Attached files

file filename
EX-10.4 - PRSU AGREEMENT - Delek US Holdings, Inc.dk-ex10410qprsuagreementx6.htm
EX-10.2 - LION FACILITY AMENDMENT - Delek US Holdings, Inc.dk-ex10210qxlionfacilityam.htm
EX-32.2 - CFO CERTIFICATION - Delek US Holdings, Inc.dk-ex322xcfocertificationx.htm
EX-32.1 - CEO CERTIFICATION - Delek US Holdings, Inc.dk-ex321xceocertificationx.htm
EX-10.1 - MAPCO AMENDED CREDIT FACILITY - Delek US Holdings, Inc.dk-ex10110qxmapcoamendment.htm
EX-31.2 - CFO CERTIFICATION - Delek US Holdings, Inc.dk-ex312xcfocertificationx.htm
EX-10.3 - SMITH OFFER LETTER - Delek US Holdings, Inc.dk-ex10310qxsmithofferlett.htm
EX-3.1 - AMENDED BYLAWS - Delek US Holdings, Inc.dk-ex3110qxamendedbylawsx6.htm
EX-31.1 - CEO CERTIFICATION - Delek US Holdings, Inc.dk-ex311xceocertificationx.htm
EXCEL - IDEA: XBRL DOCUMENT - Delek US Holdings, Inc.Financial_Report.xls
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
(Mark One)
þ
 
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
 
 
 
 
 
 
For the quarterly period ended June 30, 2014
or
o
 
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
 
 
 
 
For the transition period from                      to                     
Commission file number 001-32868
DELEK US HOLDINGS, INC.
(Exact name of registrant as specified in its charter)
Delaware
 
52-2319066
(State or other jurisdiction of
 
(I.R.S. Employer
incorporation or organization)
 
Identification No.)
 
 
 
7102 Commerce Way
 
 
Brentwood, Tennessee
 
37027
(Address of principal executive offices)
 
(Zip Code)
(615) 771-6701
(Registrant’s telephone number, including area code)
Not Applicable
(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 þ No o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act.
Large accelerated filer þ
 
Accelerated filer o
 
Non-accelerated filer o
 
Smaller reporting company o
 
 
 
 
(Do not check if a 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 o No þ
At August 1, 2014, there were 60,449,995 shares of common stock, $0.01 par value, outstanding.



TABLE OF CONTENTS
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 Exhibit 31.1
 Exhibit 31.2
 Exhibit 32.1
 Exhibit 32.2
 EX-101 INSTANCE DOCUMENT
 EX-101 SCHEMA DOCUMENT
 EX-101 CALCULATION LINKBASE DOCUMENT
 EX-101 LABELS LINKBASE DOCUMENT
 EX-101 PRESENTATION LINKBASE DOCUMENT

2


Part I.
FINANCIAL INFORMATION
Item 1.
Financial Statements

Delek US Holdings, Inc.
Condensed Consolidated Balance Sheets
 
 
June 30, 2014
 
December 31, 2013
 
 
(In millions, except share and per share data)
 
 
(Unaudited)
 
 
ASSETS
 
 
 
 
Current assets:
 
 
 
 
Cash and cash equivalents
 
$
560.1

 
$
400.0

Accounts receivable
 
304.1

 
250.5

Inventory
 
623.9

 
672.3

Other current assets
 
80.4

 
87.7

Total current assets
 
1,568.5

 
1,410.5

Property, plant and equipment:
 
 
 
 
Property, plant and equipment
 
1,841.8

 
1,683.7

Less: accumulated depreciation
 
(452.6
)
 
(405.2
)
Property, plant and equipment, net
 
1,389.2

 
1,278.5

Goodwill
 
73.9

 
72.7

Other intangibles, net
 
12.8

 
13.3

Other non-current assets
 
115.2

 
59.4

Total assets
 
$
3,159.6

 
$
2,834.4

LIABILITIES AND STOCKHOLDERS’ EQUITY
 
 
 
 
Current liabilities:
 
 
 
 
Accounts payable
 
$
607.5

 
$
602.0

Current portion of long-term debt and capital lease obligations
 
49.0

 
33.7

Obligation under Supply and Offtake Agreement
 
338.8

 
331.0

Accrued expenses and other current liabilities
 
129.1

 
114.1

Total current liabilities
 
1,124.4

 
1,080.8

Non-current liabilities:
 
 
 
 
Long-term debt and capital lease obligations, net of current portion
 
567.2

 
376.6

Environmental liabilities, net of current portion
 
8.8

 
9.2

Asset retirement obligations
 
8.9

 
8.5

Deferred tax liabilities
 
233.2

 
220.0

Other non-current liabilities
 
18.4

 
18.9

Total non-current liabilities
 
836.5

 
633.2

Stockholders’ equity:
 
 
 
 
Preferred stock, $0.01 par value, 10,000,000 shares authorized, no shares issued and outstanding
 

 

Common stock, $0.01 par value, 110,000,000 shares authorized, 60,448,243 shares and 60,229,107 shares issued at June 30, 2014 and December 31, 2013, respectively
 
0.6

 
0.6

Additional paid-in capital
 
388.4

 
384.5

Accumulated other comprehensive income
 
12.9

 
(4.0
)
Treasury stock, 1,260,244 and 1,000,000 shares, at cost, as of June 30, 2014 and December 31, 2013, respectively.
 
(45.8
)
 
(37.9
)
Retained earnings
 
650.6

 
591.8

Non-controlling interest in subsidiaries
 
192.0

 
185.4

Total stockholders’ equity
 
1,198.7

 
1,120.4

Total liabilities and stockholders’ equity
 
$
3,159.6

 
$
2,834.4

See accompanying notes to condensed consolidated financial statements

3


Delek US Holdings, Inc.
Condensed Consolidated Statements of Income (Unaudited)
 
 
Three Months Ended
 
Six Months Ended
 
 
June 30,
 
June 30,
 
 
2014
 
2013
 
2014
 
2013
 
 
(In millions, except share and per share data)
 
 
 
 
Net sales
 
$
2,374.7

 
$
2,187.4

 
$
4,240.4

 
$
4,447.3

Operating costs and expenses:
 
 
 
 
 
 
 
 
Cost of goods sold
 
2,105.3

 
1,966.1

 
3,745.7

 
3,938.3

Operating expenses
 
102.3

 
95.3

 
200.8

 
194.0

General and administrative expenses
 
32.9

 
28.1

 
67.4

 
60.7

Depreciation and amortization
 
28.2

 
21.6

 
52.8

 
43.6

Other operating income, net
 

 
(1.5
)
 

 
(1.5
)
Total operating costs and expenses
 
2,268.7

 
2,109.6

 
4,066.7

 
4,235.1

Operating income
 
106.0

 
77.8

 
173.7

 
212.2

Interest expense
 
10.1

 
9.2

 
19.7

 
18.4

Interest income
 

 
(0.1
)
 
(0.4
)
 
(0.2
)
Other expense (income), net
 
0.1

 
(6.7
)
 

 
(6.7
)
Total non-operating expenses, net
 
10.2

 
2.4

 
19.3

 
11.5

Income from continuing operations before income taxes
 
95.8

 
75.4

 
154.4

 
200.7

Income tax expense
 
32.6

 
24.4

 
51.9

 
67.6

Net income
 
63.2

 
51.0

 
102.5

 
133.1

Net income attributed to non-controlling interest
 
8.3

 
4.4

 
13.9

 
9.0

Net income attributable to Delek
 
$
54.9

 
$
46.6

 
$
88.6

 
$
124.1

Basic earnings per share
 
$
0.93

 
$
0.79

 
$
1.49

 
$
2.09

Diluted earnings per share
 
$
0.92

 
$
0.78

 
$
1.48

 
$
2.06

Weighted average common shares outstanding:
 
 
 
 
 
 
 
 
Basic
 
59,283,465

 
58,925,800

 
59,266,256

 
59,246,988

Diluted
 
59,875,261

 
59,830,885

 
59,869,979

 
60,255,526

Dividends declared per common share outstanding
 
$
0.25

 
$
0.25

 
$
0.50

 
$
0.45

See accompanying notes to condensed consolidated financial statements

4


Delek US Holdings, Inc.
Condensed Consolidated Statements of Comprehensive Income (Unaudited)

 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2014
 
2013
 
2014
 
2013
 
 
(In millions)
Net income attributable to Delek
 
$
54.9

 
$
46.6

 
$
88.6

 
$
124.1

Other comprehensive income:
 
 
 
 
 
 
 
 
Net gain (loss) on derivative instruments, net of tax (expense) benefit of $(0.6) million and $(9.6) million for the three and six months ended June 30, 2014, respectively, and $0.2 million for the six months ended June 30, 2013 and net of ineffectiveness of $11.1 million and $14.2 million for the three and six months ended June 30, 2014, respectively. There was no ineffectiveness for the three or six months ended June 30, 2013.
 
1.2

 

 
16.9

 
(0.4
)
Comprehensive income attributable to Delek
 
$
56.1

 
$
46.6

 
$
105.5

 
$
123.7


See accompanying notes to condensed consolidated financial statements


5


Delek US Holdings, Inc.
Condensed Consolidated Statements of Cash Flows (Unaudited)
 
 
Six Months Ended June 30,
 
 
2014
 
2013
Cash flows from operating activities:
 
(In millions, except per share data)
Net income
 
$
102.5

 
$
133.1

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
 
Depreciation and amortization
 
52.8

 
43.6

Amortization of deferred financing costs
 
2.6

 
2.7

Accretion of asset retirement obligations
 
0.3

 
0.3

Amortization of unfavorable contract liability
 
(1.3
)
 
(1.3
)
Deferred income taxes
 
9.0

 
5.7

Equity-based compensation expense
 
6.6

 
5.2

Income tax benefit of equity-based compensation
 
(1.3
)
 
(5.0
)
Changes in assets and liabilities, net of acquisitions:
 
 
 
 
Accounts receivable, net
 
(53.6
)
 
(48.5
)
Inventories and other current assets
 
51.7

 
(150.5
)
Accounts payable and other current liabilities
 
48.3

 
24.2

Obligation under Supply and Offtake Agreement, net
 
7.8

 
39.8

Non-current assets and liabilities, net
 
(53.4
)
 
3.8

Net cash provided by operating activities
 
172.0

 
53.1

Cash flows from investing activities:
 
 
 
 
Business combinations
 
(11.1
)
 
(5.4
)
Purchases of property, plant and equipment
 
(153.4
)
 
(64.5
)
Proceeds from sales of assets
 
0.2

 
0.7

Net cash used in investing activities
 
(164.3
)
 
(69.2
)
Cash flows from financing activities:
 
 
 
 
Proceeds from long-term revolvers
 
691.2

 
162.2

Payments on long-term revolvers
 
(570.5
)
 
(186.2
)
Proceeds from term debt
 
99.9

 
5.4

Payments on term debt and capital lease obligations
 
(14.4
)
 
(49.4
)
Proceeds from exercise of stock options
 
0.7

 
1.0

Taxes paid due to the net settlement of equity-based compensation
 
(4.1
)
 
(2.5
)
Income tax benefit of equity-based compensation
 
1.3

 
5.0

Repurchase of common stock
 
(7.9
)
 
(37.9
)
Distribution to non-controlling interest
 
(7.9
)
 
(5.6
)
Dividends paid
 
(29.8
)
 
(27.0
)
Deferred financing costs paid
 
(6.1
)
 
(0.5
)
Net cash provided by (used in) financing activities
 
152.4

 
(135.5
)
Net increase (decrease) in cash and cash equivalents
 
160.1

 
(151.6
)
Cash and cash equivalents at the beginning of the period
 
400.0

 
601.7

Cash and cash equivalents at the end of the period
 
$
560.1

 
$
450.1

Supplemental disclosures of cash flow information:
 
 
 
 
Cash paid during the period for:
 
 
 
 
Interest, net of capitalized interest of $0.7 million and $0.3 million in the 2014 and 2013 periods, respectively.
 
