
 
Weighted
Average
Remaining
Contractual
Life in
Years
 
 
Weighted
Average
Exercise
Price
 
 
Aggregate
Intrinsic
Value
 
 
Number
Exercisable
 
 
Weighted
Average
Exercise
Price
 
 
Aggregate
Intrinsic
Value
 
$12.69 — $17.88  
 
 
24,000
 
 
 
0.6
 
 
$
15.29
 
 
 
 
 
 
24,000
 
 
$
15.29
 
 
 
 
$20.28 — $29.60  
 
 
36,000
 
 
 
4.7
 
 
$
26.49
 
 
 
 
 
 
36,000
 
 
$
26.49
 
 
 
 
$35.17 — $36.82  
 
 
56,036
 
 
 
3.5
 
 
$
35.91
 
 
 
 
 
 
56,036
 
 
$
35.91
 
 
 
 
$41.24 — $56.45  
 
 
145,596
 
 
 
6.7
 
 
$
52.14
 
 
 
 
 
 
145,596
 
 
$
52.14
 
 
 
 
$61.89 — $62.48  
 
 
60,306
 
 
 
9.2
 
 
$
62.38
 
 
 
 
 
 
60,306
 
 
$
62.38
 
 
 
 
$12.69 — $62.48  
 
 
321,938
 
 
 
5.9
 
 
$
45.62
 
 
$
10,038,000
 
 
 
321,938
 
 
$
45.62
 
 
$
10,038,000
 

The following is a summary of the restricted stock award activity under the director plan described above for the three months ended March 31, 2013:
 
   
Unvested
Restricted Stock
Award Shares
   
Weighted
Average
Grant Date
Fair Value
Per Share
 
Nonvested balance at December 31, 2012
    348     $ 62.99  
Vested
    (348 )   $ 62.99  
Nonvested balance at March 31, 2013
 
   
 
 
The total intrinsic value of all stock options exercised under all of the Company’s plans was $2,227,000 and $860,000 for the three months ended March 31, 2013 and 2012, respectively. The actual tax benefit realized for tax deductions from stock option exercises was $842,000 and $329,000 for the three months ended March 31, 2013 and 2012, respectively.
 
The total intrinsic value of all the restricted stock vestings under all of the Company’s plans was $9,200,000 and $10,860,000 for the three months ended March 31, 2013 and 2012, respectively. The actual tax benefit realized for tax deductions from restricted stock vestings was $3,477,000 and $4,149,000 for the three months ended March 31, 2013 and 2012, respectively.
 
As of March 31, 2013, there was $4,231,000 of unrecognized compensation cost related to nonvested stock options and $20,722,000 related to restricted stock. The stock options are expected to be recognized over a weighted average period of approximately 2.0 years and restricted stock over approximately 3.3 years. The total fair value of options vested was $1,707,000 and $1,312,000 during the three months ended March 31, 2013 and 2012, respectively. The fair value of the restricted stock vested was $9,200,000 and $10,860,000 for the three months ended March 31, 2013 and 2012, respectively.
 
The weighted average per share fair value of stock options granted during the three months ended March 31, 2013 and 2012 was $23.66 and $21.62, respectively. The fair value of the stock options granted during the three months ended March 31, 2013 and 2012 was $2,592,000 and $2,160,000, 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 three months ended March 31, 2013 and 2012 were as follows:
 
   
Three months ended
 March 31,
 
   
2013
   
2012
 
Dividend yield    
None
     
None
 
Average risk-free interest rate
    1.0%       1.0%  
Stock price volatility     34%       33%  
Estimated option term    
Six years
     
Six years
 

 
12

 
 
(8)
OTHER COMPREHENSIVE INCOME
 
The Company’s changes in other comprehensive income for the three months ended March 31, 2013 and 2012 were as follows (in thousands):
 
 
 
Three months ended March 31,
 
 
 
2013
 
 
2012
 
 
 
Gross
Amount
 
 
Income
Tax
(Provision)
Benefit
 
 
Net
Amount
 
 
Gross
Amount
 
 
Income
Tax
(Provision)
Benefit
 
 
Net
Amount
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Pension and postretirement benefits (a):
                                               
Amortization of net actuarial loss
 
$
1,906
 
 
$
(729
)
 
$
1,177
 
 
$
1,601
 
 
$
(612
)
 
$
989
 
Actuarial gains
   
     
     
     
     
     
 
                                                 
Foreign currency translation adjustments
 
 
205
 
 
 
 
 
 
205
 
 
 
295
 
 
 
 
 
 
295
 
                                                 
Change in fair value of derivative instruments (b):
                                               
Unrealized gains
   
2,889
     
(1,012)
     
1,877
     
3,716
     
(1,306)
     
2,410
 
Reclassified to net earnings
 
 
(1,389)
 
 
 
486
 
 
 
(903)
 
 
 
(2,046)
 
 
 
716
 
 
 
(1,330)
 
Total
 
$
3,611
 
 
$
(1,255
)
 
$
2,356
 
 
$
3,566
 
 
$
(1,202
)
 
$
2,364
 
 
 
(a)
Actuarial losses are amortized into costs of sales and operating expenses or selling, general and administrative expenses as appropriate.  (See Note 12 – Retirement Plans)
 
 
(b)
Reclassifications to net earnings of derivatives qualifying as effective hedges are recognized in interest expense or costs of sales and operating expenses as appropriate.  (See Note 6 – Derivative Instruments)
 
(9)
SEGMENT DATA
 
The Company’s operations are classified into two reportable business segments as follows:
 
Marine Transportation — Marine transportation principally by United States flag vessels of liquid cargoes throughout the United States inland waterway system, coastwise along all three United States coasts and in Alaska and Hawaii and, to a lesser extent, United States coastal transportation of dry-bulk cargoes. The principal products transported include petrochemicals, black oil, refined petroleum products and agricultural chemicals.