$
17.5

 
$
15.8

Income taxes
 
$
41.4

 
$
44.1


See accompanying notes to condensed consolidated financial statements

6


Delek US Holdings, Inc.
Notes to Condensed Consolidated Financial Statements (Unaudited)
1. Organization and Basis of Presentation
Delek US Holdings, Inc. is the sole shareholder or owner of membership interests of Delek Refining, Inc. ("Refining"), Delek Finance, Inc., Delek Marketing & Supply, LLC ("Marketing"), Lion Oil Company ("Lion Oil"), Delek Renewables, LLC, Delek Rail Logistics, Inc., Delek Logistics Services Company, MAPCO Express, Inc. ("MAPCO Express"), MAPCO Fleet, Inc., NTI Investments, LLC, GDK Bearpaw, LLC, Delek Helena, LLC, Commerce Way Insurance Company, Inc. and Delek Land Holdings, LLC. Unless otherwise indicated or the context requires otherwise, the terms "we," "our," "us," "Delek" and "Company" are used in this report to refer to Delek US Holdings, Inc. and its consolidated subsidiaries. Delek is listed on the New York Stock Exchange under the symbol "DK."
Our condensed consolidated financial statements include Delek Logistics Partners, LP ("Delek Logistics"), a variable interest entity. Because our consolidated subsidiary, Delek Logistics GP, LLC ("Logistics GP"), is the general partner of Delek Logistics, we have the ability to direct the activities of Delek Logistics that most significantly impact its economic performance. We are also considered to be the primary beneficiary for accounting purposes and are Delek Logistics' primary customer. Delek Logistics does not derive an amount of gross margin material to us from third parties. However, in the event that Delek Logistics incurs a loss, our operating results will reflect Delek Logistics' loss, net of intercompany eliminations, to the extent of our ownership interest in Delek Logistics.
The condensed consolidated financial statements include the accounts of Delek and its consolidated subsidiaries. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles ("GAAP") have been condensed or omitted, although management believes that the disclosures herein are adequate to make the financial information presented not misleading. Our unaudited condensed consolidated financial statements have been prepared in conformity with GAAP applied on a consistent basis with those of the annual audited financial statements included in our Annual Report on Form 10-K filed with the Securities and Exchange Commission ("SEC") on March 3, 2014, as amended by Amendment No. 1 on Form 10-K/A that was filed with the SEC on June 26, 2014 (collectively, the "Annual Report on Form 10-K") and in accordance with the rules and regulations of the SEC. These unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and the notes thereto for the year ended December 31, 2013 included in our Annual Report on Form 10-K.
In the opinion of management, all adjustments necessary for a fair presentation of the financial position and the results of operations for the interim periods have been included. All significant intercompany transactions and account balances have been eliminated in consolidation. All adjustments are of a normal, recurring nature. Operating results for the interim period should not be viewed as representative of results that may be expected for any future interim period or for the full year.
Certain prior period amounts have been reclassified in order to conform to the current year presentation. These reclassifications had no effect on net income or shareholders' equity as previously reported.
The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
New Accounting Pronouncements
On January 1, 2014 we adopted guidance issued by the Financial Accounting Standards Board regarding "Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists" to eliminate diversity in practice. This guidance requires that companies net their unrecognized tax benefits against all same-jurisdiction net operating losses or tax credit carryforwards that would be used to settle the position with a tax authority. The adoption of this guidance did not materially affect our business, financial position or results of operations.
 

7


2. Delek Logistics Partners, LP
On November 7, 2012, Delek Logistics, then a wholly owned, indirect subsidiary of Delek, closed its initial public offering (the "DKL Offering") of 9,200,000 common units. Headquartered in Brentwood, Tennessee, Delek Logistics was formed by Delek to own, operate, acquire and construct crude oil and refined products logistics and marketing assets. Delek Logistics' initial assets were contributed by us in connection with the DKL Offering and included certain assets formerly owned or used by our subsidiaries, including Delek Marketing & Supply, Inc., Lion Oil and Paline Pipeline Company, LLC. A substantial majority of Delek Logistics' assets are currently integral to Delek’s refining and marketing operations.
In July 2013, Delek Logistics completed the acquisition of a terminal, storage tanks and related assets adjacent to our refinery in Tyler, Texas (the "Tyler refinery") from one of our subsidiaries (the "Tyler Acquisition"). The cash paid for the assets acquired was approximately $94.8 million, financed with a combination of proceeds from the amended and restated Delek Logistics revolving credit agreement and cash on hand.

In February 2014, a subsidiary of Delek Logistics completed the acquisition of certain storage tanks and the products terminal located at our refinery in El Dorado, Arkansas (the "El Dorado refinery") from Lion Oil (the "El Dorado Acquisition"). The cash paid for the assets acquired was approximately $95.9 million, financed with borrowings under the amended and restated Delek Logistics revolving credit agreement. The storage tanks have approximately 2.5 million barrels of aggregate shell capacity and consist of 158 tanks and ancillary assets, including piping and pumps.

The Tyler Acquisition and the El Dorado Acquisition are both considered a transfer of a business between entities under common control. As such, the assets acquired and liabilities assumed were transferred to Delek Logistics at historical basis instead of fair value.
As of June 30, 2014, we owned a 60.0% limited partner interest in Delek Logistics, and a 96.1% interest in Logistics GP, which owns the 2.0% general partner interest in Delek Logistics and all of the incentive distribution rights. Delek's partnership interest in Delek Logistics includes 2,799,258 common units, 11,999,258 subordinated units and 493,533 general partner units.
We have agreements with Delek Logistics that, among other things, establish fees for certain administrative and operational services provided by us and our subsidiaries to Delek Logistics, provide certain indemnification obligations and establish terms for fee-based commercial logistics and marketing services provided by Delek Logistics and its subsidiaries to us.

8


With the exception of affiliate balances which are eliminated in consolidation, the Delek Logistics condensed consolidated balance sheets as of June 30, 2014 and December 31, 2013, as presented below, are included in the consolidated balance sheets of Delek.
 
 
June 30,
2014
 
December 31, 2013(1)
 
 
 
 
 
(In millions)
 
 
(Unaudited)
ASSETS
 
 
 
 
Cash and cash equivalents
 
$
2.4

 
$
0.9

Accounts receivable
 
38.0

 
29.0

Inventory
 
24.8

 
17.5

Other current assets
 
0.8

 
0.3

Net property, plant and equipment
 
220.6

 
225.8

Goodwill
 
11.7

 
10.5

Intangible assets, net
 
11.8

 
12.3

Other non-current assets
 
4.3

 
5.0

Total assets
 
$
314.4

 
$
301.3

LIABILITIES AND EQUITY
 
 
 
 
Accounts payable
 
$
39.7

 
$
26.0

Accounts payable to related parties
 
2.6

 
1.5

Accrued expenses and other current liabilities
 
16.0

 
12.2

Revolving credit facility
 
239.0

 
164.8

Asset retirement obligations
 
3.2

 
3.1

Deferred tax liabilities
 
0.4

 
0.3

Other non-current liabilities
 
5.6

 
6.2

Equity
 
7.9

 
87.2

Total liabilities and equity
 
$
314.4

 
$
301.3

                
(1)These amounts have been restated to reflect the assets and liabilities acquired in the El Dorado Acquisition.

3. Acquisitions
Crossett Biodiesel Facility Acquisition

On January 2, 2014, we purchased a biodiesel plant in Crossett, Arkansas (the "Crossett Facility") from Pinnacle Biofuels, Inc. for approximately $11.1 million, which has been preliminarily allocated to property, plant and equipment.  The property, plant and equipment valuation is subject to change during the purchase price allocation period. The Crossett Facility has a production capacity of approximately 10.0 million gallons per year. The Crossett Facility produced biodiesel exclusively for Delek under a tolling agreement prior to this acquisition.
4. Inventory
Refinery inventory consists of crude oil, in-process, refined products and blendstocks which are stated at the lower of cost or market. Cost of inventory for the Tyler refinery is determined under the last-in, first-out ("LIFO") valuation method. Cost of crude oil, in-process, refined product and feedstock inventories in excess of market value is charged to cost of goods sold. Cost of inventory for the operations of Lion Oil is determined on a first-in, first-out ("FIFO") basis.
Logistics inventory consists of refined products which are stated at the lower of cost or market on a FIFO basis.
Retail inventory consists of gasoline, diesel fuel, other petroleum products, cigarettes, beer, convenience merchandise and food service merchandise. Fuel inventories are stated at the lower of cost or market on a FIFO basis. Non-fuel inventories are stated at estimated cost as determined by the retail inventory method.

9


Carrying value of inventories consisted of the following (in millions):
 
 
June 30,
2014
 
December 31,
2013
Refinery raw materials and supplies
 
$
269.0

 
$
250.9

Refinery work in process
 
77.5

 
58.6

Refinery finished goods
 
206.1

 
299.2

Retail fuel
 
19.4

 
19.2

Retail merchandise
 
27.1

 
26.9

Logistics refined products
 
24.8

 
17.5

Total inventories
 
$
623.9

 
$
672.3

At June 30, 2014 and December 31, 2013, the excess of replacement cost (FIFO) over the carrying value (LIFO) of the Tyler refinery inventories was $52.0 million and $51.5 million, respectively.
Permanent Liquidations
During the three and six months ended June 30, 2014, we incurred a permanent reduction in a LIFO layer resulting in a liquidation (loss) gain in our refinery inventory of $(1.8) million and $2.3 million, respectively. These liquidations were recognized as a component of cost of goods sold in the three and six months ended June 30, 2014.
During both the three and six months ended June 30, 2013, we incurred a permanent reduction in a LIFO layer resulting in a liquidation loss in our refinery inventory of a $0.7 million. These liquidations were recognized as a component of cost of goods sold in the three and six months ended June 30, 2013.
5. Crude Oil Supply and Inventory Purchase Agreement
Delek has a Master Supply and Offtake Agreement (the "Supply and Offtake Agreement") with J. Aron & Company ("J. Aron"). Throughout the term of the Supply and Offtake Agreement, which was amended on December 23, 2013 to expire on April 30, 2017, Lion Oil and J. Aron will identify mutually acceptable contracts for the purchase of crude oil from third parties and J. Aron will supply up to 100,000 barrels per day ("bpd") of crude to the El Dorado refinery. Crude oil supplied to the El Dorado refinery by J. Aron will be purchased daily at an estimated average monthly market price by Lion Oil. J. Aron will also purchase all refined products from the El Dorado refinery at an estimated market price daily, as they are produced. These daily purchases and sales are trued-up on a monthly basis in order to reflect actual average monthly prices. We have recorded a receivable related to this settlement of $13.4 million and $18.2 million as of June 30, 2014 and December 31, 2013, respectively, which is included in accounts receivable on the condensed consolidated balance sheet. Also pursuant to the Supply and Offtake Agreement and other related agreements, Lion Oil will endeavor to arrange potential sales by either Lion Oil or J. Aron to third parties of the products produced at the El Dorado refinery or purchased from third parties. In instances where Lion Oil is the seller to such third parties, J. Aron will first transfer the applicable products to Lion Oil.
While title to the inventories will reside with J. Aron, this arrangement will be accounted for as a product financing arrangement. Delek incurred fees payable to J. Aron of $2.6 million and $5.0 million during the three and six months ended June 30, 2014, respectively, and $2.1 million and $4.2 million during the three and six months ended June 30, 2013, respectively. These amounts are included as a component of interest expense in the condensed consolidated statements of income. Upon any termination of the Supply and Offtake Agreement, including in connection with a force majeure event, the parties are required to negotiate with third parties for the assignment to us of certain contracts, commitments and arrangements, including procurement contracts, commitments for the sale of product, and pipeline, terminalling, storage and shipping arrangements.
Upon the expiration of the Supply and Offtake Agreement on April 30, 2017 or upon any earlier termination, Delek will be required to repurchase the consigned crude oil and refined products from J. Aron at then prevailing market prices. At June 30, 2014, Delek had 3.3 million barrels of inventory consigned for J. Aron and we have recorded liabilities associated with this consigned inventory of $338.8 million in the condensed consolidated balance sheet.