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

The Company’s two reportable business segments are managed separately based on fundamental differences in their operations. The Company evaluates the performance of its segments based on the contributions to operating income of the respective segments, before income taxes, interest, gains or losses on disposition of assets, other nonoperating income, noncontrolling interests, accounting changes, and nonrecurring items. Intersegment sales for the three months ended March 31, 2013 and 2012 were not significant.
 
 
13

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

 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
Revenues:
 
 
 
 
 
 
Marine transportation
 
$
418,518
 
 
$
335,957
 
Diesel engine services
 
 
140,267
 
 
 
230,978
 
 
 
$
558,785
 
 
$
566,935
 
Segment profit (loss):
 
 
 
 
 
 
 
 
Marine transportation
 
$
89,253
 
 
$
68,490
 
Diesel engine services
 
 
14,022
 
 
 
23,554
 
Other
 
 
(11,339
)
 
 
(8,675
)
 
 
$
91,936
 
 
$
83,369
 
 
 
 
March 31,
2013
 
 
December 31,
2012
 
Total assets:
 
 
 
 
 
 
Marine transportation
 
$
3,007,532
 
 
$
2,951,723
 
Diesel engine services
 
 
644,367
 
 
 
647,986
 
Other
 
 
46,186
 
 
 
53,419
 
 
 
$
3,698,085
 
 
$
3,653,128
 
 
The following table presents the details of “Other” segment loss for the three months ended March 31, 2013 and 2012 (in thousands):
 
 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
General corporate expenses
 
$
(3,394
)
 
$
(2,956
)
Loss on disposition of assets
 
 
(32
)
 
 
(28
)
Interest expense
 
 
(7,988
)
 
 
(5,840
)
Other income
 
 
75
 
 
 
149
 
 
 
$
(11,339
)
 
$
(8,675
)
 
The following table presents the details of “Other” total assets as of March 31, 2013 and December 31, 2012 (in thousands):
 
 
 
March 31,
2013
 
 
December 31,
2012
 
General corporate assets
 
$
44,276
 
 
$
51,611
 
Investment in affiliates
 
 
1,910
 
 
 
1,808
 
 
 
$
46,186
 
 
$
53,419
 
 
(10)
TAXES ON INCOME
 
Earnings before taxes on income and details of the provision for taxes on income for the three months ended March 31, 2013 and 2012 were as follows (in thousands):
 
 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
Earnings before taxes on income – United States
 
$
91,936
 
 
$
83,369
 
 
 
 
 
 
 
 
 
 
Provision for taxes on income:
 
 
 
 
 
 
 
 
Federal:
 
 
 
 
 
 
 
 
Current
 
$
9,430
 
 
$
9,680
 
Deferred
 
 
21,497
 
 
 
18,183
 
State and local
 
 
3,457
 
 
 
3,627
 
 
 
$
34,384
 
 
$
31,490
 
 
 
14

 
 
(11)
EARNINGS PER SHARE
 
The following table presents the components of basic and diluted earnings per share for the three months ended March 31, 2013 and 2012 (in thousands, except per share amounts):
 
 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
Net earnings attributable to Kirby
 
$
56,578
 
 
$
50,944
 
Undistributed earnings allocated to restricted shares
 
 
(401
)
 
 
(393
)
Income available to Kirby common stockholders – basic
 
 
56,177
 
 
 
50,551
 
Undistributed earnings allocated to restricted shares
 
 
401
 
 
 
393
 
Undistributed earnings reallocated to restricted shares
 
 
(399
)
 
 
(391
)
Income available to Kirby common stockholders – diluted
 
$
56,179
 
 
$
50,553
 
 
 
 
 
 
 
 
 
 
Shares outstanding:
 
 
 
 
 
 
 
 
Weighted average common stock issued and outstanding
 
 
56,669
 
 
 
55,808
 
Weighted average unvested restricted stock
 
 
(401
)
 
 
(430
)
Weighted average common stock outstanding – basic
 
 
56,268
 
 
 
55,378
 
Dilutive effect of stock options
 
 
187
 
 
 
257
 
Weighted average common stock outstanding – diluted
 
 
56,455
 
 
 
55,635
 
 
 
 
 
 
 
 
 
 
Net earnings per share attributable to Kirby common stockholders:
 
 
 
 
 
 
 
 
Basic
 
$
1.00
 
 
$
.91
 
Diluted
 
$
1.00
 
 
$
.91
 
 
Certain outstanding options to purchase approximately 209,000 and 102,000 shares of common stock were excluded in the computation of diluted earnings per share as of March 31, 2013 and 2012, respectively, as such stock options would have been antidilutive.
 
(12)
RETIREMENT PLANS
 
The Company sponsors a defined benefit plan for its inland vessel personnel and shore based tankermen. The plan benefits are based on an employee’s years of service and compensation. The plan assets consist primarily of equity and fixed income securities.
 
The Company’s pension plan funding strategy has historically been to contribute an amount equal to the greater of the minimum required contribution under ERISA or the amount necessary to fully fund the plan on an accumulated benefit obligation (“ABO”) basis at the end of the fiscal year. The ABO is based on a variety of demographic and economic assumptions, and the pension plan assets’ returns are subject to various risks, including market and interest rate risk, making an accurate prediction of the pension plan contribution difficult. Based on current pension plan assets and market conditions, the Company expects to make a contribution of up to $5,000,000 to its pension plan prior to December 31, 2013 to fund its 2013 pension plan obligations. As of March 31, 2013, no 2013 year contributions have been made.
 
The Company sponsors an unfunded defined benefit health care plan that provides limited postretirement medical benefits to employees who meet minimum age and service requirements, and to eligible dependents. The plan limits cost increases in the Company’s contribution to 4% per year. The plan is contributory, with retiree contributions adjusted annually. The plan eliminated coverage for future retirees as of December 31, 2011. The Company also has an unfunded defined benefit supplemental executive retirement plan (“SERP”) that was assumed in an acquisition in 1999. That plan ceased to accrue additional benefits effective January 1, 2000.
 
The components of net periodic benefit cost for the Company’s defined benefit plans for the three months ended March 31, 2013 and 2012 were as follows (in thousands):
 
 
 
Pension Benefits
 
 
 
Pension Plan
 
 
SERP
 
 
 
Three months ended
March 31,
 
 
Three months ended
March 31,
 
 
 
2013
 
 
2012
 
 
2013
 
 
2012
 
Components of net periodic benefit cost:
 
 
 
 
 
 
 
 
 
 
 
 
Service cost
 
$
3,171
 
 
$
2,566
 
 
$
 
 
$
 
Interest cost
 
 
2,835
 
 
 
2,584
 
 
 
17
 
 
 
18
 
Expected return on plan assets
 
 
(4,027
)
 
 
(3,220
)
 
 
 
 
 
 
Amortization of actuarial loss
 
 
2,056
 
 
 
1,752
 
 
 
5
 
 
 
4
 
Net periodic benefit cost
 
$
4,035
 
 
$
3,682
 
 
$
22
 
 
$
22
 
 
 
15

 
 
The components of net periodic benefit cost for the Company’s postretirement benefit plan for the three months ended March 31, 2013 and 2012 were as follows (in thousands):
 
 
 
Other Postretirement Benefits
 
 
 
Postretirement Welfare Plan
 
 
 
Three months ended March 31,
 
 
 
2013
 
 
2012
 
Components of net periodic benefit cost:
 
 
 
 
 
 
Service cost
 
$
 
 
$
 
Interest cost
 
 
28
 
 
 
33
 
Amortization of actuarial gain
 
 
(155
)
 
 
(154
)
Net periodic benefit cost
 
$
(127
)
 
$
(121
)
 
(13)
CONTINGENCIES
 
In 2000, the Company and a group of approximately 45 other companies were notified that they are Potentially Responsible Parties (“PRPs”) under the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”) with respect to a Superfund site, the Palmer Barge Line Superfund Site (“Palmer”), located in Port Arthur, Texas. In prior years, Palmer had provided tank barge cleaning services to various subsidiaries of the Company. The Company and three other PRPs entered into an agreement with the United States Environmental Protection Agency (“EPA”) to perform a remedial investigation and feasibility study and, subsequently, a limited remediation was performed and is now complete. During the 2007 third quarter, five new PRPs entered into an agreement with the EPA related to the Palmer site. In July 2008, the EPA sent a letter to approximately 30 PRPs for the Palmer site, including the Company, indicating that it intends to pursue recovery of $2,949,000 of costs it incurred in relation to the site. The EPA updated its past cost claim to $3,616,000 which includes approximately $700,000 in expenses.  The Company and the other members of the PRP group are evaluating the EPA’s updated cost and continue to pursue resolution of all claims with the Department of Justice (“DOJ”).
 
In 2000, the Company and nine other companies were named as PRPs under CERCLA with respect to a Superfund site, the State Marine of Port Arthur Superfund Site (“State Marine”), located in Port Arthur, Texas. In the past, State Marine performed tank barge cleaning and services for various subsidiaries of the Company. The DOJ and EPA sought to recover reimbursement of its past costs of approximately $2,977,000 in connection with clean-up activities it incurred in relation to the site. On February 28, 2013, the Company and nine other PRPs settled this matter. The Company’s share of the settlement payment was approximately $120,000.

 
16

 
 
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 $56,227,000 at March 31, 2013, including $6,331,000 in letters of credit and $49,896,000 in performance bonds. All of these instruments have an expiration date within five years. The Company does not believe demand for payment under these instruments is likely and expects no material cash outlays to occur in connection with these instruments.

Item 1A.
Risk Factors
 
The Company continues to be subject to the risk factors previously disclosed in its “Risk Factors” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.
 