10


6. Long-Term Obligations and Notes Payable
Outstanding borrowings under Delek’s existing debt instruments and capital lease obligations are as follows (in millions):
 
 
June 30,
2014
 
December 31,
2013
MAPCO Revolver
 
$
107.0

 
$
67.5

DKL Revolver
 
239.0

 
164.8

Wells Term Loan
 
70.0

 

Reliant Bank Revolver
 
17.0

 
10.0

Promissory notes
 
73.0

 
77.4

Lion Term Loan, net of $0.3 million debt discount at June 30, 2014
 
109.7

 
90.0

Capital lease obligations
 
0.5

 
0.6

 
 
616.2

 
410.3

Less: Current portion of long-term debt, notes payable and capital lease obligations
 
49.0

 
33.7

 
 
$
567.2

 
$
376.6

MAPCO Revolver
Our subsidiary, MAPCO Express, has a revolving credit facility with Fifth Third Bank, as administrative agent, and a syndicate of lenders that was amended and restated on May 6, 2014 (the "MAPCO Revolver"). The MAPCO Revolver consists of a $160.0 million revolving credit limit which includes (i) a $10.0 million swing line loan sub-limit; (ii) a $40.0 million letter of credit sub-limit; and (iii) an accordion feature which permits an increase in borrowings by up to $50.0 million, subject to additional lender commitments. As of June 30, 2014, we had $107.0 million outstanding under the MAPCO Revolver, as well as letters of credit issued of $2.6 million, with approximately $50.4 million availability remaining. Borrowings under the MAPCO Revolver are secured by (i) substantially all the assets of MAPCO Express and its subsidiaries, subject to certain exceptions and limitations, (ii) all of Delek’s shares in MAPCO Express and (iii) a limited guaranty provided by Delek of up to $50.0 million in obligations. The MAPCO Revolver will mature on May 6, 2019. The MAPCO Revolver bears interest based on predetermined pricing grids which allow us to choose between base rate loans or London Interbank Offered Rate ("LIBOR") rate loans. At June 30, 2014, the weighted average borrowing rate was approximately 3.66%. Additionally, the MAPCO Revolver requires us to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of June 30, 2014, this fee was 0.35% per year.
Wells ABL
Our subsidiary, Delek Refining, Ltd. has an asset-based loan credit facility with Wells Fargo Bank, National Association, as administrative agent, and a syndicate of lenders (the "Wells ABL") that consists of (i) a $600 million revolving loan (the "Wells Revolving Loan"), which includes a $55.0 million swing line loan sub-limit and a $550.0 million letter of credit sub-limit, (ii) a $70.0 million delayed single draw term loan (the "Wells Term Loan") and (iii) an accordion feature which permits an increase in revolving credit commitments of up to $875.0 million subject to additional lender commitments and the satisfaction of certain other conditions precedent. The Wells Revolving Loan matures on January 16, 2019 and the Wells Term Loan matures on December 31, 2016. The Wells Term Loan is subject to repayment in level principal installments of approximately $5.8 million per quarter beginning December 31, 2014, with a final balloon payment due on December 31, 2016. As of June 30, 2014, under the Wells ABL we had letters of credit issued totaling approximately $123.7 million and no revolving borrowed amounts outstanding; under the Wells Term Loan we had $70.0 million outstanding. Borrowings under the Wells ABL are secured by substantially all the assets of Refining and its subsidiaries, with certain limitations. Under the facility, revolving loans and letters of credit are provided subject to availability requirements which are determined pursuant to a borrowing base calculation as defined in the credit agreement. The borrowing base as calculated is primarily supported by cash, certain accounts receivable and certain inventory. Borrowings under the Wells Revolving Loan and Wells Term Loan bear interest based on separate predetermined pricing grids which allow us to choose between base rate loans or LIBOR rate loans. At June 30, 2014, the weighted average borrowing rate under the Wells Term Loan was approximately 3.90%. Additionally, the Wells ABL requires us to pay a quarterly credit utilization fee. As of June 30, 2014, this fee was approximately 0.38% per year. Borrowing capacity, as calculated and reported under the terms of the Wells ABL credit facility, as of June 30, 2014, was $350.5 million.

11


DKL Revolver
Delek Logistics has a $400.0 million Senior Secured Revolving Credit Agreement with Fifth Third Bank, as administrative agent, and a syndicate of lenders (the "DKL Revolver"). Delek Logistics and each of its existing subsidiaries are borrowers under the DKL Revolver. The DKL Revolver contains a dual currency borrowing tranche that permits draw downs in U.S. or Canadian dollars and an accordion feature whereby Delek Logistics can increase the size of the credit facility to an aggregate of $450.0 million, subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions precedent.
The obligations under the DKL Revolver are secured by a first priority lien on substantially all of Delek Logistics' tangible and intangible assets. Additionally, a subsidiary of Delek provides a limited guaranty of Delek Logistics' obligations under the DKL Revolver. The guaranty is (i) limited to an amount equal to the principal amount, plus unpaid and accrued interest, of a promissory note made by Delek in favor of the subsidiary guarantor (the "Holdings Note") and (ii) secured by the subsidiary guarantor's pledge of the Holdings Note to the DKL Revolver lenders. As of June 30, 2014, the principal amount of the Holdings Note was $102.0 million.
The DKL Revolver will mature on November 7, 2017. Borrowings under the DKL Revolver bear interest at either a U.S. base rate, Canadian prime rate, LIBOR rate, or a Canadian Dealer Offered Rate ("CDOR") rate plus applicable margins, at the election of the borrowers and as a function of draw down currency. The applicable margin varies based upon Delek Logistics' Leverage Ratio, which is defined as the ratio of total funded debt to EBITDA for the most recently ended four fiscal quarters. At June 30, 2014, the weighted average borrowing rate was approximately 2.70%. Additionally, the DKL Revolver requires us to pay a leverage ratio dependent quarterly fee on the average unused revolving commitment. As of June 30, 2014, this fee was 0.50% per year. As of June 30, 2014, Delek Logistics had $239.0 million of outstanding borrowings under the DKL Revolver, as well as letters of credit issued of $13.5 million. Amounts available under the DKL Revolver, as of June 30, 2014, were approximately $147.5 million.
Reliant Bank Revolver
We have a revolving credit agreement with Reliant Bank which was amended on June 26, 2014 (the "Reliant Bank Revolver"). The Reliant Bank Revolver provides for unsecured loans of up to $17.0 million. As of June 30, 2014, we had $17.0 million outstanding under this facility. The Reliant Bank Revolver matures on June 28, 2016, and bears interest at a fixed rate of 5.25% per annum. The Reliant Bank Revolver requires us to pay a quarterly fee of 0.50% per year on the average available revolving commitment. As of June 30, 2014, the weighted average borrowing rate was 5.25%. As of June 30, 2014, we had no undrawn amounts available under the Reliant Bank Revolver.
Promissory Notes
In 2011, Delek began construction on new MAPCO Mart convenience stores (each a "Build-to-Suit Development" or "BTS"). In order to fund these construction projects, we entered into separate notes for each BTS project with Standard Insurance Company (collectively, the "Notes") varying in size from $1.0 million to $2.2 million. The Notes bear interest at fixed rates, ranging from 5.00% to 6.38% per annum. Each of the Notes is secured by the land or leasehold interest, as applicable, and the building and equipment of its respective completed MAPCO Mart. Under the terms of each Note, beginning on the first day of the eleventh month following the initial fund advancement, payments of principal on each respective Note are due over a ten-year term calculated using a 25-year amortization schedule. If any Note is not paid in full after the initial ten-year period, we may continue to make monthly payments under the Note; however, the interest rate will reset pursuant to the terms of the Note. There is also an additional interest rate reset after the first 20-year period. The final maturity dates of the Notes range from June 1, 2036 to November 1, 2039. As of June 30, 2014, we had amounts drawn under 29 Notes related to these BTS projects, for a total amount of approximately $38.8 million outstanding under the Notes.
On April 29, 2011, Delek entered into a $50.0 million promissory note (the "Ergon Note") with Ergon, Inc. ("Ergon") in connection with the closing of our acquisition of Lion Oil. As of June 30, 2014, $30.0 million was outstanding under the Ergon Note. The Ergon Note requires Delek to make annual amortization payments of $10.0 million each commencing April 29, 2013. The Ergon Note matures on April 29, 2017. Interest under the Ergon Note is computed at a fixed rate equal to 4.00% per annum.
On December 19, 2011, Delek entered into a $25.0 million promissory note (the "Ergon Paline Note") with Ergon Terminaling, Inc. ("Ergon Terminaling") in connection with the closing of the acquisition of all of the membership interests of Paline from Ergon Terminaling. The Ergon Paline Note was subsequently assigned by Ergon Terminaling to Ergon. As of June 30, 2014, $4.2 million was outstanding under the Ergon Paline Note. The Ergon Paline Note requires Delek to make quarterly amortization payments of approximately $2.1 million each commencing on March 31, 2012. The Ergon Paline Note matures on December 19, 2014. Interest under the Ergon Paline Note is computed at a fixed rate equal to 6.00% per annum.

12


Lion Term Loan
Our subsidiary, Lion Oil, has a term loan credit facility (the "Lion Term Loan") with Israel Discount Bank of New York, Bank Hapoalim B.M and Fifth Third Bank as the lenders. The Lion Term Loan was amended on June 23, 2014 to add Fifth Third Bank as an additional lender in the principal amount of $20.0 million, thereby increasing the total loan size to $110.0 million. As of June 30, 2014, $110.0 million was outstanding under the Lion Term Loan. The Lion Term Loan requires Delek to make quarterly amortization payments of $5.5 million each commencing on December 31, 2014. The Lion Term Loan matures on December 18, 2018, and is secured by (i) all assets of Lion Oil (excluding inventory and accounts receivable), (ii) all of our shares in Lion Oil, and (iii) a first priority lien on the subordinated and common units of Delek Logistics held by Lion Oil. Interest on the unpaid balance of the Lion Term Loan is computed at a rate per annum equal to the LIBOR Rate or the Reference Rate, at our election, plus the applicable margins, subject in each case to an interest rate floor of 5.50% per annum. As of June 30, 2014, the weighted average borrowing rate was 5.50%.
Restrictive Covenants
Under the terms of our MAPCO Revolver, Wells ABL, DKL Revolver, Reliant Bank Revolver and Lion Term Loan we are required to comply with certain usual and customary financial and non-financial covenants. Further, although we were not required to comply with a fixed charge coverage ratio financial covenant under the Wells ABL during the three months ended June 30, 2014, we may be required to comply with this covenant at times when the borrowing base excess availability is less than certain thresholds, as defined in the Wells ABL. We believe we were in compliance with all covenant requirements under each of our credit facilities as of June 30, 2014.
Certain of our credit facilities contain limitations on the incurrence of additional indebtedness, making of investments, creation of liens, dispositions of property, making of restricted payments and transactions with affiliates. Specifically, these covenants may limit the payment, in the form of cash or other assets, of dividends or other distributions, or the repurchase of shares with respect to the equity of our subsidiaries. Additionally, certain of our credit facilities limit our ability to make investments, including extensions of loans or advances to, or acquisition of equity interests in, or guarantees of obligations of, any other entities.
Interest-Rate Derivative Instruments
Delek entered into interest rate swap and cap agreements for a total notional amount of $205.0 million. These agreements are intended to economically hedge floating interest rate risk related to our current debt. However, as we have elected to not apply the permitted hedge accounting treatment, including formal hedge designation and documentation, in accordance with the provisions of ASC 815, Derivatives and Hedging ("ASC 815"), the fair value of the derivatives is recorded in other non-current liabilities in the accompanying condensed consolidated balance sheets with the offset recognized in earnings. The derivative instruments mature in 2015 and 2016. The estimated mark-to-market liability associated with our interest rate derivatives, as of June 30, 2014 and December 31, 2013, was $2.0 million and $2.7 million, respectively.
In accordance with ASC 815, we recorded non-cash income representing the change in estimated fair value of the interest rate swap and cap agreements of $0.4 million and $0.7 million for the three and six months ended June 30, 2014, respectively, and $0.8 million and $1.2 million for the three and six months ended June 30, 2013, respectively.
While Delek has not elected to apply permitted hedge accounting treatment for these interest rate derivatives in accordance with the provisions of ASC 815 in the past, we may choose to apply that treatment for future transactions.
7. Income Taxes
At June 30, 2014, Delek had unrecognized tax benefits of $0.3 million that, if recognized, would affect our effective tax rate. Delek recognizes accrued interest and penalties related to unrecognized tax benefits as an adjustment to the current provision for income taxes. Interest of a nominal amount was recognized related to unrecognized tax benefits during both the three and six months ended June 30, 2014 and 2013.