Item 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
Statements contained in this Form 10-K that are not historical facts, including, but not limited to, any projections contained herein, are forward-looking statements and involve a number of risks and uncertainties. Such statements can be identified by the use of forward-looking terminology such as “may,” “will,” “expect,” “anticipate,” “estimate” or “continue,” or the negative thereof or other variations thereon or comparable terminology. The actual results of the future events described in such forward-looking statements in this Form 10-Q could differ materially from those stated in such forward-looking statements. Among the factors that could cause actual results to differ materially are: adverse economic conditions, industry competition and other competitive factors, adverse weather conditions such as high water, low water, tropical storms, hurricanes, tsunamis, fog and ice, marine accidents, lock delays, fuel costs, interest rates, construction of new equipment by competitors, government and environmental laws and regulations, and the timing, magnitude and number of acquisitions made by the Company. For a more detailed discussion of factors that could cause actual results to differ from those presented in forward-looking statements, see Item 1A-Risk Factors found in the Company’s Annual Report on Form 10-K for the year ended December 31, 2012.  Forward-looking statements are based on currently available information and the Company assumes no obligation to update any such statements.
 
For purposes of the Management’s Discussion, all net earnings per share attributable to Kirby common stockholders are “diluted earnings per share.” The weighted average number of common shares applicable to diluted earnings per share for the first quarter of 2013 and 2012 were 56,455,000 and 55,635,000, respectively. The increase in the weighted average number of common shares for the 2013 first quarter compared with the 2012 first quarter primarily reflects the issuance of 500,000 shares of Company common stock associated with the December 14, 2012 acquisition of Penn, the issuance of restricted stock and the exercise of stock options.
 
 
17

 
 
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 March 31, 2013, the Company operated a fleet of 844 inland tank barges with 16.9 million barrels of capacity, and operated an average of 256 inland towboats during the 2013 first quarter. The Company’s coastal fleet consisted of 82 tank barges with 6.3 million barrels of capacity and 85 coastal tugboats. The Company also operates seven offshore barge and tug units transporting dry-bulk commodities in United States coastal trade. Through its diesel engine services segment the Company provides after-market services for medium-speed and high-speed diesel engines, reduction gears and ancillary products for marine and power generation applications, distributes and services high-speed diesel engines and transmissions, pumps and compression products, and manufactures and remanufacturers oilfield service equipment, including pressure pumping units, for the land-based pressure pumping and oilfield service markets.
 
For the 2013 first quarter, net earnings attributable to Kirby were $56,578,000, or $1.00 per share, on revenues of $558,785,000, compared with 2012 first quarter net earnings attributable to Kirby of $50,944,000, or $.91 per share, on revenues of $566,935,000.   The 2013 first quarter results included a $4,300,000 before taxes, or $.05 per share, credit to selling, general and administrative expenses, resulting from a net decrease in the fair value of the contingent earnout liability associated with the April 2011 acquisition of United.  This compares with a 2012 first quarter charge to selling, general and administrative expenses increasing the fair value of the contingent earnout liability by $4,200,000 before taxes, or $.05 per share, and a $2,421,000 before taxes, or $.03 per share, severance charge associated with the integration of Kirby Offshore Marine’s administrative functions into the Company.
 
 Marine Transportation
 
For the 2013 first quarter, 75% of the Company’s revenue was generated by its marine transportation segment. The segment’s customers include many of the major petrochemical and refining companies that operate in the United States. Products transported include intermediate materials used to produce many of the end products used widely by businesses and consumers — plastics, fiber, paints, detergents, oil additives and paper, among others, as well as residual fuel oil, ship bunkers, asphalt, gasoline, diesel fuel, heating oil and agricultural chemicals. Consequently, the Company’s marine transportation business mirrors the volumes produced by the Company’s petroleum, petrochemical and refining customer base. The 2013 first quarter results include the operations of Allied, acquired on November 1, 2012, and Penn, acquired on December 14, 2012.
 
The Company’s marine transportation segment’s revenues for the 2013 first quarter increased 25% and operating income increased 30% compared with the 2012 first quarter revenues and operating income. The higher marine transportation revenues reflected continued strong demand across all inland marine transportation markets, petrochemicals, black oil, refined petroleum products and agricultural chemicals, along with continued favorable pricing trends.  The Company’s inland petrochemical and black oil fleets achieved consistent tank barge utilization levels in the 90% to 95% range throughout the 2013 first quarter.  The Company’s coastal marine transportation markets continued to improve with tank barge utilization levels in the 90% range, aided by the addition of petrochemical volumes with the acquisition of the Allied fleet and additional black oil volumes with the acquisition of Penn, along with the transportation of crude oil and condensate.

During the 2013 and 2012 first quarters, approximately 75% of marine transportation’s inland revenues were under term contracts and 25% were spot contract revenues. Inland time charters during the 2013 and 2012 first quarters represented 57% and 56%, respectively, of the inland revenues under term contracts.
 
During the 2013 first quarter, approximately 70% of the coastal revenues were under term contracts and 30% were spot contract revenues. Coastal time charters represented approximately 90% of the revenues under term contracts during the 2013 first quarter.  For the 2012 first quarter, approximately 60% of the coastal revenues were under term contracts and 40% were spot contract revenues.  The increase in term contracts reflected the 2012 fourth quarter acquisitions of Allied and Penn, along with stronger demand for coastal tank barges.
 
Rates on inland term contracts renewed in the 2013 first quarter increased in the 4% to 6% average range compared with term contracts renewed in the first quarter of 2012. Spot contract rates in the 2013 first quarter, which include the cost of fuel, increased modestly compared with the 2012 fourth quarter.  Effective January 1, 2013, annual escalators for labor and the producer price index on a number of inland multi-year contracts resulted in rate increases on those contracts by approximately 1%, excluding fuel.
 
Rates on coastal term contracts renewed in the 2013 first quarter increased in the 7% to 9% average range compared with term contracts renewed in the 2012 first quarter. Spot contract rates in the 2013 first quarter, which include the cost of fuel, improved in the 5% to 9% average range compared with the 2012 fourth quarter.

 
18

 
 
The marine transportation operating margin was 21.3% for the 2013 first quarter compared with 20.4% for the 2012 first quarter.
 
Diesel Engine Services
 
For the 2013 first quarter, the diesel engine services segment generated 25% of the Company’s revenue, of which 18% was generated from manufacturing, 58% from overhauls and service, and 24% from direct parts sales. The results of the diesel engine services segment are largely influenced by the economic cycles of the marine and power generation markets and the land-based pressure pumping and oilfield service industries.
 
Diesel engine services revenues for the 2013 first quarter decreased 39% and operating income decreased 40% compared with the 2012 first quarter revenues and operating income.  The decreases were primarily attributable to a continuation of lower demand for the manufacturing of pressure pumping units, as well as a decline in the sales and service of land-based diesel engines and transmissions.  Partially offsetting the decline in the manufacturing of pressure pumping units was an increase in the number of pressure pumping units remanufactured.  The marine diesel engine services market remained stable, and the power generation market benefited from major generator set upgrades and parts sales for both domestic and international power generation customers.

The diesel engine services operating margin for the 2013 first quarter was 10.0%, including the positive earnings impact of the $4,300,000 credit to the contingent earnout liability, compared with 10.2% for the first quarter of 2012.

Cash Flow and Capital Expenditures
 
The Company continued to generate strong operating cash flow during the 2013 first quarter, with net cash provided by operating activities of $97,796,000 compared with $73,368,000 of net cash provided by operating activities for the 2012 first quarter. The 33% increase was primarily from higher net earnings attributable to Kirby, higher depreciation and amortization and a higher deferred tax provision in the 2013 first quarter versus the 2012 first quarter, and a $9,747,000 smaller net decrease in cash flows from changes in operating assets and liabilities.   In addition, during the 2013 and 2012 first quarters, the Company generated cash of $2,262,000 and $1,001,000, respectively, from the exercise of stock options and $1,861,000 and $3,434,000, respectively, from proceeds from the disposition of assets.
 
For the 2013 first quarter, cash generated and borrowings under the Company’s revolving credit facility were used for capital expenditures of $71,157,000, including $55,072,000 for inland tank barge and towboat construction, $6,906,000 for progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units scheduled for completion in the 2013 first half, and $9,179,000 primarily for upgrading the existing marine transportation fleet.  The Company’s debt-to-capitalization ratio decreased to 38.4% at March 31, 2013 from 39.9% at December 31, 2012, primarily due to a decrease of $31,650,000 of debt outstanding and the increase in total equity from net earnings attributable to Kirby for the 2013 first quarter of $56,578,000, exercise of stock options, and the amortization of unearned equity compensation.  As of March 31, 2013, the Company had $144,480,000 outstanding under its revolving credit facility and $455,000,000 outstanding under its term loan, of which $71,500,000 was classified as current portion of long-term debt, $500,000,000 of senior notes outstanding and $3,980,000 outstanding under its credit agreement.
 
The Company projects that capital expenditures for 2013 will be in the $190,000,000 to $200,000,000 range. The 2013 construction program will consist of 55 inland tank barges with a total capacity of 1,200,000 barrels and three inland towboats. Based on current commitments, steel prices and projected delivery schedules, the Company’s 2013 payments on new inland tank barges and towboats will be approximately $115,000,000 and approximately $10,000,000 in progress payments on the construction of two offshore articulated dry-bulk barge and tugboat units for delivery in the 2013 first half with an estimated total cost of $52,000,000 for each unit. The balance of approximately $65,000,000 to $75,000,000 is primarily capital upgrades and improvements to existing marine equipment and marine transportation and diesel engine services facilities.

During the 2013 first quarter, the Company took delivery of 19 new inland tank barges with a total capacity of approximately 533,000 barrels, and retired 13 inland tank barges, returned two charter inland tank barges and transferred one tank barge to the offshore operations, reducing its capacity by approximately 253,000 barrels. As a result, the Company added a net three inland tank barges and 280,000 barrels of capacity, as the new barges were generally larger capacity barges than the barges removed from service.
 
Outlook
 
Petrochemical and black oil inland tank barge utilization levels remained strong during the 2013 first quarter, in the 90% to 95% range. While the United States economy remains sluggish, with consistently high unemployment levels and weak consumer confidence, the United States petrochemical industry continues to see strong production levels for both domestic consumption and exports. Low priced domestic natural gas, a basic feedstock for the United States petrochemical industry, provides the industry with a competitive advantage against foreign petrochemical producers. As a result, United States petrochemical production has remained strong throughout 2012 and the 2013 first quarter, thereby producing increased marine transportation volumes for basic petrochemicals to both domestic consumers and terminals for export destinations. The black oil market has also remained strong throughout 2012 and the 2013 first quarter, primarily due to a continued stable United States refinery utilization level, aided by the export of diesel fuel and heavy fuel oil, and demand for the transportation of crude oil from shale formations in South Texas, as well as the movement of Canadian and Bakken crude oil from the Midwest to the Gulf Coast.
 