13


8. Stockholders' Equity

Changes to equity during the six months ended June 30, 2014 are presented below (in millions):
 
 
Delek Stockholders' Equity
 
Non-Controlling Interest in Subsidiaries
 
Total Stockholders' Equity
Balance at December 31, 2013
 
$
935.0

 
$
185.4

 
$
1,120.4

Net income
88.6

 
13.9

 
102.5

Unrealized gain on cash flow hedges, net of deferred income tax expense of $9.6 million and ineffectiveness of $14.2 million
16.9

 

 
16.9

Common stock dividends ($0.50 per share)
(29.8
)
 

 
(29.8
)
Distribution to non-controlling interest

 
(7.9
)
 
(7.9
)
Equity-based compensation expense
6.0

 
0.6

 
6.6

Purchase of common stock
(7.9
)
 

 
(7.9
)
Income tax benefit of equity-based compensation expense
1.3

 

 
1.3

Taxes paid due to the net settlement of equity-based compensation
(4.1
)
 

 
(4.1
)
Exercise of equity-based awards
0.7

 

 
0.7

Balance at June 30, 2014
 
$
1,006.7

 
$
192.0

 
$
1,198.7


Dividends

During the six months ended June 30, 2014, our Board of Directors declared the following dividends:

Date Declared
 
Dividend Amount Per Share
 
Record Date
 
Payment Date
February 25, 2014
 
$0.15
 
March 11, 2014
 
March 25, 2014
March 13, 2014
 
$0.10
 
April 3, 2014
 
April 24, 2014
May 6, 2014
 
$0.15
 
May 27, 2014
 
June 17, 2014
June 11, 2014
 
$0.10
 
June 26, 2014
 
July 17, 2014

Stock Repurchase Program

On March 13, 2014, we announced that our Board of Directors had authorized a $50.0 million common stock repurchase program. The repurchases are intended to be implemented through open market transactions or in privately negotiated transactions, in accordance with applicable securities laws. The timing, price, and size of repurchases will be made at the discretion of management and will depend upon prevailing market prices, general economic and market conditions and other considerations. The stock repurchase program does not obligate us to acquire any particular amount of stock and the authorization under the stock repurchase program will expire on December 31, 2014. During the three and six months ended June 30, 2014, we repurchased 260,244 shares of common stock, for a total of $7.9 million, under the stock repurchase program. See Note 15 for additional information regarding the stock repurchase program.



14


9. Equity Based Compensation
Delek US Holdings, Inc. 2006 Long-Term Incentive Plan
Compensation expense for equity-based awards amounted to $2.9 million ($1.9 million, net of taxes) and $5.5 million ($3.6 million, net of taxes) for the three and six months ended June 30, 2014, respectively, and $2.3 million ($1.5 million, net of taxes) and $4.3 million ($2.8 million, net of taxes) for the three and six months ended June 30, 2013, respectively. These amounts are included in general and administrative expenses in the accompanying condensed consolidated statements of income.
As of June 30, 2014, there was $30.7 million of total unrecognized compensation cost related to non-vested share-based compensation arrangements, which is expected to be recognized over a weighted-average period of 2.6 years.
We issued 138,954 and 219,136 shares of common stock as a result of exercised stock options, stock appreciation rights, and vested restricted stock units during the three and six months ended June 30, 2014, respectively, and 222,921 and 437,677 shares of common stock during the three and six months ended June 30, 2013, respectively. These amounts do not include shares withheld to satisfy employee tax obligations related to the exercises and vestings. These withheld shares totaled 57,835 and 115,987 shares during the three and six months ended June 30, 2014, respectively, and 105,341 and 263,973 during the three and six months ended June 30, 2013, respectively.
Delek Logistics, GP, LLC 2012 Long-Term Incentive Plan
Compensation expense for these awards was $0.4 million ($0.3 million, net of taxes) and $0.8 million ($0.5 million, net of taxes) for the three and six months ended June 30, 2014, respectively, and $0.9 million ($0.6 million, net of taxes) for both the three and six months ended June 30, 2013, respectively. These amounts are included in general and administrative expenses in the accompanying condensed consolidated statements of income.
As of June 30, 2014, there was $5.0 million of total unrecognized compensation cost related to non-vested share-based compensation arrangements, which is expected to be recognized over a weighted-average period of 3.4 years.
Granting of GP Interest
On March 10, 2013, we granted membership interests in Logistics GP, the general partner of Delek Logistics, to certain executives, including Ezra Uzi Yemin, our Chairman, President and Chief Executive Officer. These interests consisted of a total 1.4% membership interest in Logistics GP and vested on June 10, 2013. On December 10, 2013, we granted Mr. Yemin an additional 4.0% membership interest in Logistics GP. Half of the 4.0% vested immediately, 0.50% vested on June 10, 2014 and, subject to Mr. Yemin's continued employment with Delek, 0.25% will vest every six months following June 10, 2014 through June 10, 2017. Total compensation expense recognized for these grants amounted to $0.1 million ($0.1 million, net of taxes) and $0.3 million ($0.2 million, net of taxes) for the three and six months ended June 30, 2014, respectively. As of June 30, 2014, there was $0.6 million of total unrecognized compensation cost related to non-vested GP membership interests, which is expected to be recognized over a weighted-average period of 2.9 years.
10. Earnings Per Share
Basic and diluted earnings per share are computed by dividing net income by the weighted average common shares outstanding. The common shares used to compute Delek’s basic and diluted earnings per share are as follows:
 
 
Three Months Ended
 
Six Months Ended
 
 
June 30,
 
June 30,
 
 
2014

2013
 
2014
 
2013
Weighted average common shares outstanding
 
59,283,465

 
58,925,800

 
59,266,256

 
59,246,988

Dilutive effect of equity instruments
 
591,796

 
905,085

 
603,723

 
1,008,538

Weighted average common shares outstanding, assuming dilution
 
59,875,261

 
59,830,885

 
59,869,979

 
60,255,526

Outstanding common share equivalents totaling 1,944,161 were excluded from the diluted earnings per share calculation for both the three and six months ended June 30, 2014, compared to 1,040,025 excluded for both the three and six months ended June 30, 2013, as these common share equivalents did not have a dilutive effect under the treasury stock method.

15


11. Segment Data
We report our operating results in three reportable segments: refining, logistics and retail. Decisions concerning the allocation of resources and assessment of operating performance are made based on this segmentation. Management measures the operating performance of each reportable segment based on the segment contribution margin.
In conjunction with the Tyler Acquisition and the El Dorado Acquisition, we reclassified certain operating segments. The results of the operation of the assets associated with these acquisitions were previously reported as part of our refining segment and are now reported in our logistics segment. The historical results of the operation of these assets have been reclassified to conform to the current presentation.
Effective April 1, 2014, we revised the structure of the internal financial information reviewed by management and began allocating the results of hedging activity previously reported in corporate, other and eliminations to our refining segment. The historical results of this hedging activity have been reclassified to conform to the current presentation. The assets and/or liabilities associated with this hedging activity have not been allocated to the refining segment.
Segment contribution margin is defined as net sales less cost of sales and operating expenses, excluding depreciation and amortization. Operations which are not specifically included in the reportable segments are included in the corporate and other category, which primarily consists of operating expenses associated with ancillary company operations and intercompany eliminations.
The refining segment processes crude oil and other purchased feedstocks for the manufacture of transportation motor fuels, including various grades of gasoline, diesel fuel, aviation fuel, asphalt and other petroleum-based products that are distributed through both our own and third-party product terminals and pipelines. The refining segment has a combined nameplate capacity of 140,000 bpd, comprised of 60,000 bpd at the Tyler refinery and 80,000 bpd at the El Dorado refinery.
Our logistics segment owns and operates crude oil and refined products logistics and marketing assets. The logistics segment generates revenue and subsequently contribution margin, which we define as net sales less cost of goods sold and operating expenses, by charging fees for gathering, transporting and storing crude oil and for marketing, distributing, transporting and storing refined products.
Our retail segment markets gasoline, diesel, other refined petroleum products and convenience merchandise through a network of company-operated retail fuel and convenience stores throughout the southeastern United States. As of June 30, 2014, we had 362 stores in total, consisting of 196 located in Tennessee, 90 in Alabama, 48 in Georgia, 12 in Arkansas, 8 in Virginia, 5 in Kentucky and 3 in Mississippi. The retail fuel and convenience stores operate under our MAPCO Express®, MAPCO Mart®, East Coast®, Fast Food and FuelTM, Favorite Markets®, Delta Express® and Discount Food MartTM brands. The retail segment also supplied fuel to approximately 48 dealer locations as of June 30, 2014. In the retail segment, management reviews operating results on a divisional basis, where a division represents a specific geographic market. These divisional operating segments exhibit similar economic characteristics, provide the same products and services, and operate in a manner such that aggregation of these operations is appropriate for segment presentation.
Our refining segment has a services agreement with our logistics segment, which, among other things, requires the refining segment to pay service fees based on the number of gallons sold at the Tyler refinery and a sharing of a portion of the margin achieved in return for providing marketing, sales and customer services. This intercompany transaction fee was $3.6 million and $7.1 million during the three and six months ended June 30, 2014, respectively, and $3.7 million and $6.7 million during the three and six months ended June 30, 2013, respectively. Additionally, the refining segment pays transportation and storage fees to the logistics segment for the utilization of certain crude and finished product pipeline and tank assets. These fees were $24.1 million and $45.1 million during the three and six months ended June 30, 2014, respectively, and $11.8 million and $23.7 million during the three and six months ended June 30, 2013, respectively. The refining segment sold finished product and services to the retail and logistics segments in the amount of $187.4 million and $294.6 million during the three and six months ended June 30, 2014, respectively, and $128.1 million and $182.6 million during the three and six months ended June 30, 2013, respectively. All inter-segment transactions have been eliminated in consolidation.

16


The following is a summary of business segment operating performance as measured by contribution margin for the period indicated (in millions):
 
 
Three Months Ended June 30, 2014
 
 
Refining
 
Retail
 
Logistics
 
Corporate,
Other and Eliminations
 
Consolidated
Net sales (excluding intercompany fees and sales)
 
$
1,659.2

 
$
508.6

 
$
207.4

 
$
(0.5
)
 
$
2,374.7

Intercompany fees and sales
 
187.4

 

 
29.0

 
(216.4
)
 

Operating costs and expenses:
 
 
 
 
 
 
 
 
 
 
Cost of goods sold
 
1,662.2

 
457.1

 
196.6

 
(210.6
)
 
2,105.3

Operating expenses
 
58.7

 
34.8

 
9.6

 
(0.8
)
 
102.3

Segment contribution margin
 
$
125.7

 
$
16.7

 
$
30.2

 
$
(5.5
)
 
167.1

General and administrative expenses
 
 
 
 
 
 
 
 
 
32.9

Depreciation and amortization
 
 
 
 
 
 
 
 
 
28.2

Operating income
 
 
 
 
 
 
 
 
 
$
106.0

Total assets
 
$
2,104.5

 
$
466.3

 
$
314.4

 
$
274.4

 
$
3,159.6

Capital spending (excluding business combinations)
 
$
24.1

 
$
6.5

 
$
1.0

 
$
7.5

 
$
39.1


 
 
Three Months Ended June 30, 2013
 
 
Refining(1)
 
Retail
 
Logistics
 
Corporate,
Other and Eliminations
(1)
 
Consolidated
Net sales (excluding intercompany fees and sales)
 
$
1,480.3

 
$
493.9

 
$
212.9

 
$
0.3

 
$
2,187.4

Intercompany fees and sales
 
128.1

 

 
17.2

 
(145.3
)
 

Operating costs and expenses:
 
 
 
 
 
 
 
 
 
 
Cost of goods sold
 
1,454.4

 
443.8

 
207.9

 
(140.0
)
 
1,966.1

Operating expenses
 
51.6

 
34.1

 
9.9

 
(0.3
)
 
95.3

Segment contribution margin
 
$
102.4

 
$
16.0

 
$
12.3

 
$
(4.7
)
 
126.0

General and administrative expenses
 
 
 
 
 
 
 
 
 
28.1

Depreciation and amortization
 
 
 
 
 
 
 
 
 
21.6

Other operating income
 
 
 
 
 
 
 
 
 
$
(1.5
)
Operating income
 
 
 