 
19

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

As of March 31, 2013, the Company estimated there were approximately 3,300 inland tank barges in the industry fleet, of which approximately 500 were over 35 years old and approximately 300 of those over 40 years old. Given the age profile of the industry inland tank barge fleet, the expectation is that older tank barges will continue to be removed from service and replaced by new tank barges that will enter the fleet. During 2012 and early 2013, with continued strong demand for inland petrochemical and black oil tank barges and federal tax incentives on new equipment, the Company estimates that approximately 260 inland tank barges were ordered industry-wide during 2012 for delivery throughout 2013. Many older tank barges will be retired, with the extent of the retirements dependent on 2013 petrochemical and refinery production levels, crude oil movements and industry-wide tank barge utilization levels.

During 2011 and the first half of 2012, the marine transportation segment was negatively impacted by excess coastal tank barge capacity with tank barge utilization in the 75% range. The coastal operations reflected improvements in market conditions during the 2012 second half and 2013 first quarter, with tank barge utilization improving to the 75% to 80% range in the third quarter, 85% to 90% in the fourth quarter, and in the 90% range in the 2013 first quarter. During the 2012 second half and 2013 first quarter, the Company experienced increased demand for coastal crude and condensate moves and success in expanding the coastal customer base to include inland customers with coastal requirements. The acquisitions of Allied and Penn during the 2012 fourth quarter also contributed to the higher 2013 first quarter revenue and operating income.  As of March 31, 2013, the Company estimated there were approximately 268 tank barges operating in the 195,000 barrel or less coastal industry fleet. The Company believes that very few coastal tank barges were built during 2012, and that very few orders for coastal tank barges have been placed for 2013 deliveries and beyond.

In the diesel engine services segment, with the increase in drilling rigs operating in the Gulf of Mexico and relatively positive marine transportation markets during 2012, service activity levels for the marine diesel engine market reflected a modest improvement and should continue to modestly improve as activity increases. The power generation market should remain positive, benefiting from engine-generator set upgrades and parts sales for both domestic and international customers. The land-based diesel engine services market consists of manufacturing and remanufacturing of oilfield service equipment, including pressure pumping units, and servicing their components, which include high-speed diesel engines, transmissions and pumps, many of the same components used by marine customers. Currently, an estimated 17 million horsepower is employed in the North American pressure pumping business. With the current low price of natural gas, the exploration of United States natural gas shale formations has declined, resulting in excess pressure pumping horsepower. However, with the current high price of crude oil, the exploration of United States crude oil shale formations has remained active. As a result of the excess pressure pumping horsepower, new orders for pressure pumping units have essentially stopped and the supply and distribution portion of the land-based market has slowed. While the Company expects its land-based diesel engine business to remain profitable, it does not expect any significant improvement in this market until late 2013 or early 2014. The focus of the Company, currently as well as into the future, will be on the remanufacturing and service of existing pressure pumping equipment.
 
Acquisitions
 
On December 28, 2012, the Company purchased the assets of Flag for $6,864,000 in cash. Flag was an East Coast high-speed diesel engine service provider, operating factory-authorized full service marine dealerships for Caterpillar, Cummins, MTU and John Deere diesel engines. Financing of the acquisition was through the Company’s revolving credit facility.

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

On November 1, 2012, the Company purchased from Allied 10 coastal tank barges with a total capacity of 680,000 barrels, three offshore dry-bulk barges with a total capacity of 48,000 deadweight tons and seven coastal tugboats for $107,014,000 in cash, before post-closing adjustments and excluding transaction fees, including a provision for up to $10,000,000 that will be paid contingent on developments with the sugar provisions in the United States Farm Bill. The fair value of the contingent liability recorded at the acquisition date was $9,756,000. A payment of $5,000,000 was made in the 2013 first quarter on the contingent liability. Allied provided coastal transportation of petrochemicals as well as dry sugar products in the Northeast, Atlantic and Gulf Coast regions of the United States. Financing of the equipment acquisition was through the Company’s revolving credit facility.
 
 
20

 
 
 Results of Operations
 
The Company reported 2013 first quarter net earnings attributable to Kirby of $56,578,000, or $1.00 per share, on revenues of $558,785,000, compared with 2012 first quarter net earnings attributable to Kirby of $50,944,000, or $.91 per share, on revenues of $566,935,000. The 2013 first quarter results included a $4,300,000 before taxes, or $.05 per share, credit decreasing the fair value of the United contingent earnout liability associated with the April 2011 acquisition of United.  The 2012 first quarter results included a $4,200,000 before taxes, or $.05 per share, charge increasing the fair value of the United contingent earnout liability, and a $2,421,000, or $03 per share, severance charge associated with the integration of Kirby Offshore Marine’s administrative functions into the Company.
 
Marine transportation revenues for the 2013 first quarter were $418,518,000, or 75% of total revenues, compared with $335,957,000, or 59% of total revenues, for the 2012 first quarter. Diesel engine services revenues for the 2013 first quarter were $140,267,000, or 25% of total revenues, compared with $230,978,000, or 41% of total revenues, for the 2012 first quarter.
 
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 March 31, 2013, the Company operated 844 inland tank barges, including 47 leased barges, with a total capacity of 16.9 million barrels.  This compares with 806 inland tank barges operated as of March 31, 2012, including 42 leased barges, with a total capacity of 16.0 million barrels. The Company operated an average of 256 inland towboats during the 2013 first quarter, of which an average of 73 were chartered, compared with 242 during the 2012 first quarter, of which an average of 59 were chartered.  The Company’s coastal tank barge fleet as of March 31, 2013 consisted of 82 tank barges, two of which were single hull and 12 of which were chartered, with 6.3 million barrels of capacity, and 85 tugboats. This compares with 58 coastal tank barges, three of which were single hull, with 3.8 million barrels of capacity, and 65 tugboats as of March 31, 2012. The Company operates seven offshore dry-bulk barge and tugboat units, of which one of the tugboats is chartered, engaged in the offshore transportation of dry-bulk cargoes. The Company also owns a two-thirds interest in Osprey Line, L.L.C., which transports project cargoes and cargo containers by barge, as well as a 51% interest in a shifting operation and fleeting facility for dry cargo barges and tank barges on the Houston Ship Channel.
 
The following table sets forth the Company’s marine transportation segment’s revenues, costs and expenses, operating income and operating margins for the three months ended March 31, 2013 compared with the three months ended March 31, 2012 (dollars in thousands):
 
 
 
Three months ended
March 31,
 
 
 
 
 
 
2013
 
 
2012
 
 
% Change
 
Marine transportation revenues
 
$
418,518
 
 
$
335,957
 
 
 
25
%
 
 
 
 
 
 
 
 
 
 
 
 
 
Costs and expenses:
 
 
 
 
 
 
 
 
 
 
 
 
Costs of sales and operating expenses
 
 
259,229
 
 
 
203,407
 
 
 
27
 
Selling, general and administrative
 
 
28,976
 
 
 
28,519
 
 
 
2
 
Taxes, other than on income
 
 
3,910
 
 
 
3,452
 
 
 
13
 
Depreciation and amortization
 
 
37,150
 
 
 
32,089
 
 
 
16
 
 
 
 
329,265
 
 
 
267,467
 
 
 
23
 
Operating income
 
$
89,253
 
 
$
68,490
 
 
 
30
%
 
 
 
 
 
 
 
 
 
 
 
 
 
Operating margins
 
 
21.3
%
 
 
20.4
%
 
 
 
 

 
21

 
 
 Marine Transportation Revenues
 
The following table shows the marine transportation markets serviced by the Company, the marine transportation revenue distribution for the first quarter of 2013, products moved and the drivers of the demand for the products the Company transports:
 
Markets Serviced
 
2013
First Qtr.
Revenue
Distribution
 
Products Moved
 
Drivers
Petrochemicals
 
47%
 
Benzene, Styrene, Methanol, Acrylonitrile, Xylene, Caustic Soda, Butadiene, Propylene
 
Consumer non-durables —70%
Consumer durables — 30%
             
Black Oil
 
25%
 
Residual Fuel Oil, Coker Feedstock, Vacuum Gas Oil, Asphalt, Carbon Black Feedstock, Crude Oil, Ship Bunkers
 
Fuel for Power Plants and Ships, Feedstock for Refineries, Road Construction
             
Refined Petroleum Products
 
24%
 
Gasoline, No. 2 Oil, Jet Fuel, Heating Oil, Naphtha, Diesel Fuel, Ethanol
 
Vehicle Usage, Air Travel, Weather Conditions, Refinery Utilization
             
Agricultural Chemicals
 
4%
 
Anhydrous Ammonia, Nitrogen-Based Liquid Fertilizer, Industrial Ammonia
 
Corn, Cotton and Wheat Production, Chemical Feedstock Usage
              
Marine transportation revenues for the 2013 first quarter increased 25% when compared with the 2012 first quarter, reflecting the expansion of the coastal transportation business with the acquisition of Allied on November 1, 2012 and Penn on December 14, 2012. The inland tank barge fleet contributed approximately 68% and the coastal fleet approximately 32% of the 2013 first quarter marine transportation revenues.
 
The petrochemical market, the Company’s largest market, contributed 47% of the marine transportation revenues for the 2013 first quarter, reflecting continued strong volumes from Gulf Coast petrochemical plants for both domestic consumers and to terminals for export destinations.  The 2013 first quarter also includes revenues from the 10 coastal tank barges purchased from Allied that transport petrochemicals coastwise.
 
The black oil market, which contributed 25% of 2013 first quarter marine transportation revenues, also reflected continued strong demand, driven by steady refinery production levels, the export of heavy fuel oils, and demand for crude oil and condensate transportation on both the inland waterway system and coastwise.  The 2013 first quarter also includes revenues from the 18 coastal tank barges acquired with the acquisition of Penn, expanding the Company’s coastal black oil movements consisting of refinery feedstocks, asphalt and crude oil.

The refined petroleum products market, which contributed 24% of 2013 first quarter marine transportation revenues, reflected higher demand for the movements of products in the inland and coastal markets, benefiting from additional volumes from major customers.  The coastal refined products market saw overall equipment utilization in the 90% range, driven by continued success in expanding the coastal customer base to inland customers with coastal requirements, as well as colder winter weather in the Northeast that increased the demand for distillate products.

The agricultural chemical market, which contributed 4% of 2013 first quarter marine transportation revenues, saw weak demand during January and February due to winter weather and low water conditions in the Midwest.  Demand increased significantly in March for both domestically produced and imported products.
 
For the first quarter of 2013, the inland operations of the marine transportation segment incurred 2,049 delay days, 17% less than the 2,471 delay days that occurred during the 2012 first quarter, but 39% more than the 1,479 delay days that occurred during the 2012 fourth quarter. 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.
 