 
 
 
 
 
 
$
77.8

Total assets
 
$
1,889.9

 
$
438.8

 
$
323.6

 
$
30.1

 
$
2,682.4

Capital spending (excluding business combinations)
 
$
18.2

 
$
6.7

 
$
3.4

 
$
8.2

 
$
36.5




17


 
 
Six Months Ended June 30, 2014
(In millions)
 
Refining
 
Retail
 
Logistics
 
Corporate,
Other and Eliminations
 
Consolidated
Net sales (excluding intercompany fees and sales)
 
$
2,914.8

 
$
940.2

 
$
385.7

 
$
(0.3
)
 
$
4,240.4

Intercompany fees and sales
 
294.6

 

 
54.2

 
(348.8
)
 

Operating costs and expenses:
 
 
 
 
 
 
 
 
 
 
Cost of goods sold
 
2,863.8

 
850.6

 
368.8

 
(337.5
)
 
3,745.7

Operating expenses
 
116.7

 
67.0

 
18.9

 
(1.8
)
 
200.8

Segment contribution margin
 
$
228.9

 
$
22.6

 
$
52.2

 
$
(9.8
)
 
293.9

General and administrative expenses
 
 
 
 
 
 
 
 
 
67.4

Depreciation and amortization
 
 
 
 
 
 
 
 
 
52.8

Operating income
 
 
 
 
 
 
 
 
 
$
173.7

Capital spending (excluding business combinations)
 
$
127.3

 
$
13.1

 
$
2.0

 
$
11.0

 
$
153.4


 
 
Six Months Ended June 30, 2013
(In millions)
 
Refining(1)
 
Retail
 
Logistics
 
Corporate,
Other and Eliminations
(1)
 
Consolidated
Net sales (excluding intercompany fees and sales)
 
$
3,095.3

 
$
942.7

 
$
408.9

 
$
0.4

 
$
4,447.3

Intercompany fees and sales
 
182.6

 

 
32.1

 
(214.7
)
 

Operating costs and expenses:
 
 
 
 
 
 
 
 
 
 
Cost of goods sold
 
2,894.5

 
853.1

 
395.8

 
(205.1
)
 
3,938.3

Operating expenses
 
110.1

 
65.7

 
19.0

 
(0.8
)
 
194.0

Segment contribution margin
 
$
273.3

 
$
23.9

 
$
26.2

 
$
(8.4
)
 
315.0

General and administrative expenses
 
 
 
 
 
 
 
 
 
60.7

Depreciation and amortization
 
 
 
 
 
 
 
 
 
43.6

Other operating income
 
 
 
 
 
 
 
 
 
(1.5
)
Operating income
 
 
 
 
 
 
 
 
 
$
212.2

Capital spending (excluding business combinations)
 
$
31.1

 
$
12.1

 
$
7.1

 
$
14.2

 
$
64.5


            
(1) 
Hedging activity previously reported in corporate, other and eliminations has been allocated to the refining segment.


18


Property, plant and equipment, accumulated depreciation and depreciation expense by reporting segment as of and for the three and six months ended June 30, 2014 are as follows (in millions):
 
 
Refining
 
Logistics
 
Retail
 
Corporate,
Other and Eliminations
 
Consolidated
Property, plant and equipment
 
$
1,027.6

 
$
266.5

 
$
497.2

 
$
50.5

 
$
1,841.8

Less: Accumulated depreciation
 
(218.6
)
 
(45.8
)
 
(181.3
)
 
(6.9
)
 
(452.6
)
Property, plant and equipment, net
 
$
809.0

 
$
220.7

 
$
315.9

 
$
43.6

 
$
1,389.2

Depreciation expense for the three months ended June 30, 2014
 
$
16.3

 
$
3.3

 
$
7.1

 
$
1.2

 
$
27.9

Depreciation expense for the six months ended June 30, 2014
 
$
29.2

 
$
6.5

 
$
14.2

 
$
2.3

 
$
52.2

In accordance with ASC 360, Property, Plant & Equipment, Delek evaluates the realizability of property, plant and equipment as events occur that might indicate potential impairment.

19


12. Fair Value Measurements
The fair values of financial instruments are estimated based upon current market conditions and quoted market prices for the same or similar instruments. Management estimates that the carrying value approximates fair value for all of Delek’s assets and liabilities that fall under the scope of ASC 825, Financial Instruments.
Delek applies the provisions of ASC 820, Fair Value Measurements ("ASC 820"), which defines fair value, establishes a framework for its measurement and expands disclosures about fair value measurements. ASC 820 applies to our interest rate and commodity derivatives that are measured at fair value on a recurring basis. The standard also requires that we assess the impact of nonperformance risk on our derivatives. Nonperformance risk is not considered material at this time.
ASC 820 requires disclosures that categorize assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting our assumptions about pricing by market participants.
Over the counter ("OTC") commodity swaps, physical commodity purchase and sale contracts and interest rate swaps and caps are generally valued using industry-standard models that consider various assumptions, including quoted forward prices for interest rates, time value, volatility factors and contractual prices for the underlying instruments, as well as other relevant economic measures. The degree to which these inputs are observable in the forward markets determines the classification as Level 2 or 3. Our contracts are valued using quotations provided by brokers based on exchange pricing and/or price index developers such as Platts or Argus and are, therefore, classified as Level 2.
The fair value hierarchy for our financial assets and liabilities accounted for at fair value on a recurring basis at June 30, 2014 and December 31, 2013, was as follows (in millions):
 
 
As of June 30, 2014
 
 
Level 1
 
Level 2
 
Level 3
 
Total
Assets
 
 
 
 
 
 
 
 
Commodity derivatives
 
$

 
$
116.2

 
$

 
$
116.2

Liabilities
 
 
 
 
 
 
 
 
Commodity derivatives
 

 
(63.0
)
 

 
(63.0
)
Interest rate derivatives
 

 
(2.0
)
 

 
(2.0
)
Total liabilities
 

 
(65.0
)
 

 
(65.0
)
Net assets
 
$

 
$
51.2

 
$

 
$
51.2


 
 
As of December 31, 2013
 
 
Level 1
 
Level 2
 
Level 3
 
Total
Assets
 
 
 
 
 
 
 
 
Commodity derivatives
 
$

 
$
23.9

 
$

 
$
23.9

Interest rate derivatives
 

 
0.1

 

 
0.1

Total assets
 

 
24.0

 

 
24.0

Liabilities
 
 
 
 
 
 
 
 
Commodity derivatives



(24.9
)



(24.9
)
Interest rate derivatives
 

 
(2.8
)
 

 
(2.8
)
Total liabilities
 

 
(27.7
)
 

 
(27.7
)
Net liabilities
 
$

 
$
(3.7
)
 
$

 
$
(3.7
)
The derivative values above are based on analysis of each contract as the fundamental unit of account as required by ASC 820. Derivative assets and liabilities with the same counterparty are not netted where the legal right of offset exists. This differs from the presentation in the financial statements which reflects our policy under the guidance of ASC 815-10-45, wherein we have elected to offset the fair value amounts recognized for multiple derivative instruments executed with the same counterparty, and

20


where the legal right of offset exists. As of June 30, 2014 and December 31, 2013, $2.0 million and $2.6 million, respectively, of cash collateral was held by counterparty brokerage firms and has been netted with the derivative positions with each counterparty.

13. Derivative Instruments

We use derivatives to reduce normal operating and market risks with the primary objective of reducing the impact of market price volatility on our results of operations. As such, our use of derivatives is aimed at:

limiting the exposure to price fluctuations of commodity inventory above or below target levels at each of our segments;
managing our exposure to commodity price risk associated with the purchase or sale of crude oil, feedstocks and finished grade fuel products at each of our segments; and
limiting the exposure to floating-interest rate fluctuations on our borrowings.
We primarily utilize OTC commodity swaps, generally with maturity dates of two years or less, and interest rate swap and cap agreements to achieve these objectives. OTC commodity swap contracts require cash settlement for the commodity based on the difference between a fixed or floating price and the market price on the settlement date. Interest rate swap and cap agreements economically hedge floating rate debt by exchanging interest rate cash flows, based on a notional amount from a floating rate to a fixed rate. We do not believe there is any material credit risk with respect to the counterparties to these contracts.
In accordance with ASC 815, certain of our OTC commodity swap contracts have been designated as cash flow hedges and the change in fair value between the execution date and the end of period has been recorded in other comprehensive income. The fair value of these contracts is recognized in income at the time the positions are closed and the hedged transactions are recognized in income.
From time to time, we also enter into futures contracts with supply vendors that secure supply of product to be purchased for use in the normal course of business at our refining and retail segments. These contracts are priced based on an index that is clearly and closely related to the product being purchased, contain no net settlement provisions and typically qualify under the normal purchase exemption from derivative accounting treatment under ASC 815.
The following table presents the fair value of our derivative instruments, as of June 30, 2014 and December 31, 2013. The fair value amounts below are presented on a gross basis and do not reflect the netting of asset and liability positions permitted under our master netting arrangements, including cash collateral on deposit with our counterparties. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements. As a result, the asset and liability amounts below will differ from the amounts presented in our condensed consolidated balance sheets (in millions):
 
 
 
June 30, 2014
 
December 31, 2013
Derivative Type
Balance Sheet Location
 
Assets
 
Liabilities
 
Assets
 
Liabilities
Derivatives not designated as hedging instruments:
 
 
 
 
 
 
 
 
OTC commodity swaps(1)
Other current assets
 
$
59.1

 
$
(35.9
)
 
$
18.0

 
$
(8.2
)
OTC commodity swaps(1)
Other current liabilities
 

 

 
0.9

 
(3.8
)
Interest rate derivatives
Other long term assets
 

 

 
0.1

 

Interest rate derivatives
Other long term liabilities
 

 
(2.0
)
 

 
(2.8
)
 
 
 
 
 
 
 
 
 
 
Derivatives designated as hedging instruments:
 
 
 
 
 
 
 
 
OTC commodity swaps(1)
Other current assets
 
57.1

 
(27.1
)
 
3.4

 
(10.2
)
OTC commodity swaps(1)
Other current liabilities
 

 

 
1.5

 
(2.7
)
Total gross fair value of derivatives
 
$
116.2

 
$
(65.0
)
 
$
23.9

 
$
(27.7
)
Less: Counterparty netting and cash collateral(2)
 
63.0

 
(65.0
)
 
20.1

 
(22.8
)
Total net fair value of derivatives
 
$
53.2

 
$

 
$
3.8

 
$
(4.9
)

(1) 
As of June 30, 2014 and December 31, 2013, we had open derivative contracts representing 43,115,500 barrels and 19,927,000 barrels, respectively, of crude oil and refined petroleum products. Of these open contracts, contracts

21


representing 14,886,000 and 9,292,000 barrels were designated as hedging instruments as of June 30, 2014 and December 31, 2013, respectively.
(2) 
As of June 30, 2014 and December 31, 2013, $2.0 million and $2.6 million, respectively, of cash collateral has been netted with the derivative positions with each counterparty. Included in these amounts is $2.0 million of cash collateral associated with our interest rate derivatives as of both June 30, 2014 and December 31, 2013.
Recognized gains (losses) associated with derivatives not designated as hedging instruments for the three and six months ended June 30, 2014 and 2013 are as follows (in millions):
 
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
Derivative Type
Income Statement Location
 
2014
 
2013
 
2014
 
2013
OTC commodity swaps
Cost of goods sold
 
$
1.1

 
$
3.6

 
$
28.9

 
$
(0.6
)
Interest rate derivatives
Interest expense
 
0.4

 
0.8

 
0.7

 
1.2

 
 Total
 
$
1.5

 
$
4.4

 
$
29.6

 
$
0.6

Gains on our derivatives designated as cash flow hedging instruments for the three and six months ended June 30, 2014 and 2013 are as follows (in millions):
 
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2014
 
2013
 
2014
 
2013
OTC commodity swaps:
 
 
 
 
 
 
 
 
Gain recognized in OCI (effective portion)
 
$
10.5

 
$

 
$
40.0

 
$

(Loss) gain reclassified from accumulated OCI into cost of goods sold on closed positions (effective portion)
 
$
(3.8
)
 
$

 
$
(2.1
)
 
$
0.6

Gain recognized in cost of goods sold related to ineffectiveness
 
$
11.1

 
$

 
$
14.2

 
$

For cash flow hedges, no component of the derivative instruments’ gains or losses was excluded from the assessment of hedge effectiveness for the three and six months ended June 30, 2014 and 2013. As of June 30, 2014 and December 31, 2013, gains (losses) of $12.8 million and $(4.0) million, respectively, on cash flow hedges, net of tax, primarily related to future purchases of crude oil and the associated sale of finished grade fuel, remained in accumulated other comprehensive income. Losses of $2.5 million and $1.3 million, net of tax, on settled contracts were reclassified into cost of sales during the three and six months ended June 30, 2014. Gains of $0.4 million, net of tax, on settled contracts were reclassified into cost of sales during the six months ended June 30, 2013. We estimate that $19.7 million of these deferred gains will be reclassified into cost of sales over the next 12 months as a result of hedged transactions that are forecasted to occur. For the both three and six months ended June 30, 2014, there were gains of $1.5 million reclassified from accumulated other comprehensive income into income as a result of the discontinuation of cash flow hedge accounting. There were no amounts reclassified from accumulated other comprehensive income into income as a result of the discontinuation of cash flow hedge accounting for the three or six months ended June 30, 2013.
14. Commitments and Contingencies
Litigation
In the ordinary conduct of our business, we are from time to time subject to lawsuits, investigations and claims, including environmental claims and employee-related matters.
Although we cannot predict with certainty the ultimate resolution of lawsuits, investigations and claims asserted against us, including civil penalties or other enforcement actions, we do not believe that any currently pending legal proceeding or proceedings to which we are a party will have a material adverse effect on our business, financial condition or results of operations.
Self-insurance
Delek is self-insured for workers’ compensation claims up to $1.0 million on a per accident basis. We self-insure for general liability claims, inclusive of sudden and accidental pollution claims, up to $4.0 million on a per occurrence basis. We self-insure for auto liability up to $4.0 million on a per accident basis.
We have umbrella liability insurance available to each of our segments in an amount determined reasonable by management.

22


Rate Regulation of Petroleum Pipelines
The rates and terms and conditions of service on certain of our pipelines may be subject to regulation by the Federal Energy Regulatory Commission ("FERC") under the Interstate Commerce Act ("ICA") or by the state regulatory commissions in the states in which we transport crude oil and refined products, including the Railroad Commission of Texas, the Louisiana Public Service Commission, and the Arkansas Public Service Commission. Certain of our pipeline systems are subject to such regulation and have filed tariffs with the appropriate entities. We also comply with the reporting requirements for these pipelines. Other of our pipelines have received a waiver from FERC's tariff requirements but will comply with other applicable regulatory requirements.
FERC regulates interstate transportation under the ICA, the Energy Policy Act of 1992 and the rules and regulations promulgated under those laws. The ICA and its implementing regulations require that tariff rates for interstate service on oil pipelines, including pipelines that transport crude oil and refined products in interstate commerce (collectively referred to as "petroleum pipelines"), be just and reasonable and non-discriminatory and that such rates and terms and conditions of service be filed with FERC. Under the ICA, shippers may challenge new or existing rates or services. FERC is authorized to suspend the effectiveness of a challenged rate for up to seven months.
While FERC regulates rates for shipments of crude oil or refined products in interstate commerce, state agencies may regulate rates and service for shipments in intrastate commerce. We own pipeline assets in Texas, Arkansas and Louisiana.
Environmental, Health and Safety
We are subject to various federal, state and local environmental and safety laws enforced by agencies including the U.S. Environmental Protection Agency (the "EPA"), the United States Department of Transportation/Pipeline and Hazardous Materials Safety Administration, the Occupational Safety and Health Administration, the Texas Commission on Environmental Quality, the Railroad Commission of Texas, the Arkansas Department of Environmental Quality and the Tennessee Department of Environment and Conservation as well as other state and federal agencies. Numerous permits or other authorizations are required under these laws for the operation of our refineries, terminals, pipelines, underground storage tanks ("USTs") and related operations, and may be subject to revocation, modification and renewal.
These laws and permits raise potential exposure to future claims and lawsuits involving environmental and safety matters which could include soil and water contamination, air pollution, personal injury and property damage allegedly caused by substances which we manufactured, handled, used, released or disposed, or that relate to pre-existing conditions for which we have assumed responsibility. We believe that our current operations are in substantial compliance with existing environmental and safety requirements. However, there have been and will continue to be ongoing discussions about environmental and safety matters between us and federal and state authorities, including notices of violations, citations and other enforcement actions, some of which have resulted or may result in changes to operating procedures and in capital expenditures. While it is often difficult to quantify future environmental or safety related expenditures, we anticipate that continuing capital investments and changes in operating procedures will be required for the foreseeable future to comply with existing and new requirements as well as evolving interpretations and more strict enforcement of existing laws and regulations.
The Comprehensive Environmental Response, Compensation and Liability Act, also known as Superfund, imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. Analogous state laws impose similar responsibilities and liabilities on responsible parties. In the course of our ordinary operations, our various businesses generate waste, some of which falls within the statutory definition of a hazardous substance and some of which may have been disposed of at sites that may require future cleanup under Superfund. At this time, our El Dorado refinery has been named as a minor potentially responsible party at one site for which we believe future costs will not be material.
As of June 30, 2014, we have recorded an environmental liability of approximately $9.7 million, primarily related to the probable estimated costs of remediating or otherwise addressing certain environmental issues of a non-capital nature at the Tyler and El Dorado refineries. This liability includes estimated costs for ongoing investigation and remediation efforts, which were already being performed by the former operators of the Tyler and El Dorado refineries prior to our acquisition of those facilities, for known contamination of soil and groundwater, as well as estimated costs for additional issues which have been identified subsequent to the acquisition. We expect approximately $0.6 million of this amount to be reimbursable by a prior owner of the El Dorado refinery and have recorded $0.1 million in other current assets and $0.5 million in other non-current assets in our condensed consolidated balance sheet as of June 30, 2014. Approximately $0.9 million of the total liability is expected to be expended over the next 12 months with most of the balance expended by 2022. In the future we could be required to undertake additional investigations of our refineries, pipelines and terminal facilities or convenience stores, which could result in additional remediation liabilities.

23


Most of the cost of remediating releases from USTs in our retail segment is reimbursed by state reimbursement funds which are funded by a tax on petroleum products and subject to certain deductible amounts. As of June 30, 2014, the amount accrued for such UST-related remediation was less than $0.1 million.
The EPA issued final rules for gasoline formulation that required the reduction of average benzene content by January 1, 2011 and the reduction of maximum annual average benzene content by July 1, 2012. We completed a project at the Tyler refinery in the fourth quarter of 2010 to partially reduce gasoline benzene levels. However, it is necessary for us to purchase credits to fully comply with these content requirements for the Tyler refinery. Although credits have been acquired that we believe will be sufficient to cover our obligations through at least 2015, there can be no assurance that such credits will be available in the future or that we will be able to purchase available credits at reasonable prices. Additional benzene reduction projects may be implemented to reduce or eliminate our need to purchase benzene credits depending on the availability and cost of such credits. For example, a project to reduce gasoline benzene levels was completed at the El Dorado refinery in June 2011.
Various legislative and regulatory measures to address climate change and greenhouse gas ("GHG") emissions (including carbon dioxide, methane and nitrous oxides) are in various phases of discussion or implementation. They include proposed and enacted federal regulation and state actions to develop statewide, regional or nationwide programs designed to control and reduce GHG emissions from fixed sources, such as our refineries, as well as mobile transportation sources. We are not aware of any state or regional initiatives for controlling existing GHG emissions that would affect our refineries. Although it is not possible to predict the requirements of any GHG legislation that ultimately may be enacted, any laws or regulations that have been or may be adopted to restrict or reduce GHG emissions will likely require us to incur increased operating and capital costs. The EPA also has indicated that it intends to regulate refinery GHG emissions from new and existing sources through a New Source Performance Standard ("NSPS"), although there is no firm proposal or date for such regulation.
Since the 2010 calendar year, EPA rules require us to report GHG emissions from our refinery operations and consumer use of fuel products produced at our refineries on an annual basis. While the cost of compliance with the reporting rule is not material, data gathered under the rule may be used in the future to support additional regulation of GHG. Effective January 2011, the EPA began regulating GHG emissions from refineries and other major sources through the Prevention of Significant Deterioration ("PSD") and Federal Operating Permit ("Title V") programs. While these rules do not impose any limits or controls on GHG emissions from current operations, emission increases from future projects or operational changes, such as capacity increases, may be impacted and required to meet emission limits or technological requirements such as Best Available Control Technologies ("BACT"). In June 2014, The United States Supreme Court ruled that the EPA may not require PSD and Title V permits solely because of GHG emissions, but may require BACT for GHG emissions if emissions of other pollutants would otherwise require PSD permitting. We believe this decision will not materially affect permitting issues for our operations.
In mid-2012, the EPA announced an industry-wide enforcement initiative directed at flaring operations and performance at refineries and petrochemical plants. In September 2012, the EPA finalized revisions to the NSPS for Petroleum Refineries ("NSPS Subpart Ja") that primarily affects flares and process heaters. We believe our existing process heaters meet the applicable requirements and our refineries have not received any associated inquiries or requests for information and are not a party to any associated enforcement action at this time. Affected flares have three years to comply with the new standard, and it is likely the standard will impact the way some flares at our Tyler and El Dorado refineries are designed and/or operated. We are planning capital projects at our refineries related to flare compliance with NSPS Subpart Ja that will be implemented in 2014-2016.
In June 2014, the EPA proposed rules to further regulate refinery air emissions through additional NSPS and Maximum Achievable Control Technology ("MACT") requirements. The proposed rules would require capital expenditures for additional controls on the Tyler refinery’s coker and for the relief systems, flares, tanks and other sources at both refineries, as well as requiring changes to the way we operate or start up some process units. The proposed rule would also require that we monitor property line benzene concentrations and provide the results to the EPA who will make the results available to the public. The EPA anticipates finalizing the proposed rules in April 2015 with approximately three years to comply with most of the requirements. If the proposed rules are finalized, we do not anticipate that any required capital and operating costs will be material and do not believe compliance will affect our production capacities or have a material adverse effect upon our business, financial condition of results of operations.
The Energy Independence and Security Act of 2007 ("EISA") increased the amounts of renewable fuel required to be blended into domestic transportation fuel supplies by the Energy Policy Act of 2005 to 32 billion gallons by 2022. The Renewable Fuel Standard - 2 (RFS-2) rule finalized by the EPA in 2010 to implement EISA, requires that most refiners blend increasing amounts of biofuels with refined products, equal to approximately 9.2% of combined gasoline and diesel volume in 2012, increasing to 9.6% in 2013 and escalating annually to approximately 18% by 2022. Because the mandate requires specified volumes of biofuels, if the demand for motor fuels decreases in future years even higher percentages of biofuels may be required. Alternatively, credits called Renewable Identification Numbers ("RINs") can be used instead of physically blending biofuels. The Tyler refinery began

24


supplying a 10% ethanol gasoline blend (E-10) in January 2008 and 5% biodiesel blends in June 2011. The El Dorado refinery completed projects at its truck loading rack in June 2011 to make E-10 available and in July 2012 to make biodiesel blends available. In 2013, we internally generated, through our logistics, retail and refining segments, most of the RINs required to meet the obligations of our refineries, including a carryover of 2012 RINs, with a net surplus of biodiesel RINs that were available to be sold to purchase RINs in other categories.
The EPA has proposed slightly lower overall renewable fuel obligations for 2014 in recognition of blending issues associated with exceeding the 10% "blendwall" in gasoline; however, the EPA is not expected to finalize the required volumes until sometime in the third quarter of 2014. The EPA could require increased volumes compared with the proposed volumes. If the proposed rule is finalized, it is likely we will obtain most of the RINs required for 2014 compliance through internal operations of our refineries and other business units. If the proposed volumes are not finalized, resulting in higher volumes than in 2013, it will likely be necessary for our refineries to purchase RINs in the market, but it is not possible at this time to predict what those volumes may be.
In March 2013, the EPA proposed Tier 3 gasoline rules, which were finalized in March 2014. As proposed, the final Tier 3 rule requires a reduction in annual average gasoline sulfur content from 30 ppm to 10 ppm and retains the current maximum per-gallon sulfur content of 80 ppm. Larger refineries must comply with the 10 ppm sulfur standard by January 1, 2017 but the final rule provides a three-year waiver period, to January 1, 2020, for small volume refineries that processed less than 75,000 bpd in 2011 or 2012. Both our Tyler and Lion Oil refineries meet this waiver provision and will have an additional three years to comply. We anticipate that the Tyler refinery will meet these new limits when they become effective with only minor operational changes and that a minor capital project may be required for additional sulfur removal capacity at the El Dorado refinery.
Following the November 2008 explosion and fire at the Tyler refinery, the EPA conducted an investigation under Section 114 of the Clean Air Act pertaining to our compliance with the chemical accident prevention standards. In late 2011, the EPA referred an enforcement action to the DOJ and we are in discussions with the EPA and the DOJ regarding resolution to the alleged compliance issues. Any penalties and injunctive relief required to settle the matter are not expected to be material.
We have detected several crude oil releases, including a release at Magnolia Station in March 2013, a release near Macedonia, Arkansas in October 2013 and a release in Haynesville, Louisiana in April 2014. Based on current information available to us, we do not believe the total costs associated with these events, whether alone or in the aggregate, including any fines or penalties and net of partial insurance reimbursement, will have a material adverse effect upon our business, financial condition or results of operations.
Vendor Commitments
We maintain an agreement with a significant vendor that requires our retail segment to purchase certain general merchandise exclusively from this vendor over a specified period of time. Additionally, we maintain agreements with certain fuel suppliers that contain terms which generally require our retail segment to purchase predetermined quantities of third-party branded fuel for a specified period of time. In certain fuel vendor contracts, penalty provisions exist if our retail segment does not purchase certain minimum quantities of fuel.
Letters of Credit
As of June 30, 2014, Delek had in place letters of credit totaling approximately $141.9 million with various financial institutions securing obligations primarily with respect to its workers’ compensation and general liability self-insurance programs, crude oil purchases for the refining segment and gasoline and diesel purchases for the logistics segment. No amounts were drawn by beneficiaries of these letters of credit at June 30, 2014.
15. Subsequent Events
Dividend Declaration
On August 5, 2014, our Board of Directors voted to declare a quarterly cash dividend of $0.15 per share, payable on September 16, 2014 to shareholders of record on August 26, 2014.

Stock Repurchase Program
On August 5, 2014, our Board of Directors increased the authorization under our stock repurchase program by $50.0 million to $100.0 million. Through August 6, 2014, approximately $12.7 million of the stock repurchase authorization has been utilized.

25


ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Management’s Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") is management’s analysis of our financial performance and of significant trends that may affect our future performance. The MD&A should be read in conjunction with our condensed consolidated financial statements and related notes included elsewhere in this Quarterly Report on Form 10-Q and in the Annual Report on Form 10-K filed with the Securities and Exchange Commission ("SEC") on March 3, 2014, as amended by Amendment No. 1 on Form 10-K/A that was filed with the SEC on June 26, 2014 (collectively, the "Annual Report on Form 10-K"). Those statements in the MD&A that are not historical in nature should be deemed forward-looking statements that are inherently uncertain. Unless the context otherwise requires, references to "Delek," "the Company," and "we," "our," or "us," and like terms refer to Delek US Holdings, Inc. and its consolidated subsidiaries.
Forward-Looking Statements
This Quarterly Report on Form 10-Q contains "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. These forward-looking statements reflect our current estimates, expectations and projections about our future results, performance, prospects and opportunities. Forward-looking statements include, among other things, the information concerning our possible future results of operations, business and growth strategies, financing plans, expectations that regulatory developments or other matters will not have a material adverse effect on our business or financial condition, our competitive position and the effects of competition, the projected growth of the industry in which we operate, the benefits and synergies to be obtained from our completed and any future acquisitions, and statements of management’s goals and objectives, and other similar expressions concerning matters that are not historical facts. Words such as "may," "will," "should," "could," "would," "predicts," "potential," "continue," "expects," "anticipates," "future," "intends," "plans," "believes," "estimates," "appears," "projects" and similar expressions, as well as statements in future tense, identify forward-looking statements.
Forward-looking statements should not be read as a guarantee of future performance or results, and will not necessarily be accurate indications of the times at or by which such performance or results will be achieved. Forward-looking information is based on information available at the time and/or management’s good faith belief with respect to future events, and is subject to risks and uncertainties that could cause actual performance or results to differ materially from those expressed in the statements. Important factors that, individually or in the aggregate, could cause such differences include, but are not limited to:
volatility in our refining margins or fuel gross profit as a result of changes in the prices of crude oil, other feedstocks and refined petroleum products;
reliability of our operating assets;
unanticipated increases in the cost or scope of, or significant delays in the completion of, our capital improvement and turnaround projects;
risks and uncertainties with respect to the quantities and costs of refined petroleum products supplied to our pipelines and/or held in our terminals;
operating hazards including, without limitation, refinery accidents, pipeline spills, tank failures, trucking accidents and train derailments, that are inherent in transporting, storing and processing crude oil and intermediate and finished petroleum products;
competition;
changes in, or the failure to comply with, the extensive government regulations applicable to our operating segments or industry, generally;
our ability to execute our strategy of growth through acquisitions and to avoid or mitigate transactional risks in acquisitions;
diminishment of value in long-lived assets may result in an impairment in the carrying value of the asset on our balance sheet and a resultant loss recognized in the statement of operations;
general economic and business conditions, particularly those conditions affecting levels of spending relating to travel and tourism or affecting the southeastern United States;
deterioration of creditworthiness or overall financial condition of a material counterparty (or counterparties);

26


natural disasters, casualty losses and other matters beyond our control;
increases in our debt levels;
compliance, or failure to comply, with restrictive and financial covenants in our various debt agreements;
the inability of our subsidiaries to freely make dividends, loans or other cash distributions to us;
seasonality;
acts of terrorism aimed at either our facilities or other facilities that could impair our ability to produce or transport refined products or receive feedstocks;
changes in the cost or availability of transportation for feedstocks and refined products;
volatility of derivative instruments; and
other factors discussed under the headings "Management’s Discussion and Analysis of Financial Condition and Results of Operations" and "Risk Factors" and in our other filings with the SEC.
In light of these risks, uncertainties and assumptions, our actual results of operations and execution of our business strategy could differ materially from those expressed in, or implied by, the forward-looking statements, and you should not place undue reliance upon them. In addition, past financial and/or operating performance is not necessarily a reliable indicator of future performance and you should not use our historical performance to anticipate results or future period trends. There can be no assurances that any of the events anticipated by the forward-looking statements will occur or, if any such events do occur, what impact they will have on our results of operations and financial condition.
Forward-looking statements speak only as of the date the statements are made. We assume no obligation to update forward-looking statements to reflect actual results, changes in assumptions or changes in other factors affecting forward-looking information except to the extent required by applicable securities laws. If we do update one or more forward-looking statements, no inference should be drawn that we will make additional updates with respect thereto or with respect to other forward-looking statements.
Overview
We are an integrated downstream energy business focused on petroleum refining, the wholesale distribution of refined products and convenience store retailing. Our business consists of three operating segments: (1) refining, (2) logistics, and (3) retail. Our refining segment operates independent refineries in Tyler, Texas (the "Tyler refinery") and El Dorado, Arkansas (the "El Dorado refinery") with a combined design crude distillation capacity of 140,000 barrels per day ("bpd"). Our logistics segment gathers, transports and stores crude oil and markets, distributes, transports and stores refined products in select regions of the southeastern United States and west Texas for both our refining segment and third parties. Our retail segment markets gasoline, diesel, other refined petroleum products and convenience merchandise through a network of 362 company-operated retail fuel and convenience stores located in Tennessee, Alabama, Georgia, Arkansas, Virginia, Kentucky and Mississippi.
We currently own a 60.0% limited partner interest in Delek Logistics Partners, LP ("Delek Logistics") and a 96.1% interest in the entity that owns the entire 2.0% general partner interest in Delek Logistics and all of the income distribution rights. Delek Logistics was formed by Delek in 2012 to own, operate, acquire and construct crude oil and refined products logistics and marketing assets. Delek Logistics' initial assets were contributed by us and included certain assets formerly owned or used by certain of our subsidiaries. In July 2013, Delek Logistics completed the acquisition of a terminal, storage tanks and related assets adjacent to the Tyler refinery from one of our other subsidiaries (the "Tyler Acquisition"); and, in February 2014, a subsidiary of Delek Logistics completed the acquisition from Lion Oil Company of certain storage tanks and the products terminal located at the El Dorado refinery (the "El Dorado Acquisition"). A substantial majority of Delek Logistics' assets are currently integral to our refining and marketing operations.
In conjunction with the Tyler Acquisition and the El Dorado Acquisition, we reclassified certain operating segments. The results of the operation of the assets associated with these acquisitions were previously reported as part of our refining segment and are now reported in our logistics segment. The historical results of the operation of these assets have been reclassified to conform to the current presentation.
Our profitability in the refining segment is substantially determined by the spread between the prices of refined products we sell from our refineries and the prices of crude oil we acquire to produce them, referred to as the "refining margin." The cost to acquire crude oil and the prices of refined petroleum products we ultimately sell depend on numerous factors beyond our control,

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including the supply of, and demand for, crude oil, gasoline, asphalt and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions (such as hurricanes or tornadoes), local, domestic and foreign political affairs, global conflict, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Other significant factors that influence our results in the refining segment include the cost of crude, our primary feedstock, operating costs, particularly the cost of natural gas used for fuel and the cost of electricity, seasonal factors, utilization rates and planned or unplanned maintenance activities or turnarounds. Moreover, while increases in the cost of crude oil are often reflected in the prices of light refined products, the value of heavier products, such as asphalt, coke, carbon black oil, and liquefied petroleum gas ("LPG"), are typically less likely to move in parallel with crude cost. This may cause additional pressure on our realized margin.
For our Tyler refinery, we compare our per barrel refining margin to a well established industry metric: the U.S. Gulf Coast 5-3-2 crack spread ("Gulf Coast crack spread"). The Gulf Coast crack spread is used as a benchmark against which to measure a refining margin and represents the approximate gross margin resulting from processing one barrel of crude oil into three-fifths of a barrel of gasoline and two-fifths of a barrel of high sulfur diesel. We calculate the Gulf Coast crack spread using the market value of U.S. Gulf Coast Pipeline 87 Octane Conventional Gasoline and U.S. Gulf Coast Pipeline No. 2 Heating Oil (high sulfur diesel) and the first month futures price of light sweet crude oil on the New York Mercantile Exchange ("NYMEX"). U.S. Gulf Coast Pipeline 87 Octane Conventional Gasoline is a grade of gasoline commonly marketed as Regular Unleaded at retail locations. U.S. Gulf Coast Pipeline No. 2 Heating Oil is a petroleum distillate that can be used as either a diesel fuel or a fuel oil. This is the standard by which other distillate products (such as ultra low sulfur diesel) are priced. The NYMEX is the commodities trading exchange where contracts for the future delivery of petroleum products are bought and sold.
As of the date of this Quarterly Report on Form 10-Q, we do not believe a reliable benchmark exists for the El Dorado refinery due to fluctuations in the quantities and varieties of crude oil processed and products manufactured at the El Dorado refinery and because asphalt products do not typically trade in line with other refined products. As a result, past results may not be reflective of future performance.
The cost to acquire the refined fuel products we sell to our wholesale customers in our logistics segment and to retail customers at our convenience stores in our retail segment depends on numerous factors beyond our control, including the supply of, and demand for, crude oil, gasoline and other refined petroleum products which, in turn, depend on, among other factors, changes in domestic and foreign economies, weather conditions, domestic and foreign political affairs, production levels, the availability of imports, the marketing of competitive fuels and government regulation. Our retail merchandise sales are driven by convenience, customer service, competitive pricing and branding. Motor fuel margin is sales less the delivered cost of fuel and motor fuel taxes, measured on a cents per gallon basis. Our motor fuel margins are impacted by local supply, demand, weather, competitor pricing and product brand.
As part of our overall business strategy, we regularly evaluate opportunities to expand and complement our business and may at any time be discussing or negotiating a transaction that, if consummated, could have a material effect on our business, financial condition, liquidity or results of operations.
Recent Developments
Tyler Expansion Project/Turnaround
During the first quarter of 2015, the Tyler refinery will conduct a maintenance turnaround, as well as replace the fluid catalytic cracking reactor. In addition, during the turnaround, we expect to complete a project to expand the crude nameplate capacity at the Tyler refinery by 15,000 barrels per day to 75,000 barrels per day. This expansion project is expected to cost approximately $69.8 million, of which an estimated $53.8 million is anticipated to be spent during 2014. This expansion project will be primarily financed with a $70.0 million delayed draw term loan under our Wells ABL credit facility.
Return to Shareholders
Dividends
On June 11, 2014, our Board of Directors authorized a special dividend of $0.10 per share, which was paid on July 17, 2014 to shareholders of record on June 26, 2014. This special dividend was in addition to the regular dividend of $0.15 per share, declared on May 6, 2014 and paid on June 17, 2014 to shareholders of record on May 27, 2014. On August 5, 2014, our Board of Directors voted to declare a quarterly cash dividend of $0.15 per share, payable on September 16, 2014 to shareholders of record on August 26, 2014.

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Stock Repurchase Program

On March 13, 2014, we announced that our Board of Directors had authorized a $50.0 million common stock repurchase program. The repurchases are intended to be implemented through open market transactions or in privately negotiated transactions, in accordance with applicable securities laws. The timing, price, and size of repurchases will be made at the discretion of management and will depend upon prevailing market prices, general economic and market conditions and other considerations. The stock repurchase program does not obligate us to acquire any particular amount of stock, and the authorization under the stock repurchase program will expire on December 31, 2014. During the second quarter of 2014, we purchased 260,244 shares of common stock, for $7.9 million, under the stock repurchase program for an average of $30.39 per share. On August 5, 2014, our Board of Directors increased the authorization under our stock repurchase program by $50.0 million to $100.0 million.
Economic Overview
Consolidated net income for the second quarter of 2014 was $54.9 million, or $0.92 per diluted share, compared to net income of $46.6 million, or $0.78 per diluted share, in the same period last year. Results for the second quarter of 2014 were positively impacted by improved refining margins which benefited from a wider discount between West Texas Intermediate ("WTI") Midland crude oil and WTI Cushing crude oil, as well as increased throughput at the El Dorado refinery and improved margins in the logistics segment. These were partially offset by a decline in the benchmark Gulf Coast crack spread to $17.10 per barrel in the second quarter of 2014 compared to $19.83 per barrel during the second quarter of 2013, resulting from a 9.49% increase in WTI crude oil, only partially offset by 5.88% and 2.10% increases in the U.S. Gulf Coast price of gasoline and Ultra-Low Sulfur Diesel ("ULSD"), respectively.
Refining Segment
Refining segment contribution margin increased to $125.7 million in the second quarter of 2014, versus $102.4 million in the second quarter of 2013. In the second quarter of 2014 and 2013, respectively, the refining segment operated at a combined average utilization rate of 97.9% and 94.5% and produced a combined 93.3% and 91.8% light products. The refining segment contribution margin was positively impacted by a wider discount between WTI Midland crude oil and WTI Cushing crude oil, to an average of $8.37 per barrel in the second quarter of 2014, versus $0.14 in the second quarter of 2013. This was partially offset by a one time, $22.6 million non-cash before tax expense related to the financial settlement under the the Master Supply and Offtake Agreement, as amended and restated, with J. Aron & Company (the "Supply and Offtake Agreement"). Also, market conditions resulted in a decline in the benchmark Gulf Coast crack spread, which averaged $17.10 per barrel in the second quarter of 2014, compared to $19.83 per barrel during the second quarter of 2013.
The Tyler refinery's refining margin was $18.90 per barrel sold in the second quarter of 2014, compared to $14.47 per barrel sold in the second quarter of 2013. The increase in refining margin per barrel was primarily attributable to the increase in the Midland WTI crude oil discount relative to WTI Cushing crude oil. The increased margins at the Tyler refinery were partially offset by a decrease in sales volumes, from 70,033 bpd in the second quarter of 2013 to 65,969 bpd in the second quarter of 2014. The decline in sales volumes is primarily attributable to a mechanical issue with the fluid catalytic cracking reactor, which reduced run rates for several days in late June 2014. The fluid catalytic cracking reactor was repaired early in July 2014 and is expected to be replaced as part of the first quarter 2015 turnaround of the Tyler refinery.
In the second quarter of 2014 and 2013, the El Dorado refinery operated at an average utilization rate of 98.8% and 84.8%, respectively. El Dorado's higher utilization rate in the second quarter of 2014 was attributable to the completion of the turnaround at the El Dorado refinery in the first quarter 2014, which improved light crude capability. The El Dorado refining margin was $8.59 per barrel sold during the second quarter of 2014, compared to $8.82 per barrel sold during the second quarter of 2013. The $22.6 million expense related to the Supply and Offtake Agreement reduced the El Dorado refining margin by $2.89 per barrel sold. This was partially offset by the wider discount between WTI Midland crude and WTI Cushing crude oil. Sales volumes at the El Dorado refinery increased 21.6% in the second quarter of 2014 as compared to the same period in 2013, due to increased production as a result of the ability to process additional barrels of light crude following work that was completed during the turnaround during the first quarter 2014.
Logistics Segment
Logistics segment contribution margin increased to $30.2 million in the second quarter of 2014, versus $12.3 million in the second quarter of 2013, primarily due to increased pipeline and transportation revenues associated with the Tyler Acquisition and El Dorado Acquisition, as well as improved margins in the west Texas operations, which benefited from a favorable supply/demand balance in the area due to downtime at refineries in the region. These increased revenues were partially offset by a 8.6% decline in west Texas sales volumes, to 17,450 bpd in the second quarter of 2014, versus 19,082 bpd in the prior-year period.

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Retail Segment
Retail segment contribution margin increased to $16.7 million in the second quarter of 2014, versus $16.0 million in the second quarter of 2013. The increase in retail segment contribution margin was attributable to an increase in both fuel and merchandise volumes in the second quarter of 2014, as compared to the second quarter of 2013.
At the conclusion of the second quarter of 2014, the retail segment operated 362 locations, versus 370 locations in the prior-year period, as we continued our divestiture of under-performing properties in favor of newer, large-format locations. In the second quarter of 2014, we completed the construction of three new large-format retail stores. We expect to open an additional four to six large-format stores in the remainder of 2014.
Market Trends
Our results of operations are significantly affected by the cost of the commodities that we purchase, process, produce and sell. Sudden change in petroleum-based commodity prices is our primary source of market risk. Historically, our profitability has been affected by the volatility of commodity prices, including crude oil and refined products.
We continue to experience volatility in the energy markets. The price of WTI crude oil ranged from a high of $107.26 per barrel to a low of $91.66 per barrel during the first six months of 2014 and averaged $100.85 and $94.28 per barrel in the first six months of 2014 and 2013, respectively. The Gulf Coast crack spread ranged from a high of $21.36 per barrel to a low of $10.21 per barrel during the first six months of 2014 and averaged $16.06 per barrel during the first six months of 2014, compared to an average of $23.24 in the same period of 2013.
Our Tyler and El Dorado refineries both continued to have access to discounted WTI and WTI-linked crude feedstocks during the second quarter of 2014, compared to certain of our competitors.  However, as new pipelines and rail capabilities have increased others' access to price-advantaged crude oil supplies in the mid-continent region, we have experienced a decline in certain crude oil price differentials. The price of WTI crude oil held an average discount of $6.74 per barrel when compared to Brent crude oil during the second quarter of 2014, compared to a discount of $9.12 per barrel in the comparable period of 2013. However, the WTI Midland crude oil discount to WTI Cushing crude oil averaged $8.37 per barrel in the second quarter of 2014, compared to an average of $0.14 in the second quarter of 2013. As these price differentials decrease, so does our competitive advantage inherent in our access to WTI-linked crude oils.
Environmental regulations continue to affect our margins in the form of the increasing cost of Renewable Identification Numbers ("RINs"). On a consolidated basis, we work to balance our RIN obligations in order to minimize the effect of RINs on our results. While we generate RINs in all three operating segments through our ethanol blending and biodiesel production, our refining segment needs to purchase additional RINs to satisfy its obligations. As a result, increases in the price of RINs can adversely affect our results of operations. The cost of ethanol RINs has fluctuated from an average of $0.82 in the second quarter of 2013 to an average of $0.46 in the second quarter of 2014. The cost of biodiesel RINs fluctuated from an average of $1.44 in the second quarter of 2013 to an average of $0.85 in the second quarter of 2014.
As part of our overall business strategy, management determines the cost to store crude oil, the pricing of products and whether we should maintain, increase or decrease inventory levels of crude oil or other intermediate feedstocks based on various factors, including the crude pricing market in the U.S. Gulf Coast region, the refined products market in the same region, the relationship between these two markets, our ability to obtain credit with crude oil vendors, and any other factors which may impact the costs of crude oil. During the first six months of 2014, refined product inventories decreased as compared to the end of 2013, due to a build-up of refined product inventory in the fourth quarter of 2013 in anticipation of the El Dorado refinery shutdown for the turnaround completed in the first quarter of 2014. This product inventory on hand, in addition to products transferred from the Tyler refinery, was used to meet customer demand during the shutdown for the turnaround.
Seasonality
Demand for gasoline, convenience merchandise and asphalt products is generally lower during the winter months due to seasonal decreases in motor vehicle traffic and road and home construction. Additionally, varying vapor pressure requirements between the summer and winter months tighten summer gasoline supply. As a result, our operating results are generally lower during the first and fourth quarters of the year.
Contractual Obligations
There have been no material changes to our contractual obligations and commercial commitments during the six months ended June 30, 2014, from those disclosed in our Annual Report on Form 10-K.

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Critical Accounting Policies
The preparation of our consolidated financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses and related disclosure of contingent assets and liabilities. The SEC has defined critical accounting policies as those that are both most important to the portrayal of our financial condition and results of operations and require our most difficult, complex or subjective judgments or estimates. Based on this definition and as further described in our Annual Report on Form 10-K for the year ended December 31, 2013, we believe our critical accounting policies include the following: (i) determining our inventory using the last-in, first out valuation method, (ii) evaluating impairment for property, plant and equipment and definite life intangibles, (iii) valuing goodwill and potential impairment, and (iv) estimating environmental expenditures. For all financial statement periods presented, there have been no material modifications to the application of these critical accounting policies or estimates since our most recently filed Annual Report on Form 10-K.

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Summary Financial and Other Information
The following table provides summary financial data for Delek:
 
 
Three Months Ended
 
Six Months Ended
Statement of Operations Data
 
June 30,
 
June 30,
 
 
2014
 
2013
 
2014
 
2013
 
 
(In millions, except share and per share data)
Net sales:
 
 
 
 
 
 
 
 
Refining
 
$
1,846.6

 
$
1,608.4

 
$
3,209.4

 
$
3,277.9

Logistics
 
236.4

 
230.1

 
439.9

 
441.0

Retail
 
508.6

 
493.9

 
940.2

 
942.7

Other
 
(216.9
)
 
(145.0
)
 
(349.1
)
 
(214.3
)
Total
 
2,374.7

 
2,187.4

 
4,240.4

 
4,447.3

Operating costs and expenses:
 
 
 
 
 
 
 
 
Cost of goods sold
 
2,105.3

 
1,966.1

 
3,745.7

 
3,938.3

Operating expenses
 
102.3

 
95.3

 
200.8

 
194.0

General and administrative expenses
 
32.9

 
28.1

 
67.4

 
60.7

Depreciation and amortization
 
28.2

 
21.6

 
52.8

 
43.6

Other operating income
 

 
(1.5
)
 

 
(1.5
)
Total operating costs and expenses
 
2,268.7

 
2,109.6

 
4,066.7

 
4,235.1

Operating income
 
106.0

 
77.8

 
173.7

 
212.2

Interest expense
 
10.1

 
9.2

 
19.7

 
18.4

Interest income
 

 
(0.1
)
 
(0.4
)
 
(0.2
)
Other income, net
 
0.1

 
(6.7
)
 

 
(6.7
)
Total non-operating expenses
 
10.2

 
2.4

 
19.3

 
11.5