 During the 2013 and 2012 first quarters, approximately 75% of marine transportation’s inland revenues were under term contracts and 25% were spot contract revenues. Inland time charters during the 2013 and 2012 first quarters, which insulate the Company from revenue fluctuations caused by weather and navigational delays and temporary market declines, represented 57% and 56%, respectively, of the revenues under term contracts. The 75% term contract and 25% spot contract mix provides the marine transportation’s inland operations with a predictable revenue stream.
 
During the 2013 first quarter, approximately 70% of the coastal revenues were under term contracts and 30% were spot contract revenues. Coastal time charters represented approximately 90% of the revenues under term contracts during 2012 first quarter.  For the 2012 first quarter, approximately 60% of the coastal revenues were under term contracts and 40% were spot contract revenues.  The increase in term contracts reflected stronger demand for coastal tank barges, as well as the 2012 fourth quarter acquisitions of Allied and Penn.
 
Rates on inland term contracts renewed in the 2013 first quarter increased in the 4% to 6% average range compared with term contracts renewed in the first quarter of 2012. Spot contract rates in the 2013 first quarter, which include the cost of fuel, increased modestly compared with the 2012 fourth quarter.  Effective January 1, 2013, annual escalators for labor and the producer price index on a number of inland multi-year contracts resulted in rate increases on those contracts of approximately 1%, excluding fuel.
 
 
22

 
 
Rates on coastal term contracts renewed in the 2013 first quarter increased in the 7% to 9% average range compared with term contracts renewed in the 2012 first quarter. Spot contract rates in the 2013 first quarter, which include the cost of fuel, improved in the 5% to 9% range compared with the 2012 fourth quarter.
 
Marine Transportation Costs and Expenses
 
Costs and expenses for the 2013 first quarter increased 23% compared with the 2012 first quarter.  Costs of sales and operating expenses for the 2013 first quarter increased 27% compared with the first quarter of 2012, partially reflecting the Allied and Penn acquisitions, as well as higher costs and expenses due to increased inland and coastal marine transportation demand.
 
The inland operations operated an average of 256 towboats during the 2013 first quarter, of which an average of 73 towboats were chartered, compared with 242 during the 2012 first quarter, of which an average of 59 were chartered.  The increase in the number of towboats operated was a reflection of the higher tank barge utilization levels in the petrochemical and black oil markets during the 2013 first quarter compared with the 2012 first quarter.  As demand increases or decreases, or as weather or water conditions dictate, the Company charters-in or releases chartered towboats in an effort to balance horsepower needs with current requirements. The Company has historically used chartered towboats for approximately one-third of its horsepower requirements.
 
During the 2013 first quarter, the inland operations consumed 11.0 million gallons of diesel fuel compared to 10.9 million gallons consumed during the 2012 first quarter. The average price per gallon of diesel fuel consumed during the 2013 first quarter was $3.25 compared with $3.16 per gallon for the 2012 first quarter. Fuel escalation and de-escalation clauses are designed to rebate fuel costs when prices decline and recover additional fuel costs when fuel prices rise; however, there is generally a 30 to 90 day delay before the contracts are adjusted. Spot contracts do not have escalators for fuel.
 
Selling, general and administrative expenses for the 2013 first quarter increased 2% compared with the 2012 first quarter, reflecting the acquisition of Allied and Penn, and a $370,000 severance charge associated with the integration of Penn's administrative functions into the Company.  The 2012 first quarter included a $2,421,000 severance charge associated with the integration of Kirby Offshore Marine’s administrative functions into the Company.
 
Depreciation and amortization for the 2013 first quarter increased 16% compared with the 2012 first quarter. The increase was primarily attributable to increased capital expenditures, including new inland tank barges and towboats, and the acquisitions of Allied and Penn.
 
Marine Transportation Operating Income and Operating Margins
 
Marine transportation operating income for the 2013 first quarter increased 30% compared with the 2012 first quarter. The operating margin was 21.3% for the 2013 first quarter compared with 20.4% for the 2012 first quarter. The higher operating income and operating margin was a reflection of continued higher inland utilization, leading to higher inland term and spot contract rates negotiated throughout 2012 and the 2013 first quarter, as well as higher coastal utilization, including the Allied and Penn equipment, and higher coastal term and spot contract rates negotiated throughout the 2012 second half and the 2013 first quarter.
 
Diesel Engine Services
 
The Company, through its diesel engine services segment, sells genuine replacement parts, provides service mechanics to overhaul and repair medium-speed and high-speed diesel engines, transmissions, reduction gears, pumps and compression products, maintains facilities to rebuild component parts or entire medium-speed and high-speed diesel engines, transmissions and entire reduction gears, and manufactures and remanufactures oilfield service equipment, including pressure pumping units. The Company primarily services the marine, power generation and land-based oil and gas operator and producer markets.
 
 
23

 
 
The following table sets forth the Company’s diesel engine services segment’s revenues, costs and expenses, operating income and operating margins for the three months ended March 31, 2013 compared with the three months ended March 31, 2012 (dollars in thousands):
 
 
 
Three months ended
March 31,
 
 
 
 
 
 
2013
 
 
2012
 
 
% Change
 
Diesel engine services revenues
 
$
140,267
 
 
$
230,978
 
 
 
(39)
%
 
 
 
 
 
 
 
 
 
 
 
 
 
Costs and expenses: