R | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from _______________ to _______________ |
Delaware | 74-1828067 | |
(State or other jurisdiction of | (I.R.S. Employer | |
incorporation or organization) | Identification No.) |
Large accelerated filer R | Accelerated filer o | Non-accelerated filer o | Smaller reporting company o |
Page | |
September 30, 2011 | December 31, 2010 | ||||||
(Unaudited) | |||||||
ASSETS | |||||||
Current assets: | |||||||
Cash and temporary cash investments | $ | 2,829 | $ | 3,334 | |||
Receivables, net | 7,509 | 4,583 | |||||
Inventories | 5,164 | 4,947 | |||||
Income taxes receivable | 5 | 343 | |||||
Deferred income taxes | 254 | 190 | |||||
Prepaid expenses and other | 109 | 121 | |||||
Total current assets | 15,870 | 13,518 | |||||
Property, plant and equipment, at cost | 31,066 | 28,921 | |||||
Accumulated depreciation | (6,847 | ) | (6,252 | ) | |||
Property, plant and equipment, net | 24,219 | 22,669 | |||||
Intangible assets, net | 251 | 224 | |||||
Deferred charges and other assets, net | 1,343 | 1,210 | |||||
Total assets | $ | 41,683 | $ | 37,621 | |||
LIABILITIES AND EQUITY | |||||||
Current liabilities: | |||||||
Current portion of debt and capital lease obligations | $ | 867 | $ | 822 | |||
Accounts payable | 8,520 | 6,441 | |||||
Accrued expenses | 785 | 590 | |||||
Taxes other than income taxes | 1,053 | 671 | |||||
Income taxes payable | 136 | 3 | |||||
Deferred income taxes | 322 | 257 | |||||
Total current liabilities | 11,683 | 8,784 | |||||
Debt and capital lease obligations, less current portion | 6,781 | 7,515 | |||||
Deferred income taxes | 4,942 | 4,530 | |||||
Other long-term liabilities | 1,607 | 1,767 | |||||
Commitments and contingencies | |||||||
Equity: | |||||||
Valero Energy Corporation stockholders’ equity: | |||||||
Common stock, $0.01 par value; 1,200,000,000 shares authorized; 673,501,593 and 673,501,593 shares issued | 7 | 7 | |||||
Additional paid-in capital | 7,559 | 7,704 | |||||
Treasury stock, at cost; 114,855,199 and 105,113,545 common shares | (6,491 | ) | (6,462 | ) | |||
Retained earnings | 15,347 | 13,388 | |||||
Accumulated other comprehensive income | 232 | 388 | |||||
Total Valero Energy Corporation stockholders’ equity | 16,654 | 15,025 | |||||
Noncontrolling interests | 16 | — | |||||
Total equity | 16,670 | 15,025 | |||||
Total liabilities and equity | $ | 41,683 | $ | 37,621 |
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||
2011 | 2010 | 2011 | 2010 | ||||||||||||
Operating revenues (a) | $ | 33,713 | $ | 21,015 | $ | 91,314 | $ | 60,069 | |||||||
Costs and expenses: | |||||||||||||||
Cost of sales | 30,033 | 18,915 | 82,981 | 54,198 | |||||||||||
Operating expenses: | |||||||||||||||
Refining | 870 | 753 | 2,427 | 2,210 | |||||||||||
Retail | 177 | 169 | 508 | 484 | |||||||||||
Ethanol | 103 | 96 | 302 | 267 | |||||||||||
General and administrative expenses | 161 | 139 | 442 | 367 | |||||||||||
Depreciation and amortization expense | 390 | 353 | 1,141 | 1,043 | |||||||||||
Asset impairment loss | — | — | — | 2 | |||||||||||
Total costs and expenses | 31,734 | 20,425 | 87,801 | 58,571 | |||||||||||
Operating income | 1,979 | 590 | 3,513 | 1,498 | |||||||||||
Other income, net | 1 | 17 | 28 | 29 | |||||||||||
Interest and debt expense, net of capitalized interest | (88 | ) | (119 | ) | (312 | ) | (363 | ) | |||||||
Income from continuing operations before income tax expense | 1,892 | 488 | 3,229 | 1,164 | |||||||||||
Income tax expense | 689 | 185 | 1,178 | 421 | |||||||||||
Income from continuing operations | 1,203 | 303 | 2,051 | 743 | |||||||||||
Income (loss) from discontinued operations, net of income taxes | — | (11 | ) | (7 | ) | 19 | |||||||||
Net income | 1,203 | 292 | 2,044 | 762 | |||||||||||
Less: Net loss attributable to noncontrolling interests | — | — | (1 | ) | — | ||||||||||
Net income attributable to Valero Energy Corporation stockholders | $ | 1,203 | $ | 292 | $ | 2,045 | $ | 762 | |||||||
Net income attributable to Valero Energy Corporation stockholders: | |||||||||||||||
Continuing operations | $ | 1,203 | $ | 303 | $ | 2,052 | $ | 743 | |||||||
Discontinued operations | — | (11 | ) | (7 | ) | 19 | |||||||||
Total | $ | 1,203 | $ | 292 | $ | 2,045 | $ | 762 | |||||||
Earnings per common share: | |||||||||||||||
Continuing operations | $ | 2.12 | $ | 0.54 | $ | 3.61 | $ | 1.31 | |||||||
Discontinued operations | — | (0.02 | ) | (0.01 | ) | 0.03 | |||||||||
Total | $ | 2.12 | $ | 0.52 | $ | 3.60 | $ | 1.34 | |||||||
Weighted-average common shares outstanding (in millions) | 564 | 564 | 566 | 563 | |||||||||||
Earnings per common share – assuming dilution: | |||||||||||||||
Continuing operations | $ | 2.11 | $ | 0.53 | $ | 3.59 | $ | 1.31 | |||||||
Discontinued operations | — | (0.02 | ) | (0.01 | ) | 0.03 | |||||||||
Total | $ | 2.11 | $ | 0.51 | $ | 3.58 | $ | 1.34 | |||||||
Weighted-average common shares outstanding – assuming dilution (in millions) | 569 | 568 | 572 | 567 | |||||||||||
Dividends per common share | $ | 0.05 | $ | 0.05 | $ | 0.15 | $ | 0.15 |
Supplemental information: | |||||||||||||||
(a) Includes excise taxes on sales by our U.S. retail system | $ | 229 | $ | 234 | $ | 670 | $ | 667 |
Nine Months Ended September 30, | |||||||
2011 | 2010 | ||||||
Cash flows from operating activities: | |||||||
Net income | $ | 2,044 | $ | 762 | |||
Adjustments to reconcile net income to net cash provided by operating activities: | |||||||
Depreciation and amortization expense | 1,141 | 1,096 | |||||
Noncash interest expense and other income, net | 20 | 8 | |||||
Asset impairment loss | — | 2 | |||||
Gain on sale of Delaware City Refinery assets | — | (92 | ) | ||||
Stock-based compensation expense | 34 | 32 | |||||
Deferred income tax expense | 393 | 285 | |||||
Changes in current assets and current liabilities | 840 | 592 | |||||
Changes in deferred charges and credits and other operating activities, net | (144 | ) | (63 | ) | |||
Net cash provided by operating activities | 4,328 | 2,622 | |||||
Cash flows from investing activities: | |||||||
Capital expenditures | (1,584 | ) | (1,226 | ) | |||
Deferred turnaround and catalyst costs | (501 | ) | (410 | ) | |||
Acquisition of Pembroke Refinery, net of cash acquired | (1,675 | ) | — | ||||
Acquisition of pipeline and terminal facilities | (37 | ) | — | ||||
Acquisitions of ethanol plants | — | (260 | ) | ||||
Proceeds from sale of the Delaware City Refinery assets and associated terminal and pipeline assets | — | 220 | |||||
Other investing activities, net | (24 | ) | 15 | ||||
Net cash used in investing activities | (3,821 | ) | (1,661 | ) | |||
Cash flows from financing activities: | |||||||
Non-bank debt: | |||||||
Borrowings | — | 1,244 | |||||
Repayments | (718 | ) | (517 | ) | |||
Accounts receivable sales program: | |||||||
Proceeds from the sale of receivables | — | 1,225 | |||||
Repayments | — | (1,325 | ) | ||||
Purchase of common stock for treasury | (270 | ) | (2 | ) | |||
Issuance of common stock in connection with stock-based compensation plans | 42 | 12 | |||||
Common stock dividends | (85 | ) | (85 | ) | |||
Debt issuance costs | — | (10 | ) | ||||
Contributions from noncontrolling interests | 12 | — | |||||
Other financing activities, net | 17 | 5 | |||||
Net cash provided by (used in) financing activities | (1,002 | ) | 547 | ||||
Effect of foreign exchange rate changes on cash | (10 | ) | 19 | ||||
Net increase (decrease) in cash and temporary cash investments | (505 | ) | 1,527 | ||||
Cash and temporary cash investments at beginning of period | 3,334 | 825 | |||||
Cash and temporary cash investments at end of period | $ | 2,829 | $ | 2,352 |
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||
2011 | 2010 | 2011 | 2010 | ||||||||||||
Net income | $ | 1,203 | $ | 292 | $ | 2,044 | $ | 762 | |||||||
Other comprehensive income (loss): | |||||||||||||||
Foreign currency translation adjustment | (278 | ) | 100 | (166 | ) | 63 | |||||||||
Pension and other postretirement benefits: | |||||||||||||||
Net loss arising during the period, net of income tax benefit of $-, $-, $-, and $- | — | — | — | (21 | ) | ||||||||||
Net gain reclassified into income, net of income tax expense of $1, $2, $2, and $2 | (1 | ) | (2 | ) | (3 | ) | (4 | ) | |||||||
Net loss on pension and other postretirement benefits | (1 | ) | (2 | ) | (3 | ) | (25 | ) | |||||||
Derivative instruments designated and qualifying as cash flow hedges: | |||||||||||||||
Net gain (loss) arising during the period, net of income tax (expense) benefit of $(7), $-, $(7), and $1 | 13 | — | 13 | (1 | ) | ||||||||||
Net gain reclassified into income, net of income tax expense of $-, $13, $-, and $47 | — | (24 | ) | — | (88 | ) | |||||||||
Net gain (loss) on cash flow hedges | 13 | (24 | ) | 13 | (89 | ) | |||||||||
Other comprehensive income (loss) | (266 | ) | 74 | (156 | ) | (51 | ) | ||||||||
Comprehensive income | 937 | 366 | 1,888 | 711 | |||||||||||
Less: Comprehensive loss attributable to noncontrolling interests | — | — | (1 | ) | — | ||||||||||
Comprehensive income attributable to Valero Energy Corporation stockholders | $ | 937 | $ | 366 | $ | 1,889 | $ | 711 |
1. | BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES |
2. | ACQUISITIONS AND DISPOSITIONS |
Current assets, net of cash acquired | $ | 2,217 | |
Property, plant and equipment | 777 | ||
Deferred charges and other assets | 17 | ||
Intangible assets | 50 | ||
Current liabilities, less current portion of debt and capital lease obligations | (1,294 | ) | |
Debt and capital leases assumed, including current portion | (12 | ) | |
Other long-term liabilities | (77 | ) | |
Noncontrolling interest | (3 | ) | |
Purchase price, net of cash acquired | $ | 1,675 |
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||
2011 | 2010 | 2011 | 2010 | ||||||||
Operating revenues | $ | 3,028 | N/A | $ | 3,028 | N/A | |||||
Income from continuing operations | 19 | N/A | 19 | N/A |
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||
2011 | 2010 | 2011 | 2010 | ||||||||||||
Operating revenues | $ | 35,491 | $ | 24,594 | $ | 103,030 | $ | 70,638 | |||||||
Income from continuing operations attributable to Valero stockholders | 1,196 | 306 | 1,941 | 767 | |||||||||||
Earnings per common share from continuing operations – basic | 2.11 | 0.54 | 3.41 | 1.36 | |||||||||||
Earnings per common share from continuing operations – assuming dilution | 2.10 | 0.54 | 3.39 | 1.35 |
Three Months Ended September 30, 2010 | Nine Months Ended September 30, 2010 | |||||||
Operating revenues | $ | 1,195 | $ | 3,559 | ||||
Loss before income taxes | (18 | ) | (36 | ) |
Three Months Ended September 30, 2010 | Nine Months Ended September 30, 2010 | ||||||
Operating revenues | $ | — | $ | — | |||
Loss before income taxes | — | (33 | ) |
3. | IMPAIRMENT ANALYSIS |
4. | INVENTORIES |
September 30, 2011 | December 31, 2010 | ||||||
Refinery feedstocks | $ | 2,502 | $ | 2,225 | |||
Refined products and blendstocks | 2,217 | 2,233 | |||||
Ethanol feedstocks and products | 130 | 201 | |||||
Convenience store merchandise | 102 | 101 | |||||
Materials and supplies | 213 | 187 | |||||
Inventories | $ | 5,164 | $ | 4,947 |
5. | DEBT |
• | in May 2011, we made a scheduled debt repayment of $200 million related to our 6.125% senior notes; |
• | in April 2011, we made scheduled debt repayments of $8 million related to our Series A 5.45%, Series B 5.40%, and Series C 5.40% industrial revenue bonds; |
• | in February 2011, we made a scheduled debt repayment of $210 million related to our 6.75% senior notes; and |
• | in February 2011, we paid $300 million to acquire the Gulf Opportunity Zone Revenue Bonds Series 2010 (GO Zone Bonds), which were subject to mandatory tender. We expect to hold the GO Zone Bonds for our own account until conditions permit the remarketing of these bonds at an interest rate acceptable to us. |
• | in June 2010, we made a scheduled debt repayment of $25 million related to our 7.25% debentures; |
• | in May 2010, we redeemed our 6.75% senior notes with a maturity date of May 1, 2014 for $190 million, or 102.25% of stated value; |
• | in April 2010, we made scheduled debt repayments of $8 million related to our Series A 5.45%, Series B 5.40%, and Series C 5.40% industrial revenue bonds; |
• | in March 2010, we redeemed our 7.50% senior notes with a maturity date of June 15, 2015 for $294 million, or 102.5% of stated value; and |
• | in February 2010, we issued $400 million of 4.50% notes due in February 2015 and $850 million of 6.125% notes due in February 2020 for total net proceeds of $1.2 billion. |
Amounts Outstanding | ||||||||
Borrowing Capacity | Expiration | September 30, 2011 | December 31, 2010 | |||||
Letter of credit facility | $200 | June 2012 | $— | $— | ||||
Letter of credit facility | $300 | June 2012 | $300 | $100 | ||||
Revolver | $2,400 | November 2012 | $74 | $399 | ||||
Canadian revolving credit facility | C$115 | December 2012 | C$20 | C$20 |
6. | COMMITMENTS AND CONTINGENCIES |
7. | EQUITY |
2011 | 2010 | |||||||||||||||||||||||
Valero Stockholders’ Equity | Non- controlling Interests | Total Equity | Valero Stockholders’ Equity | Non- controlling Interests | Total Equity | |||||||||||||||||||
Balance at beginning of period | $ | 15,025 | $ | — | $ | 15,025 | $ | 14,725 | $ | — | $ | 14,725 | ||||||||||||
Net income (loss) | 2,045 | (1 | ) | 2,044 | 762 | — | 762 | |||||||||||||||||
Dividends | (85 | ) | — | (85 | ) | (85 | ) | — | (85 | ) | ||||||||||||||
Stock-based compensation expense | 34 | — | 34 | 32 | — | 32 | ||||||||||||||||||
Tax deduction in excess of stock-based compensation expense | 19 | — | 19 | 7 | — | 7 | ||||||||||||||||||
Transactions in connection with stock-based compensation plans: | ||||||||||||||||||||||||
Stock issuances | 42 | — | 42 | 12 | — | 12 | ||||||||||||||||||
Stock repurchases | (270 | ) | — | (270 | ) | (2 | ) | — | (2 | ) | ||||||||||||||
Contributions from noncontrolling interest | — | 14 | 14 | — | — | — | ||||||||||||||||||
Recognition of noncontrolling interest in connection with Pembroke Acquisition | — | 3 | 3 | — | — | — | ||||||||||||||||||
Other comprehensive income (loss) | (156 | ) | — | (156 | ) | (51 | ) | — | (51 | ) | ||||||||||||||
Balance at end of period | $ | 16,654 | $ | 16 | $ | 16,670 | $ | 15,400 | $ | — | $ | 15,400 |
8. | EMPLOYEE BENEFIT PLANS |
Pension Plans | Other Postretirement Benefit Plans | ||||||||||||||
2011 | 2010 | 2011 | 2010 | ||||||||||||
Three months ended September 30: | |||||||||||||||
Service cost | $ | 28 | $ | 22 | $ | 4 | $ | 3 | |||||||
Interest cost | 21 | 21 | 5 | 6 | |||||||||||
Expected return on plan assets | (28 | ) | (28 | ) | — | — | |||||||||
Amortization of: | |||||||||||||||
Prior service cost (credit) | 1 | 1 | (6 | ) | (5 | ) | |||||||||
Net loss | 3 | — | — | 1 | |||||||||||
Net periodic benefit cost | $ | 25 | $ | 16 | $ | 3 | $ | 5 | |||||||
Nine months ended September 30: | |||||||||||||||
Service cost | $ | 73 | $ | 65 | $ | 9 | $ | 8 | |||||||
Interest cost | 64 | 62 | 16 | 19 | |||||||||||
Expected return on plan assets | (84 | ) | (84 | ) | — | — | |||||||||
Amortization of: | |||||||||||||||
Prior service cost (credit) | 2 | 2 | (17 | ) | (15 | ) | |||||||||
Net loss | 9 | 1 | 1 | 3 | |||||||||||
Net periodic benefit cost | $ | 64 | $ | 46 | $ | 9 | $ | 15 |
9. | EARNINGS PER COMMON SHARE |
Three Months Ended September 30, | |||||||||||||||
2011 | 2010 | ||||||||||||||
Restricted Stock | Common Stock | Restricted Stock | Common Stock | ||||||||||||
Earnings per common share from continuing operations: | |||||||||||||||
Net income attributable to Valero stockholders from continuing operations | $ | 1,203 | $ | 303 | |||||||||||
Less dividends paid: | |||||||||||||||
Common stock | 28 | 28 | |||||||||||||
Nonvested restricted stock | — | — | |||||||||||||
Undistributed earnings | $ | 1,175 | $ | 275 | |||||||||||
Weighted-average common shares outstanding | 3 | 564 | 3 | 564 | |||||||||||
Earnings per common share from continuing operations: | |||||||||||||||
Distributed earnings | $ | 0.05 | $ | 0.05 | $ | 0.05 | $ | 0.05 | |||||||
Undistributed earnings | 2.07 | 2.07 | 0.49 | 0.49 | |||||||||||
Total earnings per common share from continuing operations | $ | 2.12 | $ | 2.12 | $ | 0.54 | $ | 0.54 | |||||||
Earnings per common share from continuing operations – assuming dilution: | |||||||||||||||
Net income attributable to Valero stockholders from continuing operations | $ | 1,203 | $ | 303 | |||||||||||
Weighted-average common shares outstanding | 564 | 564 | |||||||||||||
Common equivalent shares: | |||||||||||||||
Stock options | 3 | 3 | |||||||||||||
Performance awards and unvested restricted stock | 2 | 1 | |||||||||||||
Weighted-average common shares outstanding – assuming dilution | 569 | 568 | |||||||||||||
Earnings per common share from continuing operations – assuming dilution | $ | 2.11 | $ | 0.53 |
Nine Months Ended September 30, | |||||||||||||||
2011 | 2010 | ||||||||||||||
Restricted Stock | Common Stock | Restricted Stock | Common Stock | ||||||||||||
Earnings per common share from continuing operations: | |||||||||||||||
Net income attributable to Valero stockholders from continuing operations | $ | 2,052 | $ | 743 | |||||||||||
Less dividends paid: | |||||||||||||||
Common stock | 85 | 85 | |||||||||||||
Nonvested restricted stock | — | — | |||||||||||||
Undistributed earnings | $ | 1,967 | $ | 658 | |||||||||||
Weighted-average common shares outstanding | 3 | 566 | 3 | 563 | |||||||||||
Earnings per common share from continuing operations: | |||||||||||||||
Distributed earnings | $ | 0.15 | $ | 0.15 | $ | 0.15 | $ | 0.15 | |||||||
Undistributed earnings | 3.46 | 3.46 | 1.16 | 1.16 | |||||||||||
Total earnings per common share from continuing operations | $ | 3.61 | $ | 3.61 | $ | 1.31 | $ | 1.31 | |||||||
Earnings per common share from continuing operations – assuming dilution: | |||||||||||||||
Net income attributable to Valero stockholders from continuing operations | $ | 2,052 | $ | 743 | |||||||||||
Weighted-average common shares outstanding | 566 | 563 | |||||||||||||
Common equivalent shares: | |||||||||||||||
Stock options | 4 | 3 | |||||||||||||
Performance awards and unvested restricted stock | 2 | 1 | |||||||||||||
Weighted-average common shares outstanding – assuming dilution | 572 | 567 | |||||||||||||
Earnings per common share from continuing operations – assuming dilution | $ | 3.59 | $ | 1.31 |
Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||
2011 | 2010 | 2011 | 2010 | ||||||||
Stock options | 6 | 17 | 6 | 14 |
10. | SEGMENT INFORMATION |
Refining | Retail | Ethanol | Corporate | Total | ||||||||||||||||
Three months ended September 30, 2011: | ||||||||||||||||||||
Operating revenues from external customers | $ | 29,177 | $ | 3,053 | $ | 1,483 | $ | — | $ | 33,713 | ||||||||||
Intersegment revenues | 2,258 | — | 25 | — | 2,283 | |||||||||||||||
Operating income (loss) | 1,947 | 97 | 107 | (172 | ) | 1,979 | ||||||||||||||
Three months ended September 30, 2010: | ||||||||||||||||||||
Operating revenues from external customers | 17,811 | 2,360 | 844 | — | 21,015 | |||||||||||||||
Intersegment revenues | 1,576 | — | 73 | — | 1,649 | |||||||||||||||
Operating income (loss) | 590 | 105 | 47 | (152 | ) | 590 | ||||||||||||||
Nine months ended September 30, 2011: | ||||||||||||||||||||
Operating revenues from external customers | 78,660 | 8,865 | 3,789 | — | 91,314 | |||||||||||||||
Intersegment revenues | 6,566 | — | 125 | — | 6,691 | |||||||||||||||
Operating income (loss) | 3,476 | 298 | 215 | (476 | ) | 3,513 | ||||||||||||||
Nine months ended September 30, 2010: | ||||||||||||||||||||
Operating revenues from external customers | 51,104 | 6,893 | 2,072 | — | 60,069 | |||||||||||||||
Intersegment revenues | 4,675 | — | 184 | — | 4,859 | |||||||||||||||
Operating income (loss) | 1,479 | 285 | 139 | (405 | ) | 1,498 |
September 30, 2011 | December 31, 2010 | ||||||
Refining | $ | 35,541 | $ | 30,363 | |||
Retail | 1,933 | 1,925 | |||||
Ethanol | 879 | 953 | |||||
Corporate | 3,330 | 4,380 | |||||
Total consolidated assets | $ | 41,683 | $ | 37,621 |
11. | SUPPLEMENTAL CASH FLOW INFORMATION |
Nine Months Ended September 30, | |||||||
2011 | 2010 | ||||||
Decrease (increase) in current assets: | |||||||
Receivables, net | $ | (1,963 | ) | $ | (516 | ) | |
Inventories | 891 | 79 | |||||
Income taxes receivable | 333 | 787 | |||||
Prepaid expenses and other | 12 | 111 | |||||
Increase (decrease) in current liabilities: | |||||||
Accounts payable | 1,191 | 358 | |||||
Accrued expenses | 137 | (51 | ) | ||||
Taxes other than income taxes | 99 | (168 | ) | ||||
Income taxes payable | 140 | (8 | ) | ||||
Changes in current assets and current liabilities | $ | 840 | $ | 592 |
• | the amounts shown above exclude changes in cash and temporary cash investments, deferred income taxes, and current portion of debt and capital lease obligations, as well as the effect of certain noncash investing and financing activities discussed below; |
• | the amounts shown above exclude the current assets and current liabilities acquired in connection with the the Pembroke Acquisition in August 2011 and the acquisitions of three ethanol plants in the first quarter of 2010; |
• | amounts accrued for capital expenditures and deferred turnaround and catalyst costs are reflected in investing activities when such amounts are paid; |
• | amounts accrued for common stock purchases in the open market that are not settled as of the balance sheet date are reflected in financing activities when the purchases are settled and paid; and |
• | certain differences between consolidated balance sheet changes and the changes reflected above result from translating foreign currency denominated balances at the applicable exchange rates as of each balance sheet date. |
Nine Months Ended September 30, | |||||||
2011 | 2010 | ||||||
Interest paid in excess of amount capitalized | $ | 276 | $ | 302 | |||
Income taxes paid (received), net | 289 | (645 | ) |
Cash provided by (used in) operating activities: | |||
Paulsboro Refinery | $ | 42 | |
Delaware City Refinery | (76 | ) | |
Cash used in investing activities: | |||
Paulsboro Refinery | (32 | ) | |
Delaware City Refinery | — |
12. | FAIR VALUE MEASUREMENTS |
• | Level 1 - Observable inputs, such as unadjusted quoted prices in active markets for identical assets or liabilities. |
• | Level 2 - Inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. These include quoted prices for similar assets or liabilities in active markets and quoted prices for identical or similar assets or liabilities in markets that are not active. |
• | Level 3 - Unobservable inputs for the asset or liability for which there is little, if any, market activity at the measurement date. Unobservable inputs reflect our own assumptions about what market participants would use to price the asset or liability. The inputs are developed based on the best information available in the circumstances, which might include occasional market quotes or sales of similar instruments or our own financial data such as internally developed pricing models, discounted cash flow methodologies, as well as instruments for which the fair value determination requires significant judgment. |
Fair Value Measurements Using | |||||||||||||||||||
Quoted Prices in Active Markets (Level 1) | Significant Other Observable Inputs (Level 2) | Significant Unobservable Inputs (Level 3) | Total as of September 30, 2011 | ||||||||||||||||
Netting Adjustments | |||||||||||||||||||
Assets: | |||||||||||||||||||
Commodity derivative contracts | $ | 6,764 | $ | 238 | $ | — | $ | (6,734 | ) | $ | 268 | ||||||||
Physical purchase contracts | — | (81 | ) | — | — | (81 | ) | ||||||||||||
Investments of nonqualified benefit plans | 81 | — | 11 | — | 92 | ||||||||||||||
Other investments | — | — | — | — | — | ||||||||||||||
Liabilities: | |||||||||||||||||||
Commodity derivative contracts | 6,503 | 338 | — | (6,734 | ) | 107 | |||||||||||||
Nonqualified benefit plan obligations | 34 | — | — | — | 34 | ||||||||||||||
RINs obligation | 137 | — | — | — | 137 |
Fair Value Measurements Using | |||||||||||||||||||
Quoted Prices in Active Markets (Level 1) | Significant Other Observable Inputs (Level 2) | Significant Unobservable Inputs (Level 3) | Total as of December 31, 2010 | ||||||||||||||||
Netting Adjustments | |||||||||||||||||||
Assets: | |||||||||||||||||||
Commodity derivative contracts | $ | 3,240 | $ | 489 | $ | — | $ | (3,560 | ) | $ | 169 | ||||||||
Physical purchase contracts | — | 17 | — | — | 17 | ||||||||||||||
Investments of nonqualified benefit plans | 104 | — | 10 | — | 114 | ||||||||||||||
Other investments | — | — | — | — | — | ||||||||||||||
Liabilities: | |||||||||||||||||||
Commodity derivative contracts | 3,097 | 502 | — | (3,560 | ) | 39 | |||||||||||||
Nonqualified benefit plan obligations | 36 | — | — | — | 36 | ||||||||||||||
RINs obligation | 51 | — | — | — | 51 |
• | Commodity derivative contracts consist primarily of exchange-traded futures and swaps, and as disclosed in Note 13, some of these contracts are designated as hedging instruments. These contracts are measured at fair value using the market approach. Exchange-traded futures are valued based on quoted prices from the exchange and are categorized in Level 1 of the fair value hierarchy. Swaps are priced using third-party broker quotes, industry pricing services, and exchange-traded curves, with appropriate consideration of counterparty credit risk, but because they have contractual terms that are not identical to exchange-traded futures instruments with a comparable market price, these financial instruments are categorized in Level 2 of the fair value hierarchy. |
• | Physical purchase contracts to purchase inventories represent the fair value of firm commitments to purchase crude oil feedstocks and the fair value of fixed-price corn purchase contracts, and as disclosed in Note 13, some of these contracts are designated as hedging instruments. The fair values of these firm commitments and purchase contracts are measured using a market approach based on quoted prices from the commodity exchange, but because these commitments have contractual terms that are not identical to exchange-traded futures instruments with a comparable market price, they are categorized in Level 2 of the fair value hierarchy. |
• | Nonqualified benefit plan assets consist of investment securities held by our nonqualified defined benefit and nonqualified defined contribution plans. The nonqualified benefit plan obligations relate to our nonqualified defined contribution plans under which our obligations to eligible employees are equal to the fair value of the assets held by those plans. The nonqualified benefit plan assets categorized in Level 1 of the fair value hierarchy are measured at fair value using a market approach based on quotations from national securities exchanges. The nonqualified benefit plan assets categorized in Level 3 of the fair value hierarchy represent insurance contracts, the fair value of which is provided by the insurer. |
• | Other investments consist of (i) equity securities of private companies over which we do not exercise significant influence nor whose financial statements are consolidated into our financial statements and (ii) debt securities of a private company whose financial statements are not consolidated into our financial statements. We have elected to account for these investments at their fair values. These investments are categorized in Level 3 of the fair value hierarchy as the fair values of these investments are determined using the income approach based on internally developed analyses. |
• | Our RINs obligation represents a liability for the purchase of Renewable Identification Numbers (RINs) to satisfy our obligation to blend biofuels into the products we produce. A RIN represents a serial number assigned to each gallon of biofuel produced or imported into the U.S. as required by the EPA’s Renewable Fuel Standard, which was implemented in accordance with the Energy Policy Act of 2005. The EPA sets annual quotas for the percentage of biofuels that must be blended into motor fuels consumed in the U.S., and as a producer of motor fuels from petroleum, we are obligated to blend biofuels into the products we produce at a rate that is at least equal to the EPA’s quota. To the degree we are unable to blend at that rate, we must purchase RINs in the open market to satisfy our obligation. Our RINs obligation is based on our RINs deficiency and the price of those RINs as of the balance sheet date. Our RINs obligation is categorized in Level 1 of the fair value hierarchy and is measured at fair value using the market approach based on quoted prices from an independent pricing service. |
2011 | 2010 | ||||||||||||||
Investments of Nonqualified Benefit Plans | Other Investments | Investments of Nonqualified Benefit Plans | Other Investments | ||||||||||||
Three months ended September 30: | |||||||||||||||
Balance at beginning of period | $ | 11 | $ | — | $ | 10 | $ | — | |||||||
Purchases | — | 5 | — | — | |||||||||||
Total losses included in earnings | — | (5 | ) | — | — | ||||||||||
Transfers in and/or out of Level 3 | — | — | — | — | |||||||||||
Balance at end of period | $ | 11 | $ | — | $ | 10 | $ | — | |||||||
The amount of total losses included in earnings attributable to the change in unrealized losses relating to assets still held at end of period | $ | — | $ | (5 | ) | $ | — | $ | — | ||||||
Nine months ended September 30: | |||||||||||||||
Balance at beginning of period | $ | 10 | $ | — | $ | 10 | $ | — | |||||||
Purchases | — | 21 | — | 1 | |||||||||||
Total gains (losses) included in earnings | 1 | (21 | ) | — | (1 | ) | |||||||||
Transfers in and/or out of Level 3 | — | — | — | — | |||||||||||
Balance at end of period | $ | 11 | $ | — | $ | 10 | $ | — | |||||||
The amount of total gains (losses) included in earnings attributable to the change in unrealized gains (losses) relating to assets still held at end of period | $ | 1 | $ | (21 | ) | $ | — | $ | (1 | ) |
September 30, 2011 | December 31, 2010 | ||||||
Carrying amount (excluding capital leases) | $ | 7,595 | $ | 8,300 | |||
Fair value | 9,169 | 9,492 |
13. | PRICE RISK MANAGEMENT ACTIVITIES |
Notional Contract Volumes by Year of Maturity | |||
Derivative Instrument | 2011 | ||
Crude oil and refined products: | |||
Futures – long | 3,025 | ||
Futures – short | 16,453 | ||
Physical purchase contracts – long | 13,428 |
Notional Contract Volumes by Year of Maturity | |||
Derivative Instrument | 2012 | ||
Crude oil and refined products: | |||
Swaps – long | 5,241 | ||
Swaps – short | 5,241 |
Notional Contract Volumes by Year of Maturity | |||||||||
Derivative Instrument | 2011 | 2012 | 2013 | ||||||
Crude oil and refined products: | |||||||||
Swaps – long | 34,708 | 65,040 | — | ||||||
Swaps – short | 33,890 | 65,040 | — | ||||||
Futures – long | 200,076 | 40,388 | — | ||||||
Futures – short | 192,292 | 41,219 | — | ||||||
Options – long | 606 | 10 | — | ||||||
Options – short | 600 | — | — | ||||||
Corn: | |||||||||
Futures – long | 22,325 | 8,405 | — | ||||||
Futures – short | 41,300 | 23,980 | 260 | ||||||
Physical purchase contracts – long | 12,166 | 10,991 | 265 |
Notional Contract Volumes by Year of Maturity | ||||||
Derivative Instrument | 2011 | 2012 | ||||
Crude oil and refined products: | ||||||
Swaps – long | 6,196 | 3,240 | ||||
Swaps – short | 6,196 | 3,240 | ||||
Futures – long | 66,365 | 15,868 | ||||
Futures – short | 66,389 | 15,831 | ||||
Options – short | 75 | — | ||||
Natural gas: | ||||||
Futures – long | 5,050 | — | ||||
Futures – short | 5,050 | — | ||||
Corn: | ||||||
Swaps – long | — | 1,050 | ||||
Swaps – short | — | 1,050 | ||||
Futures – long | 3,850 | 60 | ||||
Futures – short | 2,350 | 1,060 |
Consolidated Balance Sheet Location | September 30, 2011 | ||||||||
Asset Derivatives | Liability Derivatives | ||||||||
Derivatives designated as hedging instruments | |||||||||
Commodity contracts: | |||||||||
Futures | Receivables, net | $ | 360 | $ | 237 | ||||
Swaps | Receivables, net | 46 | 40 | ||||||
Swaps | Accrued expenses | 4 | 3 | ||||||
Total | $ | 410 | $ | 280 | |||||
Derivatives not designated as hedging instruments | |||||||||
Commodity contracts: | |||||||||
Futures | Receivables, net | $ | 6,170 | $ | 6,266 | ||||
Swaps | Receivables, net | 6 | 5 | ||||||
Swaps | Prepaid expenses and other | 2 | 1 | ||||||
Swaps | Accrued expenses | 181 | 268 | ||||||
Options | Receivables, net | 5 | — | ||||||
Options | Accrued expenses | — | 21 | ||||||
Physical purchase contracts | Inventories | — | 81 | ||||||
Total | $ | 6,364 | $ | 6,642 | |||||
Total derivatives | $ | 6,774 | $ | 6,922 |
Consolidated Balance Sheet Location | December 31, 2010 | ||||||||
Asset Derivatives | Liability Derivatives | ||||||||
Derivatives designated as hedging instruments | |||||||||
Commodity contracts: | |||||||||
Futures | Receivables, net | $ | 120 | $ | 183 | ||||
Swaps | Prepaid expenses and other | 55 | 39 | ||||||
Swaps | Accrued expenses | 31 | 32 | ||||||
Total | $ | 206 | $ | 254 | |||||
Derivatives not designated as hedging instruments | |||||||||
Commodity contracts: | |||||||||
Futures | Receivables, net | $ | 2,717 | $ | 2,914 | ||||
Swaps | Prepaid expenses and other | 287 | 277 | ||||||
Swaps | Accrued expenses | 116 | 148 | ||||||
Options | Accrued expenses | — | 6 | ||||||
Physical purchase contracts | Inventories | 17 | — | ||||||
Total | $ | 3,137 | $ | 3,345 | |||||
Total derivatives | $ | 3,343 | $ | 3,599 |
Derivatives in Fair Value Hedging Relationships | Location | Gain or (Loss) Recognized in Income on Derivatives | Gain or (Loss) Recognized in Income on Hedged Item | Gain or (Loss) Recognized in Income for Ineffective Portion of Derivative | ||||||||||||||||||||||
2011 | 2010 | 2011 | 2010 | 2011 | 2010 | |||||||||||||||||||||
Three months ended September 30: | ||||||||||||||||||||||||||
Commodity contracts | Cost of sales | $ | 170 | $ | 54 | $ | (161 | ) | $ | (56 | ) | $ | 9 | $ | (2 | ) | ||||||||||
Nine months ended September 30: | ||||||||||||||||||||||||||
Commodity contracts | Cost of sales | 219 | 253 | (222 | ) | (247 | ) | (3 | ) | 6 |
Derivatives in Cash Flow Hedging Relationships | Gain or (Loss) Recognized in OCI on Derivatives (Effective Portion) | Gain or (Loss) Reclassified from Accumulated OCI into Income (Effective Portion) | Gain or (Loss) Recognized in Income on Derivatives (Ineffective Portion) | |||||||||||||||||||||||||
2011 | 2010 | Location | 2011 | 2010 | Location | 2011 | 2010 | |||||||||||||||||||||
Three months ended September 30: | ||||||||||||||||||||||||||||
Commodity contracts | $ | 20 | $ | — | Cost of sales | $ | — | $ | 37 | Cost of sales | $ | 4 | $ | — | ||||||||||||||
Nine months ended September 30: | ||||||||||||||||||||||||||||
Commodity contracts | 20 | (2 | ) | Cost of sales | — | 135 | Cost of sales | 4 | — |
Derivatives Designated as Economic Hedges and Other Derivative Instruments | Location of Gain or (Loss) Recognized in Income on Derivatives | Gain or (Loss) Recognized in Income on Derivatives | ||||||||
2011 | 2010 | |||||||||
Three months ended September 30: | ||||||||||
Commodity contracts | Cost of sales | $ | 9 | $ | 22 | |||||
Foreign currency contracts | Cost of sales | 41 | (5 | ) | ||||||
Other contract | Cost of sales | 29 | — | |||||||
Total | $ | 79 | $ | 17 | ||||||
Nine months ended September 30: | ||||||||||
Commodity contracts | Cost of sales | $ | (362 | ) | $ | (93 | ) | |||
Foreign currency contracts | Cost of sales | 32 | (2 | ) | ||||||
Other contract | Cost of sales | 29 | — | |||||||
Total | $ | (301 | ) | $ | (95 | ) |
Trading Derivatives | Location of Gain or (Loss) Recognized in Income on Derivatives | Gain or (Loss) Recognized in Income on Derivatives | ||||||||
2011 | 2010 | |||||||||
Three months ended September 30: | ||||||||||
Commodity contracts | Cost of sales | $ | 3 | $ | 2 | |||||
Nine months ended September 30: | ||||||||||
Commodity contracts | Cost of sales | 17 | 7 |
Item 2. | Management’s Discussion and Analysis of Financial Condition and Results of Operations |
• | future refining margins, including gasoline and distillate margins; |
• | future retail margins, including gasoline, diesel, home heating oil, and convenience store merchandise margins; |
• | future ethanol margins; |
• | expectations regarding feedstock costs, including crude oil differentials, and operating expenses; |
• | anticipated levels of crude oil and refined product inventories; |
• | our anticipated level of capital investments, including deferred refinery turnaround and catalyst costs and capital expenditures for environmental and other purposes, and the effect of those capital investments on our results of operations; |
• | anticipated trends in the supply of and demand for crude oil and other feedstocks and refined products in the U.S., Canada, the United Kingdom, Ireland, and elsewhere; |
• | expectations regarding environmental, tax, and other regulatory initiatives; and |
• | the effect of general economic and other conditions on refining, retail, and ethanol industry fundamentals. |
• | 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; |
• | political and economic conditions in nations that produce crude oil or consume refined products, including the U.S., Canada, Europe, the Middle East, Africa, and South America; |
• | domestic and foreign demand for, and supplies of, refined products such as gasoline, diesel fuel, jet fuel, home heating oil, petrochemicals, and ethanol; |
• | domestic and foreign demand for, and supplies of, crude oil and other feedstocks; |
• | the ability of the members of the Organization of Petroleum Exporting Countries (OPEC) to agree on and to maintain crude oil price and production controls; |
• | the level of consumer demand, including seasonal fluctuations; |
• | refinery overcapacity or undercapacity; |
• | our ability to successfully integrate any acquired businesses into our operations; |
• | the actions taken by competitors, including both pricing and adjustments to refining capacity in response to market conditions; |
• | the level of foreign imports of refined products to the U.S., Canada, or the United Kingdom; |
• | accidents or other unscheduled shutdowns affecting our refineries, machinery, pipelines, or equipment, or those of our suppliers or customers; |
• | changes in the cost or availability of transportation for feedstocks and refined products; |
• | the price, availability, and acceptance of alternative fuels and alternative-fuel vehicles; |
• | the levels of government subsidies for ethanol and other alternative fuels; |
• | delay of, cancellation of, or failure to implement planned capital projects and realize the various assumptions and benefits projected for such projects or cost overruns in constructing such planned capital projects; |
• | lower than expected ethanol margins; |
• | earthquakes, hurricanes, tornadoes, and irregular weather, which can unforeseeably affect the price or availability of natural gas, crude oil, grain and other feedstocks, and refined products and ethanol; |
• | rulings, judgments, or settlements in litigation or other legal or regulatory matters, including unexpected environmental remediation costs, in excess of any reserves or insurance coverage; |
• | legislative or regulatory action, including the introduction or enactment of federal, state, municipal, or foreign legislation or rulemakings, including tax and environmental regulations, such as those to be implemented under the California Global Warming Solutions Act (also known as AB 32) and the EPA’s regulation of greenhouse gases, which may adversely affect our business or operations; |
• | changes in the credit ratings assigned to our debt securities and trade credit; |
• | changes in currency exchange rates, including the value of the Canadian dollar, the pound sterling, and the Euro relative to the U.S. dollar; and |
• | overall economic conditions, including the stability and liquidity of financial markets. |
Three Months Ended September 30, | ||||||||||||
2011 | 2010 | Change | ||||||||||
Operating income (loss) by business segment: | ||||||||||||
Refining | $ | 1,947 | $ | 590 | $ | 1,357 | ||||||
Retail | 97 | 105 | (8 | ) | ||||||||
Ethanol | 107 | 47 | 60 | |||||||||
Corporate | (172 | ) | (152 | ) | (20 | ) | ||||||
Total | $ | 1,979 | $ | 590 | $ | 1,389 | ||||||
Nine Months Ended September 30, | ||||||||||||
2011 | 2010 | Change | ||||||||||
Operating income (loss) by business segment: | ||||||||||||
Refining | $ | 3,476 | $ | 1,479 | $ | 1,997 | ||||||
Retail | 298 | 285 | 13 | |||||||||
Ethanol | 215 | 139 | 76 | |||||||||
Corporate | (476 | ) | (405 | ) | (71 | ) | ||||||
Total | $ | 3,513 | $ | 1,498 | $ | 2,015 |
Three Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Operating revenues | $ | 33,713 | $ | 21,015 | $ | 12,698 | |||||
Costs and expenses: | |||||||||||
Cost of sales (d) | 30,033 | 18,915 | 11,118 | ||||||||
Operating expenses: | |||||||||||
Refining | 870 | 753 | 117 | ||||||||
Retail (d) | 177 | 169 | 8 | ||||||||
Ethanol | 103 | 96 | 7 | ||||||||
General and administrative expenses | 161 | 139 | 22 | ||||||||
Depreciation and amortization expense: | |||||||||||
Refining | 340 | 303 | 37 | ||||||||
Retail | 29 | 27 | 2 | ||||||||
Ethanol | 10 | 10 | — | ||||||||
Corporate | 11 | 13 | (2 | ) | |||||||
Total costs and expenses | 31,734 | 20,425 | 11,309 | ||||||||
Operating income | 1,979 | 590 | 1,389 | ||||||||
Other income, net | 1 | 17 | (16 | ) | |||||||
Interest and debt expense, net of capitalized interest | (88 | ) | (119 | ) | 31 | ||||||
Income from continuing operations before income tax expense | 1,892 | 488 | 1,404 | ||||||||
Income tax expense | 689 | 185 | 504 | ||||||||
Income from continuing operations | 1,203 | 303 | 900 | ||||||||
Income (loss) from discontinued operations, net of income taxes | — | (11 | ) | 11 | |||||||
Net income | 1,203 | 292 | 911 | ||||||||
Less: Net loss attributable to noncontrolling interests | — | — | — | ||||||||
Net income attributable to Valero stockholders | $ | 1,203 | $ | 292 | $ | 911 | |||||
Net income attributable to Valero stockholders: | |||||||||||
Continuing operations | $ | 1,203 | $ | 303 | $ | 900 | |||||
Discontinued operations | — | (11 | ) | 11 | |||||||
Total | $ | 1,203 | $ | 292 | $ | 911 | |||||
Earnings per common share – assuming dilution: | |||||||||||
Continuing operations | $ | 2.11 | $ | 0.53 | $ | 1.58 | |||||
Discontinued operations | — | (0.02 | ) | 0.02 | |||||||
Total | $ | 2.11 | $ | 0.51 | $ | 1.60 |
Three Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Refining (a) (b): | |||||||||||
Operating income | $ | 1,947 | $ | 590 | $ | 1,357 | |||||
Throughput margin per barrel (e) | $ | 13.24 | $ | 8.13 | $ | 5.11 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 3.65 | 3.71 | (0.06 | ) | |||||||
Depreciation and amortization expense | 1.43 | 1.50 | (0.07 | ) | |||||||
Total operating costs per barrel | 5.08 | 5.21 | (0.13 | ) | |||||||
Operating income per barrel | $ | 8.16 | $ | 2.92 | $ | 5.24 | |||||
Throughput volumes (thousand barrels per day): | |||||||||||
Feedstocks: | |||||||||||
Heavy sour crude | 540 | 443 | 97 | ||||||||
Medium/light sour crude | 455 | 402 | 53 | ||||||||
Acidic sweet crude | 150 | 51 | 99 | ||||||||
Sweet crude | 739 | 708 | 31 | ||||||||
Residuals | 310 | 239 | 71 | ||||||||
Other feedstocks | 123 | 113 | 10 | ||||||||
Total feedstocks | 2,317 | 1,956 | 361 | ||||||||
Blendstocks and other | 275 | 247 | 28 | ||||||||
Total throughput volumes | 2,592 | 2,203 | 389 | ||||||||
Yields (thousand barrels per day): | |||||||||||
Gasolines and blendstocks | 1,196 | 1,088 | 108 | ||||||||
Distillates | 894 | 766 | 128 | ||||||||
Other products (f) | 519 | 381 | 138 | ||||||||
Total yields | 2,609 | 2,235 | 374 |
Three Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Gulf Coast: | |||||||||||
Operating income | $ | 1,167 | $ | 388 | $ | 779 | |||||
Throughput volumes (thousand barrels per day) | 1,522 | 1,336 | 186 | ||||||||
Throughput margin per barrel (e) | $ | 13.08 | $ | 8.34 | $ | 4.74 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 3.31 | 3.65 | (0.34 | ) | |||||||
Depreciation and amortization expense | 1.43 | 1.54 | (0.11 | ) | |||||||
Total operating costs per barrel | 4.74 | 5.19 | (0.45 | ) | |||||||
Operating income per barrel | $ | 8.34 | $ | 3.15 | $ | 5.19 | |||||
Mid-Continent: | |||||||||||
Operating income | $ | 586 | $ | 131 | $ | 455 | |||||
Throughput volumes (thousand barrels per day) | 400 | 422 | (22 | ) | |||||||
Throughput margin per barrel (e) | $ | 22.27 | $ | 8.06 | $ | 14.21 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 4.76 | 3.34 | 1.42 | ||||||||
Depreciation and amortization expense | 1.59 | 1.33 | 0.26 | ||||||||
Total operating costs per barrel | 6.35 | 4.67 | 1.68 | ||||||||
Operating income per barrel | $ | 15.92 | $ | 3.39 | $ | 12.53 | |||||
North Atlantic (a) (b): | |||||||||||
Operating income | $ | 65 | $ | 36 | $ | 29 | |||||
Throughput volumes (thousand barrels per day) | 386 | 193 | 193 | ||||||||
Throughput margin per barrel (e) | $ | 5.46 | $ | 6.04 | $ | (0.58 | ) | ||||
Operating costs per barrel: | |||||||||||
Operating expenses | 2.91 | 2.75 | 0.16 | ||||||||
Depreciation and amortization expense | 0.74 | 1.30 | (0.56 | ) | |||||||
Total operating costs per barrel | 3.65 | 4.05 | (0.40 | ) | |||||||
Operating income per barrel | $ | 1.81 | $ | 1.99 | $ | (0.18 | ) | ||||
West Coast: | |||||||||||
Operating income | $ | 129 | $ | 35 | $ | 94 | |||||
Throughput volumes (thousand barrels per day) | 284 | 252 | 32 | ||||||||
Throughput margin per barrel (e) | $ | 11.96 | $ | 8.66 | $ | 3.30 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 4.94 | 5.42 | (0.48 | ) | |||||||
Depreciation and amortization expense | 2.08 | 1.74 | 0.34 | ||||||||
Total operating costs per barrel | 7.02 | 7.16 | (0.14 | ) | |||||||
Operating income per barrel | $ | 4.94 | $ | 1.50 | $ | 3.44 | |||||
Total refining operating income | $ | 1,947 | $ | 590 | $ | 1,357 |
Three Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Feedstocks: | |||||||||||
Louisiana Light Sweet (LLS) crude oil | $ | 112.21 | $ | 78.66 | $ | 33.55 | |||||
LLS less West Texas Intermediate (WTI) crude oil | 22.47 | 2.58 | 19.89 | ||||||||
LLS less Alaska North Slope (ANS) crude oil | 0.60 | 3.03 | (2.43 | ) | |||||||
LLS less Brent crude oil | (1.43 | ) | 1.73 | (3.16 | ) | ||||||
LLS less Mars crude oil | 2.53 | 3.96 | (1.43 | ) | |||||||
LLS less Maya crude oil | 13.48 | 11.04 | 2.44 | ||||||||
WTI crude oil | 89.74 | 76.08 | 13.66 | ||||||||
WTI less Mars crude oil | (19.94 | ) | 1.38 | (21.32 | ) | ||||||
WTI less Maya crude oil | (8.99 | ) | 8.46 | (17.45 | ) | ||||||
Products: | |||||||||||
Gulf Coast: | |||||||||||
Conventional 87 gasoline less LLS | $ | 8.20 | $ | 4.35 | $ | 3.85 | |||||
Ultra-low-sulfur diesel less LLS | 14.19 | 9.12 | 5.07 | ||||||||
Propylene less LLS | 12.46 | 2.61 | 9.85 | ||||||||
Conventional 87 gasoline less WTI | 30.67 | 6.93 | 23.74 | ||||||||
Ultra-low-sulfur diesel less WTI | 36.66 | 11.70 | 24.96 | ||||||||
Propylene less WTI | 34.93 | 5.19 | 29.74 | ||||||||
Mid-Continent: | |||||||||||
Conventional 87 gasoline less WTI | 32.11 | 9.20 | 22.91 | ||||||||
Ultra-low-sulfur diesel less WTI | 38.34 | 13.20 | 25.14 | ||||||||
North Atlantic: | |||||||||||
Conventional 87 gasoline less Brent | 7.48 | 5.85 | 1.63 | ||||||||
Ultra-low-sulfur diesel less Brent | 14.55 | 12.16 | 2.39 | ||||||||
Conventional 87 gasoline less WTI | 31.38 | 6.70 | 24.68 | ||||||||
Ultra-low-sulfur diesel less WTI | 38.45 | 13.01 | 25.44 | ||||||||
West Coast: | |||||||||||
CARBOB 87 gasoline less ANS | 10.27 | 16.96 | (6.69 | ) | |||||||
CARB diesel less ANS | 15.77 | 15.10 | 0.67 | ||||||||
CARBOB 87 gasoline less WTI | 32.14 | 16.51 | 15.63 | ||||||||
CARB diesel less WTI | 37.64 | 14.65 | 22.99 | ||||||||
New York Harbor corn crush (dollars per gallon) | 0.36 | 0.43 | (0.07 | ) |
Three Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Retail–U.S.: (d) | |||||||||||
Operating income | $ | 59 | $ | 72 | $ | (13 | ) | ||||
Company-operated fuel sites (average) | 994 | 990 | 4 | ||||||||
Fuel volumes (gallons per day per site) | 5,168 | 5,204 | (36 | ) | |||||||
Fuel margin per gallon | $ | 0.155 | $ | 0.176 | $ | (0.021 | ) | ||||
Merchandise sales | $ | 324 | $ | 322 | $ | 2 | |||||
Merchandise margin (percentage of sales) | 29.2 | % | 28.8 | % | 0.4 | % | |||||
Margin on miscellaneous sales | $ | 22 | $ | 21 | $ | 1 | |||||
Operating expenses | $ | 111 | $ | 108 | $ | 3 | |||||
Depreciation and amortization expense | $ | 19 | $ | 18 | $ | 1 | |||||
Retail–Canada: (d) | |||||||||||
Operating income | $ | 38 | $ | 33 | $ | 5 | |||||
Fuel volumes (thousand gallons per day) | 3,214 | 3,214 | — | ||||||||
Fuel margin per gallon | $ | 0.273 | $ | 0.247 | $ | 0.026 | |||||
Merchandise sales | $ | 72 | $ | 66 | $ | 6 | |||||
Merchandise margin (percentage of sales) | 29.4 | % | 30.4 | % | (1 | )% | |||||
Margin on miscellaneous sales | $ | 11 | $ | 10 | $ | 1 | |||||
Operating expenses | $ | 66 | $ | 61 | $ | 5 | |||||
Depreciation and amortization expense | $ | 10 | $ | 9 | $ | 1 | |||||
Ethanol (c): | |||||||||||
Operating income | $ | 107 | $ | 47 | $ | 60 | |||||
Production (thousand gallons per day) | 3,272 | 3,100 | 172 | ||||||||
Gross margin per gallon of production (e) | $ | 0.73 | $ | 0.54 | $ | 0.19 | |||||
Operating costs per gallon of production: | |||||||||||
Operating expenses | 0.34 | 0.34 | — | ||||||||
Depreciation and amortization expense | 0.04 | 0.03 | 0.01 | ||||||||
Total operating costs per gallon of production | 0.38 | 0.37 | 0.01 | ||||||||
Operating income per gallon of production | $ | 0.35 | $ | 0.17 | $ | 0.18 |
(a) | The information presented for the three months ended September 30, 2011 includes the results of operations of our refinery in Wales, United Kingdom (Pembroke Refinery), including the related marketing and logistics business, from the date of its acquisition, August 1, 2011, through September 30, 2011. In addition, the refining segment and North Atlantic region operating highlights for the three months ended September 30, 2011 include the Pembroke Refinery. |
(b) | In December 2010, we sold our Paulsboro Refinery to PBF Holding Company LLC. The results of operations of the Paulsboro Refinery have been presented as discontinued operations for the three months ended September 30, 2010. In addition, the refining segment and North Atlantic region operating highlights exclude the Paulsboro Refinery for the three months ended September 30, 2010. |
(c) | We acquired three ethanol plants in the first quarter of 2010. The information presented includes the results of operations of those plants commencing on their respective acquisition dates. Ethanol production volumes are based on total production during each period divided by actual calendar days per period. |
(d) | Credit card transaction processing fees incurred by our retail segment of $23 million for the three months ended September 30, 2010 have been reclassified from retail operating expenses to cost of sales. The Retail–U.S. and Retail–Canada operating highlights for the three months ended September 30, 2010 have been restated to reflect this reclassification. |
(e) | Throughput margin per barrel represents operating revenues less cost of sales of our refining segment divided by throughput volumes. Gross margin per gallon of production represents operating revenues less cost of sales of our ethanol segment divided by production volumes. |
(f) | Other products primarily include petrochemicals, gas oils, No. 6 fuel oil, petroleum coke, and asphalt. |
(g) | The regions reflected herein contain the following refineries: the Gulf Coast region includes the Corpus Christi East, Corpus Christi West, Texas City, Houston, Three Rivers, St. Charles, Aruba, and Port Arthur Refineries; the Mid-Continent region includes the McKee, Ardmore, and Memphis Refineries; the North Atlantic (formerly known as Northeast) region includes the Pembroke and Quebec City Refineries; and the West Coast region includes the Benicia and Wilmington Refineries. |
(h) | Average market reference prices for LLS crude oil, along with price differentials between the price of LLS crude oil and other types of crude oil, have been included in the table of Average Market Reference Prices and Differentials. The table also includes price differentials by region between the prices of certain products and the benchmark crude oil that provides the best indicator of product margins for each region. Prior to the first quarter of 2011, feedstock and product differentials presented herein were based on the price of WTI crude oil. However, the price of WTI crude oil no longer provides a reasonable benchmark price of crude oil for all regions. Beginning in late 2010, WTI light-sweet crude oil began to price at a discount to waterborne light-sweet crude oils, such as LLS and Brent, because of increased WTI supplies resulting from greater domestic production and increased deliveries of crude oil from Canada into the Mid-Continent region. Therefore, the use of the price of WTI crude oil as a benchmark price for regions that do not process WTI crude oil is no longer reasonable. |
• | The WTI-based benchmark reference margin for Mid-Continent conventional 87 gasoline was $32.11 per barrel for the third quarter of 2011, compared to $9.20 per barrel for the third quarter of 2010, representing a favorable increase of $22.91 per barrel. In addition, the WTI-based benchmark reference margin for Mid-Continent ultra-low sulfur diesel (a type of distillate) was $38.34 per barrel for the third quarter of 2011, compared to $13.20 per barrel for the third quarter of 2010, representing a favorable increase of $25.14 per barrel. We estimate that these increases in gasoline and distillate margins per barrel had a positive impact to our refining margin of approximately $500 million and $300 million, respectively, quarter versus quarter. The increases in the gasoline and distillate benchmark reference margins in the Mid-Continent region are primarily due to the substantial discount in the price of WTI crude oil, the primary type of crude oil processed by our Mid-Continent refineries, versus LLS-type crude oils. Historically, the price of WTI crude oil has tracked LLS crude oil, but due to the significant development of crude oil reserves within the Mid-Continent region and increased deliveries of crude oil from Canada into the Mid-Continent region, the increased supply of WTI crude oil has resulted in WTI crude oil currently being priced at a significant discount to LLS crude oil. |
• | The LLS-based benchmark reference margin for Gulf Coast conventional 87 gasoline was $8.20 per barrel for the third quarter of 2011, compared to $4.35 per barrel for the third quarter of 2010, representing a favorable increase of $3.85 per barrel. In addition, the LLS-based benchmark reference margin for Gulf Coast ultra-low sulfur diesel was $14.19 per barrel for the third quarter of 2011, compared to $9.12 per barrel for the third quarter of 2010, representing a favorable increase of $5.07 per barrel. We estimate that these increases in gasoline and distillate margins per barrel had a positive impact to our refining margin of approximately $200 million and $250 million, respectively, quarter versus quarter. The increases in the gasoline and distillate benchmark reference margins are supported by increased exports of gasoline and distillate as well as an increase in demand for distillates. |
• | In addition, our system benefited from the increase in the discount of the price of heavy sour crude oils as compared to the price of sweet crude oils. For example, Maya crude oil, which is a type of heavy sour crude oil, sold at a discount of $13.48 per barrel to LLS crude oil, which is a type of sweet crude oil, during the third quarter of 2011. This compares to a discount of $11.04 per barrel during the third quarter of 2010, representing a favorable increase of $2.44 per barrel. We estimate that the increase in the discounts for all types of sour crude oil that we process had a positive impact to our refining margin of approximately $120 million, quarter versus quarter. |
Nine Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Operating revenues | $ | 91,314 | $ | 60,069 | $ | 31,245 | |||||
Costs and expenses: | |||||||||||
Cost of sales (d) (e) | 82,981 | 54,198 | 28,783 | ||||||||
Operating expenses: | |||||||||||
Refining | 2,427 | 2,210 | 217 | ||||||||
Retail (d) | 508 | 484 | 24 | ||||||||
Ethanol | 302 | 267 | 35 | ||||||||
General and administrative expenses | 442 | 367 | 75 | ||||||||
Depreciation and amortization expense: | |||||||||||
Refining | 995 | 898 | 97 | ||||||||
Retail | 84 | 80 | 4 | ||||||||
Ethanol | 28 | 27 | 1 | ||||||||
Corporate | 34 | 38 | (4 | ) | |||||||
Asset impairment loss | — | 2 | (2 | ) | |||||||
Total costs and expenses | 87,801 | 58,571 | 29,230 | ||||||||
Operating income | 3,513 | 1,498 | 2,015 | ||||||||
Other income, net | 28 | 29 | (1 | ) | |||||||
Interest and debt expense, net of capitalized interest | (312 | ) | (363 | ) | 51 | ||||||
Income from continuing operations before income tax expense | 3,229 | 1,164 | 2,065 | ||||||||
Income tax expense | 1,178 | 421 | 757 | ||||||||
Income from continuing operations | 2,051 | 743 | 1,308 | ||||||||
Income (loss) from discontinued operations, net of income taxes | (7 | ) | 19 | (26 | ) | ||||||
Net income | 2,044 | 762 | 1,282 | ||||||||
Less: Net loss attributable to noncontrolling interests | (1 | ) | — | (1 | ) | ||||||
Net income attributable to Valero stockholders | $ | 2,045 | $ | 762 | $ | 1,283 | |||||
Net income attributable to Valero stockholders: | |||||||||||
Continuing operations | $ | 2,052 | $ | 743 | $ | 1,309 | |||||
Discontinued operations | (7 | ) | 19 | (26 | ) | ||||||
Total | $ | 2,045 | $ | 762 | $ | 1,283 | |||||
Earnings per common share – assuming dilution: | |||||||||||
Continuing operations | $ | 3.59 | $ | 1.31 | $ | 2.28 | |||||
Discontinued operations | (0.01 | ) | 0.03 | (0.04 | ) | ||||||
Total | $ | 3.58 | $ | 1.34 | $ | 2.24 |
Nine Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Refining (a) (b): | |||||||||||
Operating income (e) | $ | 3,476 | $ | 1,479 | $ | 1,997 | |||||
Throughput margin per barrel (e) (f) | $ | 10.80 | $ | 7.97 | $ | 2.83 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 3.80 | 3.84 | (0.04 | ) | |||||||
Depreciation and amortization expense | 1.56 | 1.56 | — | ||||||||
Total operating costs per barrel | 5.36 | 5.40 | (0.04 | ) | |||||||
Operating income per barrel | $ | 5.44 | $ | 2.57 | $ | 2.87 | |||||
Throughput volumes (thousand barrels per day): | |||||||||||
Feedstocks: | |||||||||||
Heavy sour crude | 455 | 452 | 3 | ||||||||
Medium/light sour crude | 415 | 399 | 16 | ||||||||
Acidic sweet crude | 117 | 51 | 66 | ||||||||
Sweet crude | 695 | 655 | 40 | ||||||||
Residuals | 284 | 195 | 89 | ||||||||
Other feedstocks | 122 | 115 | 7 | ||||||||
Total feedstocks | 2,088 | 1,867 | 221 | ||||||||
Blendstocks and other | 252 | 241 | 11 | ||||||||
Total throughput volumes | 2,340 | 2,108 | 232 | ||||||||
Yields (thousand barrels per day): | |||||||||||
Gasolines and blendstocks | 1,069 | 1,046 | 23 | ||||||||
Distillates | 793 | 695 | 98 | ||||||||
Other products (g) | 491 | 392 | 99 | ||||||||
Total yields | 2,353 | 2,133 | 220 |
Nine Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Gulf Coast: | |||||||||||
Operating income (e) | $ | 2,064 | $ | 1,027 | $ | 1,037 | |||||
Throughput volumes (thousand barrels per day) | 1,418 | 1,268 | 150 | ||||||||
Throughput margin per barrel (e) (f) | $ | 10.48 | $ | 8.35 | $ | 2.13 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 3.62 | 3.78 | (0.16 | ) | |||||||
Depreciation and amortization expense | 1.53 | 1.60 | (0.07 | ) | |||||||
Total operating costs per barrel | 5.15 | 5.38 | (0.23 | ) | |||||||
Operating income per barrel | $ | 5.33 | $ | 2.97 | $ | 2.36 | |||||
Mid-Continent: | |||||||||||
Operating income (e) | $ | 1,146 | $ | 271 | $ | 875 | |||||
Throughput volumes (thousand barrels per day) | 401 | 392 | 9 | ||||||||
Throughput margin per barrel (e) (f) | $ | 16.18 | $ | 7.59 | $ | 8.59 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 4.14 | 3.63 | 0.51 | ||||||||
Depreciation and amortization expense | 1.56 | 1.42 | 0.14 | ||||||||
Total operating costs per barrel | 5.70 | 5.05 | 0.65 | ||||||||
Operating income per barrel | $ | 10.48 | $ | 2.54 | $ | 7.94 | |||||
North Atlantic (a) (b): | |||||||||||
Operating income | $ | 104 | $ | 81 | $ | 23 | |||||
Throughput volumes (thousand barrels per day) | 268 | 189 | 79 | ||||||||
Throughput margin per barrel (f) | $ | 5.32 | $ | 6.01 | $ | (0.69 | ) | ||||
Operating costs per barrel: | |||||||||||
Operating expenses | 2.92 | 2.98 | (0.06 | ) | |||||||
Depreciation and amortization expense | 0.98 | 1.47 | (0.49 | ) | |||||||
Total operating costs per barrel | 3.90 | 4.45 | (0.55 | ) | |||||||
Operating income per barrel | $ | 1.42 | $ | 1.56 | $ | (0.14 | ) | ||||
West Coast: | |||||||||||
Operating income (e) | $ | 162 | $ | 102 | $ | 60 | |||||
Throughput volumes (thousand barrels per day) | 253 | 259 | (6 | ) | |||||||
Throughput margin per barrel (e) (f) | $ | 9.87 | $ | 8.14 | $ | 1.73 | |||||
Operating costs per barrel: | |||||||||||
Operating expenses | 5.21 | 5.08 | 0.13 | ||||||||
Depreciation and amortization expense | 2.31 | 1.62 | 0.69 | ||||||||
Total operating costs per barrel | 7.52 | 6.70 | 0.82 | ||||||||
Operating income per barrel | $ | 2.35 | $ | 1.44 | $ | 0.91 | |||||
Operating income for regions above | $ | 3,476 | $ | 1,481 | $ | 1,995 | |||||
Asset impairment loss applicable to refining | — | (2 | ) | 2 | |||||||
Total refining operating income | $ | 3,476 | $ | 1,479 | $ | 1,997 |
Nine Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Feedstocks: | |||||||||||
LLS crude oil | $ | 111.73 | $ | 79.35 | $ | 32.38 | |||||
LLS less WTI | 16.34 | 1.83 | 14.51 | ||||||||
LLS less ANS crude oil | 2.44 | 2.27 | 0.17 | ||||||||
LLS less Brent crude oil | (0.82 | ) | 2.14 | (2.96 | ) | ||||||
LLS less Mars crude oil | 4.05 | 3.39 | 0.66 | ||||||||
LLS less Maya crude oil | 14.58 | 10.88 | 3.70 | ||||||||
WTI crude oil | 95.39 | 77.52 | 17.87 | ||||||||
WTI less Mars crude oil | (12.29 | ) | 1.56 | (13.85 | ) | ||||||
WTI less Maya crude oil | (1.76 | ) | 9.05 | (10.81 | ) | ||||||
Products: | |||||||||||
Gulf Coast: | |||||||||||
Conventional 87 gasoline less LLS | $ | 7.43 | $ | 6.26 | $ | 1.17 | |||||
Ultra-low-sulfur diesel less LLS | 13.09 | 8.61 | 4.48 | ||||||||
Propylene less LLS | 19.33 | 7.80 | 11.53 | ||||||||
Conventional 87 gasoline less WTI | 23.77 | 8.09 | 15.68 | ||||||||
Ultra-low-sulfur diesel less WTI | 29.43 | 10.44 | 18.99 | ||||||||
Propylene less WTI | 35.67 | 9.63 | 26.04 | ||||||||
Mid-Continent: | |||||||||||
Conventional 87 gasoline less WTI | 24.79 | 8.77 | 16.02 | ||||||||
Ultra-low-sulfur diesel less WTI | 30.75 | 11.06 | 19.69 | ||||||||
North Atlantic: | |||||||||||
Conventional 87 gasoline less Brent | 6.29 | 8.33 | (2.04 | ) | |||||||
Ultra-low-sulfur diesel less Brent | 14.04 | 12.15 | 1.89 | ||||||||
Conventional 87 gasoline less WTI | 23.45 | 8.02 | 15.43 | ||||||||
Ultra-low-sulfur diesel less WTI | 31.20 | 11.84 | 19.36 | ||||||||
West Coast: | |||||||||||
CARBOB 87 gasoline less ANS | 13.39 | 14.97 | (1.58 | ) | |||||||
CARB diesel less ANS | 18.56 | 12.95 | 5.61 | ||||||||
CARBOB 87 gasoline less WTI | 27.29 | 14.53 | 12.76 | ||||||||
CARB diesel less WTI | 32.46 | 12.51 | 19.95 | ||||||||
New York Harbor corn crush (dollars per gallon) | 0.17 | 0.41 | (0.24 | ) |
Nine Months Ended September 30, | |||||||||||
2011 | 2010 | Change | |||||||||
Retail–U.S.: (d) | |||||||||||
Operating income | $ | 165 | $ | 181 | $ | (16 | ) | ||||
Company-operated fuel sites (average) | 994 | 990 | 4 | ||||||||
Fuel volumes (gallons per day per site) | 5,053 | 5,115 | (62 | ) | |||||||
Fuel margin per gallon | $ | 0.146 | $ | 0.158 | $ | (0.012 | ) | ||||
Merchandise sales | $ | 930 | $ | 910 | $ | 20 | |||||
Merchandise margin (percentage of sales) | 28.6 | % | 28.4 | % | 0.2 | % | |||||
Margin on miscellaneous sales | $ | 66 | $ | 65 | $ | 1 | |||||
Operating expenses | $ | 312 | $ | 306 | $ | 6 | |||||
Depreciation and amortization expense | $ | 56 | $ | 54 | $ | 2 | |||||
Retail–Canada: (d) | |||||||||||
Operating income | $ | 133 | $ | 104 | $ | 29 | |||||
Fuel volumes (thousand gallons per day) | 3,210 | 3,131 | 79 | ||||||||
Fuel margin per gallon | $ | 0.303 | $ | 0.263 | $ | 0.040 | |||||
Merchandise sales | $ | 197 | $ | 179 | $ | 18 | |||||
Merchandise margin (percentage of sales) | 29.6 | % | 30.3 | % | (0.7 | )% | |||||
Margin on miscellaneous sales | $ | 33 | $ | 29 | $ | 4 | |||||
Operating expenses | $ | 196 | $ | 178 | $ | 18 | |||||
Depreciation and amortization expense | $ | 28 | $ | 26 | $ | 2 | |||||
Ethanol (c): | |||||||||||
Operating income | $ | 215 | $ | 139 | $ | 76 | |||||
Production (thousand gallons per day) | 3,317 | 2,943 | 374 | ||||||||
Gross margin per gallon of production (f) | $ | 0.60 | $ | 0.54 | $ | 0.06 | |||||
Operating costs per gallon of production: | |||||||||||
Operating expenses | 0.33 | 0.33 | — | ||||||||
Depreciation and amortization expense | 0.03 | 0.04 | (0.01 | ) | |||||||
Total operating costs per gallon of production | 0.36 | 0.37 | (0.01 | ) | |||||||
Operating income per gallon of production | $ | 0.24 | $ | 0.17 | $ | 0.07 |
(a) | The information presented for the nine months ended September 30, 2011 includes the results of operations of our Pembroke Refinery, including the related marketing and logistics business, from the date of its acquisition, August 1, 2011, through September 30, 2011. In addition, the refining segment and North Atlantic region operating highlights for the nine months ended September 30, 2011 include the Pembroke Refinery. |
(b) | In December 2010, we sold our Paulsboro Refinery to PBF Holding Company LLC and in June 2010, we sold our shutdown Delaware City Refinery assets and associated terminal and pipeline assets to PBF Energy Partners LP. The results of operations of these refineries have been presented as discontinued operations for the nine months ended September 30, 2010. In addition, the refining segment and North Atlantic region operating highlights exclude these refineries for nine months ended September 30, 2010. |
(c) | We acquired three ethanol plants in the first quarter of 2010. The information presented includes the results of operations of those plants commencing on their respective acquisition dates. Ethanol production volumes are based on total production during each period divided by actual calendar days per period. |
(d) | Credit card transaction processing fees incurred by our retail segment of $68 million for the nine months ended September 30, 2010 have been reclassified from retail operating expenses to cost of sales. The Retail–U.S. and Retail–Canada operating highlights for the nine months ended September 30, 2010 have been restated to reflect this reclassification. |
(e) | Cost of sales for the nine months ended September 30, 2011 includes a loss of $542 million ($352 million after taxes) on commodity derivative contracts related to forward sales of refined products. These contracts were closed and realized during the first quarter of 2011. The $542 million loss is reflected in refining segment operating income, resulting in an $0.85 reduction in refining throughput margin per barrel for the nine months ended September 30, 2011, and is allocated to refining operating income by region, excluding the North Atlantic, based on relative throughput volumes for each region as follows: Gulf Coast- $372 million, or $0.96 per barrel; Mid-Continent- $122 million, or $1.11 per barrel; and West Coast- $48 million, or $0.69 per barrel. |
(f) | Throughput margin per barrel represents operating revenues less cost of sales of our refining segment divided by throughput volumes. Gross margin per gallon of production represents operating revenues less cost of sales of our ethanol segment divided by production volumes. |
(g) | Other products primarily include petrochemicals, gas oils, No. 6 fuel oil, petroleum coke, and asphalt. |
(h) | The regions reflected herein contain the following refineries: the Gulf Coast region includes the Corpus Christi East, Corpus Christi West, Texas City, Houston, Three Rivers, St. Charles, Aruba, and Port Arthur Refineries; the Mid-Continent region includes the McKee, Ardmore, and Memphis Refineries; the North Atlantic region includes the Pembroke and Quebec City Refineries; and the West Coast region includes the Benicia and Wilmington Refineries. |
(i) | Average market reference prices for LLS crude oil, along with price differentials between the price of LLS crude oil and other types of crude oil, have been included in the table of Average Market Reference Prices and Differentials. The table also includes price differentials by region between the prices of certain products and the benchmark crude oil that provides the best indicator of product margins for each region. Prior to the first quarter of 2011, feedstock and product differentials presented herein were based on the price of WTI crude oil. However, the price of WTI crude oil no longer provides a reasonable benchmark price of crude oil for all regions. Beginning in late 2010, WTI light-sweet crude oil began to price at a discount to waterborne light-sweet crude oils, such as LLS and Brent, because of increased WTI supplies resulting from greater domestic production and increased deliveries of crude oil from Canada into the Mid-Continent region. Therefore, the use of the price of WTI crude oil as a benchmark price for regions that do not process WTI crude oil is no longer reasonable. |
• | The WTI-based benchmark reference margin for Mid-Continent conventional 87 gasoline was $24.79 per barrel for the first nine months of 2011, compared to $8.77 per barrel for the first nine months of 2010, representing a favorable increase of $16.02 per barrel. In addition, the WTI-based benchmark reference margin for Mid-Continent ultra-low sulfur diesel (a type of distillate) was $30.75 per barrel for the first nine months of 2011, compared to $11.06 per barrel for the first nine months of 2010, representing a favorable increase of $19.69 per barrel. We estimate that these increases in gasoline and distillate margins per barrel had a positive impact to our refining margin of approximately $900 million and $800 million, respectively, nine months versus nine months. The increases in the gasoline and distillate benchmark reference margins in the Mid-Continent region are primarily due to the substantial discount in the price of WTI crude oil, the primary type of crude oil processed by our Mid-Continent refineries, versus LLS-type crude oils. Historically, the price of WTI crude oil has tracked LLS crude oil, but due to the significant development of crude oil reserves within the Mid-Continent region and increased deliveries of crude oil from Canada into the Mid-Continent region, the increased supply of WTI crude oil has resulted in WTI crude oil currently being priced at a significant discount to LLS crude oil. |
• | The LLS-based benchmark reference margin for Gulf Coast conventional 87 gasoline was $7.43 per barrel for the first nine months of 2011, compared to $6.26 per barrel for the first nine months of 2010, representing a favorable increase of $1.17 per barrel. In addition, the LLS-based benchmark reference margin for Gulf Coast ultra-low sulfur diesel was $13.09 per barrel for the first nine months of 2011, compared to $8.61 per barrel for the first nine months of 2010, representing a favorable increase of $4.48 per barrel. We estimate that these increases in gasoline and distillate margins per barrel had a positive impact to our refining margin of approximately $200 million and $600 million, respectively, nine months versus nine months. The increases in the gasoline and distillate benchmark reference margins are supported by increased exports of gasoline and distillate as well as an increase in demand for distillates. |
• | In addition, our system benefited from the increase in the discount of the price of heavy sour crude oils as compared to the price of sweet crude oils. For example, Maya crude oil, which is a type of heavy sour crude oil, sold at a discount of $14.58 per barrel to LLS crude oil, which is a type of sweet crude oil, during the first nine months of 2011. This compares to a discount of $10.88 per barrel during the first nine months of 2010, representing a favorable increase of $3.70 per barrel. We estimate that the increase in the discounts for all types of sour crude oil that we process had a positive impact to our refining margin of approximately $450 million, nine months versus nine months. |
• | fund $2.1 billion of capital expenditures and deferred turnaround and catalyst costs; |
• | purchase the Pembroke Refinery and the related marketing and logistics business for $1.7 billion, |
• | make scheduled long-term note repayments of $418 million and acquire the Gulf Opportunity Zone Revenue Bonds Series 2010 (GO Zone Bonds) for $300 million; |
• | purchase our common stock for $270 million; and |
• | pay common stock dividends of $85 million. |
• | fund $1.6 billion of capital expenditures and deferred turnaround and catalyst costs; |
• | redeem our 7.50% senior notes for $294 million and our 6.75% senior notes for $190 million; |
• | make scheduled long-term note repayments of $33 million; |
• | make repayments under our accounts receivable sales facility of $100 million; |
• | purchase additional ethanol plants for $260 million; |
• | pay common stock dividends of $85 million; and |
• | increase available cash on hand by $1.5 billion. |
Cash provided by (used in) operating activities: | |||
Paulsboro Refinery | $ | 42 | |
Delaware City Refinery | (76 | ) | |
Cash used in investing activities: | |||
Paulsboro Refinery | (32 | ) | |
Delaware City Refinery | — |
• | in May 2011, we made a scheduled debt repayment of $200 million related to our 6.125% senior notes; |
• | in April 2011, we made scheduled debt repayments of $8 million related to our Series A 5.45%, Series B 5.40%, and Series C 5.40% industrial revenue bonds; |
• | in February 2011, we made a scheduled debt repayment of $210 million related to our 6.75% senior notes; and |
• | in February 2011, we paid $300 million to acquire the GO Zone Bonds, which were subject to mandatory tender. |
Rating Agency | Rating | |
Standard & Poor’s Ratings Services | BBB (stable outlook) | |
Moody’s Investors Service | Baa2 (stable outlook) | |
Fitch Ratings | BBB (stable outlook) |
Borrowing Capacity | Expiration | Outstanding Letters of Credit | ||||
Letter of credit facility | $200 | June 2012 | $— | |||
Letter of credit facility | $300 | June 2012 | $300 | |||
Revolving credit facility | $2,400 | November 2012 | $74 | |||
Canadian revolving credit facility | C$115 | December 2012 | C$20 |
Item 3. | Quantitative and Qualitative Disclosures About Market Risk |
• | inventories and firm commitments to purchase inventories generally for amounts by which our current year LIFO inventory levels differ from our previous year-end LIFO inventory levels and |
• | forecasted feedstock and refined product purchases, refined product sales, and natural gas purchases, and corn purchases to lock in the price of those forecasted transactions at existing market prices that we deem favorable. |
Derivative Instruments Held For | |||||||
Non-Trading Purposes | Trading Purposes | ||||||
September 30, 2011: | |||||||
Gain (loss) in fair value due to: | |||||||
10% increase in underlying commodity prices | $ | (56 | ) | $ | — | ||
10% decrease in underlying commodity prices | 56 | — | |||||
December 31, 2010: | |||||||
Gain (loss) in fair value due to: | |||||||
10% increase in underlying commodity prices | (199 | ) | — | ||||
10% decrease in underlying commodity prices | 189 | (1 | ) |
September 30, 2011 | |||||||||||||||||||||||||||||||
Expected Maturity Dates | |||||||||||||||||||||||||||||||
2011 | 2012 | 2013 | 2014 | 2015 | There- after | Total | Fair Value | ||||||||||||||||||||||||
Debt (excluding capital lease obligations): | |||||||||||||||||||||||||||||||
Fixed rate | $ | — | $ | 759 | $ | 489 | $ | 209 | $ | 484 | $ | 5,605 | $ | 7,546 | $ | 9,065 | |||||||||||||||
Average interest rate | — | % | 6.9 | % | 5.5 | % | 4.8 | % | 5.2 | % | 7.2 | % | 6.9 | % | |||||||||||||||||
Floating rate | $ | — | $ | 104 | $ | — | $ | — | $ | — | $ | — | $ | 104 | $ | 104 | |||||||||||||||
Average interest rate | — | % | 0.7 | % | — | % | — | % | — | % | — | % | 0.7 | % | |||||||||||||||||
December 31, 2010 | |||||||||||||||||||||||||||||||
Expected Maturity Dates | |||||||||||||||||||||||||||||||
2011 | 2012 | 2013 | 2014 | 2015 | There- after | Total | Fair Value | ||||||||||||||||||||||||
Debt (excluding capital lease obligations): | |||||||||||||||||||||||||||||||
Fixed rate | $ | 418 | $ | 759 | $ | 489 | $ | 209 | $ | 484 | $ | 5,605 | $ | 7,964 | $ | 9,092 | |||||||||||||||
Average interest rate | 6.4 | % | 6.9 | % | 5.5 | % | 4.8 | % | 5.2 | % | 7.2 | % | 6.9 | % | |||||||||||||||||
Floating rate | $ | 400 | $ | — | $ | — | $ | — | $ | — | $ | — | $ | 400 | $ | 400 | |||||||||||||||
Average interest rate | 0.5 | % | — | % | — | % | — | % | — | % | — | % | 0.5 | % |
(a) | Evaluation of disclosure controls and procedures. |
(b) | Changes in internal control over financial reporting. |
Item 1. | Legal Proceedings |
Item 2. | Unregistered Sales of Equity Securities and Use of Proceeds |
(a) | Unregistered Sales of Equity Securities. Not applicable. |
(b) | Use of Proceeds. Not applicable. |
(c) | Issuer Purchases of Equity Securities. The following table discloses purchases of shares of our common stock made by us or on our behalf for the periods shown below. |
Period | Total Number of Shares Purchased | Average Price Paid per Share | Total Number of Shares Not Purchased as Part of Publicly Announced Plans or Programs (a) | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs | Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (b) | |||||
July 2011 | 9,560 | $ | 26.35 | 9,560 | — | $3.46 billion | ||||
August 2011 | 10,597,275 | $ | 19.90 | 10,597,275 | — | $3.46 billion | ||||
September 2011 | 2,936,270 | $ | 19.27 | 2,936,270 | — | $3.46 billion | ||||
Total | 13,543,105 | $ | 19.77 | 13,543,105 | — | $3.46 billion |
(a) | The shares reported in this column represent purchases settled in the third quarter of 2011 relating to (a) our purchases of shares in open-market transactions to meet our obligations under employee stock compensation plans, and (b) our purchases of shares from our employees and non-employee directors in connection with the exercise of stock options, the vesting of restricted stock, and other stock compensation transactions in accordance with the terms of our incentive compensation plans. |
(b) | On April 26, 2007, we publicly announced an increase in our common stock purchase program from $2 billion to $6 billion, as authorized by our board of directors on April 25, 2007. The $6 billion common stock purchase program has no expiration date. On February 28, 2008, we announced that our board of directors approved a $3 billion common stock purchase program. This program is in addition to the $6 billion program. This $3 billion program has no expiration date. |
Exhibit No. | Description |
12.01 | Statements of Computations of Ratios of Earnings to Fixed Charges and Ratios of Earnings to Fixed Charges and Preferred Stock Dividends. |
31.01 | Rule 13a-14(a) Certification (under Section 302 of the Sarbanes-Oxley Act of 2002) of principal executive officer. |
31.02 | Rule 13a-14(a) Certification (under Section 302 of the Sarbanes-Oxley Act of 2002) of principal financial officer. |
32.01 | Section 1350 Certifications (as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002). |
101 | Interactive Data Files |
VALERO ENERGY CORPORATION (Registrant) | |||
By: | /s/ Michael S. Ciskowski | ||
Michael S. Ciskowski | |||
Executive Vice President and | |||
Chief Financial Officer | |||
(Duly Authorized Officer and Principal | |||
Financial and Accounting Officer) |
Nine Months Ended September 30, 2011 | |||||||||||||||||||||||||||||
Year Ended December 31, | |||||||||||||||||||||||||||||
2010 | 2009 | 2008 | 2007 | 2006 | |||||||||||||||||||||||||
Ratio of Earnings to Fixed Charges: | |||||||||||||||||||||||||||||
Earnings: | |||||||||||||||||||||||||||||
Income (loss) from continuing operations before income tax expense (benefit), excluding income from equity investees | $ | 3,229 | $ | 1,481 | $ | (334 | ) | $ | 268 | $ | 6,202 | $ | 7,206 | ||||||||||||||||
Add: | |||||||||||||||||||||||||||||
Fixed charges | 548 | 743 | 701 | 626 | 631 | 542 | |||||||||||||||||||||||
Amortization of capitalized interest | 17 | 20 | 18 | 17 | 13 | 8 | |||||||||||||||||||||||
Distributions from equity investees | — | 10 | — | — | — | 47 | |||||||||||||||||||||||
Less: | |||||||||||||||||||||||||||||
Interest capitalized | (101 | ) | (90 | ) | (105 | ) | (92 | ) | (101 | ) | (145 | ) | |||||||||||||||||
Total earnings | $ | 3,693 | $ | 2,164 | $ | 280 | $ | 819 | $ | 6,745 | $ | 7,658 | |||||||||||||||||
Fixed charges: | |||||||||||||||||||||||||||||
Interest expense, net | $ | 312 | $ | 484 | $ | 416 | $ | 360 | $ | 357 | $ | 232 | |||||||||||||||||
Interest capitalized | 101 | 90 | 105 | 92 | 101 | 145 | |||||||||||||||||||||||
Rental expense interest factor (a) | 135 | 169 | 180 | 174 | 173 | 165 | |||||||||||||||||||||||
Total fixed charges | $ | 548 | $ | 743 | $ | 701 | $ | 626 | $ | 631 | $ | 542 | |||||||||||||||||
Ratio of earnings to fixed charges | 6.7 | x | 2.9 | x | (b) | 1.3 | x | 10.7 | x | 14.1 | x | ||||||||||||||||||
Ratio of Earnings to Fixed Charges and Preferred Stock Dividends: | |||||||||||||||||||||||||||||
Total earnings | $ | 3,693 | $ | 2,164 | $ | 280 | $ | 819 | $ | 6,745 | $ | 7,658 | |||||||||||||||||
Total fixed charges | $ | 548 | $ | 743 | $ | 701 | $ | 626 | $ | 631 | $ | 542 | |||||||||||||||||
Preferred stock dividends | — | — | — | — | — | 3 | |||||||||||||||||||||||
Total fixed charges and preferred stock dividends | $ | 548 | $ | 743 | $ | 701 | $ | 626 | $ | 631 | $ | 545 | |||||||||||||||||
Ratio of earnings to fixed charges and preferred stock dividends | 6.7 | x | 2.9 | x | (b) | 1.3 | x | 10.7 | x | 14.1 | x |
(a) | The interest portion of rental expense represents one-third of rents, which is deemed representative of the interest portion of rental expense. |
(b) | For the year ended December 31, 2009, earnings were insufficient to cover fixed charges by $421 million. The deficiency included the effect of a $222 million pre-tax impairment loss resulting from the permanent cancellation of certain capital projects classified as “construction in progress” as a result of the unfavorable impact of the economic slowdown on refining industry fundamentals during the year. The deficiency was also partially attributable to a $120 million loss contingency accrual related to our dispute of a turnover tax on export sales in Aruba. |
/s/ William R. Klesse | ||
William R. Klesse Chief Executive Officer and President |
/s/ Michael S. Ciskowski | ||
Michael S. Ciskowski Executive Vice President and Chief Financial Officer |
1. | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and |
2. | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
/s/ William R. Klesse | |
William R. Klesse | |
Chief Executive Officer and President | |
November 9, 2011 |
1. | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and |
2. | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. |
/s/ Michael S. Ciskowski | |
Michael S. Ciskowski | |
Executive Vice President and Chief Financial Officer | |
November 9, 2011 |
Price Risk Management Activities (Details) (USD $) In Millions, unless otherwise specified | 3 Months Ended | 9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2011 | Sep. 30, 2010 | Sep. 30, 2011 | Sep. 30, 2010 | Sep. 30, 2011
Purchases (Long) [Member]
Cash Flow Hedging [Member]
Swap [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Fair Value Hedging [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Fair Value Hedging [Member]
Forward Contracts [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Swap [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Swap [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Swap [Member]
Purchases (Long) [Member]
Maturity Year Three [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Year Three [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Year Three [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Options Held [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Options Held [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Options Held [Member]
Purchases (Long) [Member]
Maturity Year Three [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Natural Gas In Btus [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Current Year [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Natural Gas In Btus [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Purchases (Long) [Member]
Maturity Year Two [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Fair Value Hedging [Member]
Future [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Cash Flow Hedging [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Year Three [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Sales (Short) [Member]
Maturity Year Three [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Future [Member]
Sales (Short) [Member]
Maturity Year Three [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Options Held [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Options Held [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Options Held [Member]
Sales (Short) [Member]
Maturity Year Three [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Forward Contracts [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Forward Contracts [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Economic Hedging [Member]
Forward Contracts [Member]
Sales (Short) [Member]
Maturity Year Three [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Swap [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Natural Gas In Btus [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Natural Gas In Btus [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Future [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Grain In Bushels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Options Held [Member]
Sales (Short) [Member]
Maturity Current Year [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Trading Derivatives [Member]
Options Held [Member]
Sales (Short) [Member]
Maturity Year Two [Member]
Crude Oil In Barrels [Member] | Sep. 30, 2011
Forward Contracts [Member] | Sep. 30, 2011
Refining Industry [Member] | Dec. 31, 2010
Refining Industry [Member] | Sep. 30, 2011
Financial Services Industry [Member] | Dec. 31, 2010
Financial Services Industry [Member] | |
Volume of outstanding contracts | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Nonmonetary notional amount of price risk derivatives | 5,241,000 | 3,025,000 | 13,428,000 | 34,708,000 | 65,040,000 | 0 | 200,076,000 | 22,325,000 | 40,388,000 | 8,405,000 | 0 | 0 | 606,000 | 10,000 | 0 | 6,196,000 | 0 | 3,240,000 | 1,050,000 | 66,365,000 | 5,050,000 | 3,850,000 | 15,868,000 | 0 | 60,000 | 16,453,000 | 5,241,000 | 33,890,000 | 65,040,000 | 0 | 192,292,000 | 41,300,000 | 41,219,000 | 23,980,000 | 0 | 260,000 | 600,000 | 0 | 0 | 12,166,000 | 10,991,000 | 265,000 | 6,196,000 | 0 | 3,240,000 | 1,050,000 | 66,389,000 | 5,050,000 | 2,350,000 | 15,831,000 | 0 | 1,060,000 | 75,000 | 0 | |||||||||
Price Risk Management Activities (Textual) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Notional amount of foreign currency derivative purchase contracts | $ 475 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Foreign currency commitments maturity date | October 28, 2011 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net receivables related to derivative instruments from counterparties | 1 | 4 | 0 | 21 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Gain (loss) from components excluded from assessment of fair value hedge effectiveness, net | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Gain (loss) from hedged firm commitment not qualifying as fair value hedge, net | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Gain (loss) from components excluded from assessment of cash flow hedge effectiveness, net | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Accumulated other comprehensive income, cumulative gains on cash flow hedges | 13 | 13 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Gain (loss) from cash flow hedges to be reclassified within 12 months | 10 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Amount reclassifed from accumulated OCI into income on discontinuance of cash flow hedges | $ 0 | $ 0 | $ 0 | $ 0 |
Consolidated Balance Sheets (Parenthetical) (USD $) | Sep. 30, 2011 | Dec. 31, 2010 |
---|---|---|
Valero Energy Corporation stockholders' equity: | ||
Common stock, par value | $ 0.01 | $ 0.01 |
Common stock, shares authorized | 1,200,000,000 | 1,200,000,000 |
Common stock, shares issued | 673,501,593 | 673,501,593 |
Treasury stock, common shares | 114,855,199 | 105,113,545 |
Price Risk Management Activities (Policies) | 9 Months Ended |
---|---|
Sep. 30, 2011 | |
Price Risk Management Activities, Policies [Abstract] | |
Derivatives | We are exposed to market risks related to the volatility in the price of commodities, interest rates and foreign currency exchange rates, and we enter into derivative instruments to manage those risks. We also enter into derivative instruments to manage the price risk on other contractual derivatives into which we have entered. The only types of derivative instruments we enter into are those related to the various commodities we purchase or produce, interest rate swaps, and foreign currency exchange and purchase contracts, as described below. All derivative instruments are recorded as either assets or liabilities measured at their fair values (See Note 12). When we enter into a derivative instrument, it is designated as a fair value hedge, a cash flow hedge, an economic hedge, or a trading derivative. The gain or loss on a derivative instrument designated and qualifying as a fair value hedge, as well as the offsetting loss or gain on the hedged item attributable to the hedged risk, are recognized currently in income in the same period. The effective portion of the gain or loss on a derivative instrument designated and qualifying as a cash flow hedge is initially reported as a component of other comprehensive income and is then recorded in income in the period or periods during which the hedged forecasted transaction affects income. The ineffective portion of the gain or loss on the cash flow derivative instrument, if any, is recognized in income as incurred. For our economic hedges (derivative instruments not designated as fair value or cash flow hedges) and for derivative instruments entered into by us for trading purposes, the derivative instrument is recorded at fair value and changes in the fair value of the derivative instrument are recognized currently in income. The cash flow effects of all of our derivative instruments are reflected in operating activities in the consolidated statements of cash flows for all periods presented. |
Derivative instruments collateral requirements | We do not require any collateral or other security to support derivative instruments into which we enter. |
Document and Entity Information | 9 Months Ended |
---|---|
Sep. 30, 2011 | |
Document and Entity Information [Abstract] | |
Entity Registrant Name | VALERO ENERGY CORP/TX |
Entity Central Index Key | 0001035002 |
Document Type | 10-Q |
Document Period End Date | Sep. 30, 2011 |
Amendment Flag | false |
Document Fiscal Year Focus | 2011 |
Document Fiscal Period Focus | Q3 |
Current Fiscal Year End Date | --12-31 |
Entity Well-known Seasoned Issuer | Yes |
Entity Voluntary Filers | No |
Entity Current Reporting Status | Yes |
Entity Filer Category | Large Accelerated Filer |
Entity Common Stock, Shares Outstanding | 559,726,988 |
Debt (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Sep. 30, 2011 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Outstanding letters of credit under committed lines of credit | We had outstanding letters of credit under our committed lines of credit as follows (in millions):
|
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Debt | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2011 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
DEBT |
Non-Bank Debt During the nine months ended September 30, 2011, the following activity occurred related to our non-bank debt:
During the nine months ended September 30, 2010, the following activity occurred related to our non-bank debt:
Bank Debt and Credit Facilities We have a $2.4 billion revolving credit facility (the Revolver) that has a maturity date of November 2012. The Revolver has certain restrictive covenants, including a maximum debt-to-capitalization ratio of 60 percent. As of September 30, 2011 and December 31, 2010, our debt-to-capitalization ratio, calculated in accordance with the terms of the Revolver, was 22 percent and 25 percent, respectively. We believe that we will remain in compliance with this covenant. In addition to the Revolver, one of our Canadian subsidiaries has a committed revolving credit facility under which it may borrow and obtain letters of credit up to C$115 million. During the nine months ended September 30, 2011 and 2010, we had no borrowings or repayments under our Revolver or the Canadian revolving credit facility. As of September 30, 2011 and December 31, 2010, we had no borrowings outstanding under the Revolver or the Canadian revolving credit facility. We had outstanding letters of credit under our committed lines of credit as follows (in millions):
As of September 30, 2011 and December 31, 2010, we had $346 million and $176 million, respectively, of letters of credit outstanding under our uncommitted short-term bank credit facilities. In connection with the Pembroke Acquisition, we assumed a €2.8 million short-term demand loan, which bears interest at EURIBOR plus a margin. We expect to repay the loan on or before February 2012. Accounts Receivable Sales Facility We have an accounts receivable sales facility with a group of third-party entities and financial institutions to sell on a revolving basis up to $1 billion of eligible trade receivables. We amended our agreement in June 2011 to extend the maturity date to June 2012. As of September 30, 2011 and December 31, 2010, the amount of eligible receivables sold was $100 million. There were no sales or repayments of eligible receivables during the nine months ended September 30, 2011. During the nine months ended September 30, 2010, we sold $1.2 billion of eligible receivables and repaid $1.3 billion to the third-party entities and financial institutions. Proceeds from the sale of receivables under this facility are reflected as debt. Capitalized Interest Capitalized interest was $41 million and $25 million for the three months ended September 30, 2011 and 2010, respectively, and $101 million and $67 million for the nine months ended September 30, 2011 and 2010, respectively. |
Equity (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Equity [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of changes in equity | The following is a reconciliation of the beginning and ending balances (in millions) of equity attributable to our stockholders, equity attributable to noncontrolling interests, and total equity for the nine months ended September 30, 2011 and 2010:
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Inventories (Details) (USD $) | Sep. 30, 2011 | Dec. 31, 2010 |
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Schedule of Inventories | ||
Refinery feedstocks | $ 2,502,000,000 | $ 2,225,000,000 |
Refined products and blendstocks | 2,217,000,000 | 2,233,000,000 |
Ethanol feedstocks and products | 130,000,000 | 201,000,000 |
Convenience store merchandise | 102,000,000 | 101,000,000 |
Materials and supplies | 213,000,000 | 187,000,000 |
Inventories | 5,164,000,000 | 4,947,000,000 |
Inventories (Textual) | ||
Excess of market value over carrying amount of LIFO inventories | $ 7,100,000,000 | $ 6,100,000,000 |
Inventories (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Inventories [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of inventories | Inventories consisted of the following (in millions):
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Segment Information | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Segment Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
SEGMENT INFORMATION |
The following table reflects segment activity related to continuing operations (in millions):
Total assets by reportable segment were as follows (in millions):
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Basis of Presentation and Summary of Significant Accounting Policies | 9 Months Ended | ||||
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Sep. 30, 2011 | |||||
Basis of Presentation and Summary of Significant Accounting Policies [Abstract] | |||||
BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES |
Basis of Presentation General As used in this report, the terms “Valero,” “we,” “us,” or “our” may refer to Valero Energy Corporation, one or more of its consolidated subsidiaries, or all of them taken as a whole. These unaudited consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities Exchange Act of 1934. Accordingly, they do not include all of the information and notes required by GAAP for complete consolidated financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation have been included. All such adjustments are of a normal recurring nature unless disclosed otherwise. Financial information for the three and nine months ended September 30, 2011 and 2010 included in these Condensed Notes to Consolidated Financial Statements is derived from our unaudited consolidated financial statements. Operating results for the three and nine months ended September 30, 2011 are not necessarily indicative of the results that may be expected for the year ending December 31, 2011. The consolidated balance sheet as of December 31, 2010 has been derived from our audited financial statements as of that date. For further information, refer to our consolidated financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2010. We have evaluated subsequent events that occurred after September 30, 2011 through the filing of this Form 10-Q. Any material subsequent events that occurred during this time have been properly recognized or disclosed in these financial statements. Noncontrolling Interests In connection with the acquisition of the Pembroke Refinery (see further discussion in Note 2), we acquired an 85 percent interest in Mainline Pipelines Limited (MLP). MLP owns a pipeline that distributes refined products from the Pembroke Refinery to terminals in the United Kingdom. On January 21, 2011, we entered into a joint venture agreement with Darling Green Energy LLC, a subsidiary of Darling International, Inc., to form Diamond Green Diesel Holdings LLC (DGD Holdings). DGD Holdings, through its wholly owned subsidiary, Diamond Green Diesel LLC (DGD), will construct and operate a biomass-based diesel plant having a design feed capacity of 10,000 barrels per day that will process animal fats, used cooking oils, and other vegetable oils into renewable green diesel. The plant will be located next to our St. Charles Refinery. The aggregate cost of this facility is estimated to be approximately $368 million and the construction is expected to be completed in late 2012. The joint venture agreement requires that contributions be made to DGD Holdings based on the percentage of units held by each member, which is currently on a 50/50 basis. In addition, on May 31, 2011, we agreed to lend DGD up to $221 million in order to finance 60 percent of the construction costs of the plant. Because of our controlling financial interests in MLP and DGD Holdings, we have included the financial statements of MLP and DGD Holdings in these consolidated financial statements and have separately disclosed the related noncontrolling interests. Significant Accounting Policies Reclassifications As discussed in Note 2, we sold our Paulsboro Refinery in December 2010. As a result, the results of operations of the Paulsboro Refinery have been reclassified to discontinued operations for the three and nine months ended September 30, 2010. In addition, credit card fees previously recognized in 2010 in retail operating expenses have been reclassified to cost of sales as such fees are directly and jointly related to the sale transaction. This reclassification resulted in an increase in cost of sales and a decrease in retail operating expenses of $23 million and $68 million for the three and nine months ended September 30, 2010, respectively. Use of Estimates The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. On an ongoing basis, we review our estimates based on currently available information. Changes in facts and circumstances may result in revised estimates. New Accounting Pronouncements In June 2011, the provisions of Accounting Standards Codification (ASC) Topic 220, “Comprehensive Income,” were amended to allow an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement or in two separate but consecutive statements. In both choices, the entity is required to present reclassification adjustments on the face of the financial statements for items that are reclassified from other comprehensive income to net income in the statement where those components are presented. These provisions are effective for the first interim or annual period beginning after December 15, 2011, and are to be applied retrospectively, with early adoption permitted. The adoption of this guidance effective January 1, 2012 will not affect our financial position or results of operations because these requirements only affect disclosures. In May 2011, the provisions of ASC Topic 820, “Fair Value Measurement,” were amended to clarify the application of existing fair value measurement requirements and to change certain fair value measurement and disclosure requirements. Amendments that change measurement and disclosure requirements relate to (i) fair value measurement of financial instruments that are managed within a portfolio, (ii) application of premiums and discounts in a fair value measurement, and (iii) additional disclosures about fair value measurements categorized within Level 3 of the fair value hierarchy. These provisions are effective for the first interim or annual period beginning after December 15, 2011. The adoption of this guidance effective January 1, 2012 will not affect our financial position or results of operations, but may result in additional disclosures. In January 2011, the provisions of ASC Topic 310, “Receivables,” were amended to delay temporarily the effective date of disclosures relating to troubled debt restructurings, which were previously amended in July 2010, in order to allow the Financial Accounting Standards Board time to complete its deliberations on what constitutes a troubled debt restructuring. In April 2011, the provisions of ASC Topic 310 were amended to clarify the guidance on a creditor’s evaluations of whether it has granted a concession to the debtor and whether the debtor is experiencing financial difficulties. These provisions are effective for the first interim or annual period beginning on or after June 15, 2011. The new guidance should be applied retrospectively to restructurings occurring on or after the beginning of the annual period of adoption, with early adoption permitted. The adoption of this guidance effective July 1, 2011 did not affect our financial position or results of operations. |
Acquisitions (Details) (USD $) In Millions, except Per Share data, unless otherwise specified | 3 Months Ended | 9 Months Ended | 0 Months Ended | 2 Months Ended | 3 Months Ended | 9 Months Ended | 1 Months Ended | 1 Months Ended | 1 Months Ended | |||||||||
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Sep. 30, 2011 | Sep. 30, 2010 | Sep. 30, 2011 | Sep. 30, 2010 | Dec. 31, 2011
Purchase Price Allocation Adjustments [Member]
Acquisition [Member]
Meraux Acquisition [Member] | Oct. 02, 2011
Acquisition [Member]
Meraux Acquisition [Member] | Aug. 01, 2011
Pembroke Acquisition [Member] | Sep. 30, 2011
Pembroke Acquisition [Member] | Sep. 30, 2011
Pembroke Acquisition [Member] | Sep. 30, 2011
Pembroke Acquisition [Member] | Mar. 31, 2010
ASA And Renew Acquisitions [Member] | Jan. 31, 2010
ASA Acquisition [Member] | Dec. 31, 2009
ASA Acquisition [Member] | Jan. 13, 2010
ASA Acquisition [Member] | Feb. 28, 2010
Renew Acquisition [Member] | Dec. 31, 2009
Renew Acquisition [Member] | Feb. 04, 2010
Renew Acquisition [Member] | Jun. 30, 2011
Terminals [Member] | |
Fair value of acquisition | ||||||||||||||||||
Current assets, net of cash acquired | $ 2,217 | $ 2,217 | $ 2,217 | |||||||||||||||
Property, plant and equipment | 777 | 777 | 777 | |||||||||||||||
Deferred charges and other assets | 17 | 17 | 17 | |||||||||||||||
Intangible assets | 50 | 50 | 50 | |||||||||||||||
Current liabilities, less current portion of debt and capital lease obligations | (1,294) | (1,294) | (1,294) | |||||||||||||||
Debt and capital leases assumed, including current portion | (12) | (12) | (12) | |||||||||||||||
Other long-term liabilities | (77) | (77) | (77) | |||||||||||||||
Noncontrolling interest | (3) | (3) | (3) | |||||||||||||||
Purchase price, net of cash acquired | 1,675 | 1,675 | 1,675 | |||||||||||||||
Actual amounts from acquisition | ||||||||||||||||||
Operating revenues | 3,028 | |||||||||||||||||
Income from continuing operations | 19 | |||||||||||||||||
Consolidated pro forma financial information | ||||||||||||||||||
Operating revenues | 35,491 | 24,594 | 103,030 | 70,638 | ||||||||||||||
Income from continuing operations | 1,196 | 306 | 1,941 | 767 | ||||||||||||||
Earnings per common share from continuing operations - basic | $ 2.11 | $ 0.54 | $ 3.41 | $ 1.36 | ||||||||||||||
Earnings per common share from continuing operations - assuming dilution | $ 2.10 | $ 0.54 | $ 3.39 | $ 1.35 | ||||||||||||||
Acquisitions (Textual) | ||||||||||||||||||
Effective date of acquisition | October 1, 2011 | August 1, 2011 | ||||||||||||||||
Purchase price of acquired entity | 586 | 1,800 | ||||||||||||||||
Purchase price of working capital | (40) | 261 | 1,100 | |||||||||||||||
Percentage of outstanding shares acquired | 100.00% | |||||||||||||||||
Throughput capacity of petroleum refining (barrels per day) | 135,000 | 270,000 | ||||||||||||||||
Acquired finite-lived intangible assets, weighted-average useful life | 15 | |||||||||||||||||
Acquisition related costs | 18 | 23 | ||||||||||||||||
Number of plants, pipelines, or facilities purchased | 3 | 2 | 1 | 2 | ||||||||||||||
Payments to acquire pipeline and terminal facilties | 37 | 0 | 37 | |||||||||||||||
Payments to acquire businesses, gross | $ 0 | $ 260 | $ 202 | $ 20 | $ 79 | $ 1 |
Equity | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Equity [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
EQUITY |
The following is a reconciliation of the beginning and ending balances (in millions) of equity attributable to our stockholders, equity attributable to noncontrolling interests, and total equity for the nine months ended September 30, 2011 and 2010:
The noncontrolling interests relate to the ownership interests in MLP and DGD Holdings that are owned by parties unrelated to us, as discussed in Note 1. Treasury Stock During the nine months ended September 30, 2011 and 2010, we purchased 13.6 million shares and 1.6 million shares, respectively, of our common stock in connection with the administration of our stock-based compensation plans. During the nine months ended September 30, 2011 and 2010, we issued 3.9 million and 1.6 million shares from treasury, respectively, for our stock-based compensation plans. Common Stock Dividends On October 27, 2011, our board of directors declared a regular quarterly cash dividend of $0.15 per common share payable on December 14, 2011 to holders of record at the close of business on November 16, 2011. |
Fair Value Measurements | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2011 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Measurements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
FAIR VALUE MEASUREMENTS |
General GAAP requires that certain financial instruments, such as derivative instruments, be recognized at their fair values in our consolidated balance sheets. However, other financial instruments, such as debt obligations, are not required to be recognized at their fair values, but GAAP provides an option to elect fair value accounting for these instruments. GAAP requires the disclosure of the fair values of all financial instruments, regardless of whether they are recognized at their fair values or carrying amounts in our consolidated balance sheets. For financial instruments recognized at fair value, GAAP requires the disclosure of their fair values by type of instrument, along with other information, including changes in the fair values of certain financial instruments recognized in income or other comprehensive income, and this information is provided below under “Recurring Fair Value Measurements.” For financial instruments not recognized at fair value, the disclosure of their fair values is provided below under “Other Financial Instruments.” Nonfinancial assets, such as property, plant and equipment, and nonfinancial liabilities are recognized at their carrying amounts in our consolidated balance sheets. GAAP does not permit nonfinancial assets and liabilities to be remeasured at their fair values. However, GAAP requires the remeasurement of such assets and liabilities to their fair values upon the occurrence of certain events, such as the impairment of property, plant and equipment. In addition, if such an event occurs, GAAP requires the disclosure of the fair value of the asset or liability along with other information, including the gain or loss recognized in income in the period the remeasurement occurred. This information is provided below under “Nonrecurring Fair Value Measurements.” GAAP provides a framework for measuring fair value and establishes a three-level fair value hierarchy that prioritizes inputs to valuation techniques based on the degree to which objective prices in external active markets are available to measure fair value. Following is a description of each of the levels of the fair value hierarchy.
The financial instruments and nonfinancial assets and liabilities included in our disclosure of recurring and nonrecurring fair value measurements are categorized according to the fair value hierarchy based on the inputs used to measure their fair values. Recurring Fair Value Measurements The tables below present information (in millions) about our financial instruments recognized at their fair values in our consolidated balance sheets categorized according to the fair value hierarchy of the inputs utilized by us to determine the fair values as of September 30, 2011 and December 31, 2010.
A description of our financial instruments and the valuation methods used to measure those instruments at fair value are as follows:
Cash collateral deposits of $228 million and $403 million with brokers under master netting arrangements are included in the fair value of the commodity derivatives reflected in Level 1 as of September 30, 2011 and December 31, 2010, respectively. Certain of our commodity derivative contracts under master netting arrangements include both asset and liability positions. We have elected to offset the fair value amounts recognized for multiple similar derivative instruments executed with the same counterparty, including any related cash collateral asset or obligation; however, fair value amounts by hierarchy level are presented on a gross basis in the tables above. The following is a reconciliation of the beginning and ending balances (in millions) for fair value measurements developed using significant unobservable inputs (Level 3).
Nonrecurring Fair Value Measurements As of September 30, 2011 and December 31, 2010, there were no assets or liabilities that were measured at fair value on a nonrecurring basis. Other Financial Instruments Financial instruments that we recognize in our consolidated balance sheets at their carrying amounts include cash and temporary cash investments, receivables, payables, debt and capital lease obligations. The fair values of these financial instruments approximate their carrying amounts, except for debt as shown in the table below (in millions):
The fair value of our debt is determined using the market approach based on quoted prices in active markets (Level 1). |
Employee Benefit Plans | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2011 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Employee Benefit Plans [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
EMPLOYEE BENEFIT PLANS |
The components of net periodic benefit cost related to our defined benefit plans were as follows for the three and nine months ended September 30, 2011 and 2010 (in millions):
During the nine months ended September 30, 2011 and 2010, we contributed $207 million and $54 million, respectively, to our pension plans. |
Fair Value Measurements (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Fair Value Measurements [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair value of financial assets and liabilities measured and recorded on recurring basis | The tables below present information (in millions) about our financial instruments recognized at their fair values in our consolidated balance sheets categorized according to the fair value hierarchy of the inputs utilized by us to determine the fair values as of September 30, 2011 and December 31, 2010.
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Reconciliation of the beginning and ending balances for fair value measurements developed using significant unobservable inputs | The following is a reconciliation of the beginning and ending balances (in millions) for fair value measurements developed using significant unobservable inputs (Level 3).
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Estimated fair value of debt including current portion | The fair values of these financial instruments approximate their carrying amounts, except for debt as shown in the table below (in millions):
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Commitments and Contingencies | 9 Months Ended | ||||
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Sep. 30, 2011 | |||||
Commitments and Contingencies [Abstract] | |||||
COMMITMENTS AND CONTINGENCIES |
Environmental Matters The U.S. Environmental Protection Agency (EPA) began regulating greenhouse gases on January 2, 2011, under the Clean Air Act Amendments of 1990 (Clean Air Act). According to statements by the EPA, any new construction or material expansions will require that, among other things, a greenhouse gas permit be issued at either or both the state or federal level in accordance with the Clean Air Act and regulations, and we will be required to undertake a technology review to determine appropriate controls to be implemented with the project in order to reduce greenhouse gas emissions. The determination will be on a case by case basis, and the EPA has provided only general guidance on which controls will be required. Any such controls, however, could result in material increased compliance costs, additional operating restrictions for our business, and an increase in the cost of the products we produce, which could have a material adverse effect on our financial position, results of operations, and liquidity. In addition, certain states and foreign governments have pursued independent regulation of greenhouse gases. For example, the California Global Warming Solutions Act, also known as AB 32, directs the California Air Resources Board (CARB) to develop and issue regulations to reduce greenhouse gas emissions in California to 1990 levels by 2020. The CARB has issued a variety of regulations aimed at reaching this goal, including a Low Carbon Fuel Standard (LCFS) as well as a statewide cap-and-trade program. The LCFS is effective in 2011, with small reductions in the carbon intensity of transportation fuels sold in California. The mandated reductions in carbon intensity are scheduled to increase through 2020, after which another step-change in reductions is anticipated. The LCFS is designed to encourage substitution of traditional petroleum fuels, and, over time, it is anticipated that the LCFS will lead to a greater use of electric cars and alternative fuels, such as E85, as companies seek to generate more credits to offset petroleum fuels. The statewide cap-and-trade program will begin in 2013. Initially, the program will apply only to stationary sources of greenhouse gases (e.g., refinery and power plant greenhouse gas emissions). Greenhouse gas emissions from fuels that we sell in California will be covered by the program beginning in 2015. We anticipate that free allocations of credits will be available in the early years of the program, but we expect that compliance costs will increase significantly beginning in 2015, when fuels are included in the program. Complying with AB 32, including the LCFS and the cap-and-trade program, could result in material increased compliance costs for us, increased capital expenditures, increased operating costs, and additional operating restrictions for our business, resulting in an increase in the cost of, and decreases in the demand for, the products we produce. To the degree we are unable to recover these increased costs, these matters could have a material adverse effect on our financial position, results of operations, and liquidity. On June 30, 2010, the EPA formally disapproved the flexible permits program submitted by the Texas Commission on Environmental Quality (TCEQ) in 1994 for inclusion in its clean-air implementation plan. The EPA determined that Texas’ flexible permit program did not meet several requirements under the federal Clean Air Act. Our Port Arthur, Texas City, Three Rivers, McKee, and Corpus Christi East and West Refineries formerly operated under flexible permits administered by the TCEQ. In the fourth quarter of 2010, we completed the conversion of our flexible permits into federally enforceable conventional state NSR permits (“de-flexed permits”). We are now in the process of incorporating these de-flexed permits into our Title V permits. Continued discussions with the TCEQ and the EPA regarding this matter are likely. Meanwhile, the EPA has formally disapproved other TCEQ permitting programs that historically have streamlined the environmental permitting process in Texas. For example, the EPA has disapproved the TCEQ pollution control standard permit, thus requiring conventional permitting for future pollution control equipment. Litigation is pending from industry groups and others against the EPA for each of these actions. The EPA has also objected to numerous Title V permits in Texas and other states, including permits at our Port Arthur, Corpus Christi East, and McKee Refineries. Environmental activist groups have filed a notice of intent to sue the EPA, seeking to require the EPA to assume control of these permits from the TCEQ. All of these developments have created substantial uncertainty regarding existing and future permitting. Because of this uncertainty, we are unable to determine the costs or effects of the EPA’s actions on our permitting activity. But the EPA’s disruption of the Texas permitting system could result in material increased compliance costs for us, increased capital expenditures, increased operating costs, and additional operating restrictions for our business, resulting in an increase in the cost of, and decreases in the demand for, the products we produce, which could have a material adverse effect on our financial position, results of operations, and liquidity. Tax Matters We are subject to extensive tax liabilities, including federal, state, and foreign income taxes and transactional taxes such as excise, sales/use, payroll, franchise, withholding, and ad valorem taxes. New tax laws and regulations and changes in existing tax laws and regulations are continuously being enacted or proposed that could result in increased expenditures for tax liabilities in the future. Many of these liabilities are subject to periodic audits by the respective taxing authority. Subsequent changes to our tax liabilities as a result of these audits may subject us to interest and penalties. Litigation Matters We are party to claims and legal proceedings arising in the ordinary course of business. We have not recorded a loss contingency liability with respect to some of these matters because we have determined that it is remote that a loss has been incurred. For other matters, we have recorded a loss contingency liability where we have determined that it is probable that a loss has been incurred and that the loss is reasonably estimable. These loss contingency liabilities are not material to our financial position. We re-evaluate and update our loss contingency liabilities as matters progress over time, and we believe that any changes to the recorded liabilities will not be material to our financial position or results of operations. |
Acquisitions and Dispositions | 9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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ACQUISITIONS AND DISPOSITIONS [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
ACQUISITIONS AND DISPOSITIONS |
Meraux Acquisition On October 1, 2011, we acquired the Meraux Refinery and related logistics assets for an initial payment of $586 million, including inventories of $261 million, from Murphy Oil Corporation, with the total purchase price funded from available cash. We expect to receive a favorable adjustment related to inventories in the fourth quarter of 2011 that will reduce the purchase price by approximately $40 million. The Meraux Refinery has a total throughput capacity of 135,000 barrels per day and is located in Meraux, Louisiana. This acquisition is referred to as the Meraux Acquisition. The Meraux Acquisition is consistent with our general business strategy and complements our existing refining and marketing network. A determination of the acquisition-date fair values of the assets acquired and the liabilities assumed in the Meraux Acquisition is pending the completion of an independent appraisal and other evaluations. Disclosure of pro forma information for the Meraux Acquisition for the three and nine months ended September 30, 2011 and 2010 is impracticable as historical financial information is not readily available at this time. Pembroke Acquisition On August 1, 2011, we acquired 100 percent of the outstanding shares of Chevron Limited from a subsidiary of Chevron Corporation (Chevron), and we subsequently changed the name of Chevron Limited to Valero Energy Ltd. Valero Energy Ltd owns and operates the Pembroke Refinery, which has a total throughput capacity of approximately 270,000 barrels per day and is located in Wales, United Kingdom. Valero Energy Ltd also owns, directly and through various subsidiaries, an extensive network of marketing and logistics assets throughout the United Kingdom and Ireland. On the acquisition date, we initially paid $1.8 billion from available cash, of which $1.1 billion was for working capital. Subsequent to the acquisition date, the amounts paid have been favorably adjusted for working capital true-up adjustments (primarily inventory), with an adjusted purchase price of $1.675 billion, as outlined below. We expect final settlement by year end. This acquisition is referred to as the Pembroke Acquisition. The Pembroke Acquisition is consistent with our general business strategy and broadens the geographic diversity of our refining and marketing network. The purchase price for the Pembroke Acquisition has been preliminarily allocated based on estimated fair values of the assets acquired and liabilities assumed at the acquisition date, pending the completion of an independent appraisal and other evaluations. The preliminary purchase price allocation as of September 30, 2011 was as follows (in millions):
The acquired intangible assets are subject to amortization and have preliminary estimated useful lives of 15 years. These acquired intangible assets have been preliminarily assigned to the major intangible asset classes of royalties and licenses and wholesale dealer agreements. During the three and nine months ended September 30, 2011, we recognized $18 million and $23 million, respectively, of costs related to the Pembroke Acquisition. These costs were expensed and are included in general and administrative expenses. Our consolidated statements of income include the results of operations of the Pembroke Acquisition commencing on August 1, 2011. The operating revenues and income from continuing operations associated with the Pembroke Acquisition included in our consolidated statements of income for the three and nine months ended September 30, 2011, were as follows (in millions):
The following pro forma financial information (in millions, except per share amounts) presents our consolidated results assuming the Pembroke Acquisition occurred on January 1, 2010. The pro forma financial information is not necessarily indicative of the results of future operations.
Acquisition of Pipeline and Terminal Facilities In June 2011, we acquired two product terminal facilities in Louisville and Lexington, Kentucky and a minority interest in the LouLex Pipeline system, which connects the terminal facilities, from a subsidiary of Chevron for cash consideration of $37 million. These assets provide storage and distribution facilities for our wholesale marketing business in eastern Kentucky, which is supplied primarily by our Memphis Refinery. Because this acquisition was not material to our results of operations, we have not presented actual results of operations for this acquisition from the acquisition date through September 30, 2011 or pro forma results of operations for the three and nine months ended September 30, 2011 and 2010. The consolidated statements of income for the three and nine months ended September 30, 2011 include the results of this acquisition from its acquisition date. Acquisitions of Ethanol Plants In December 2009, we signed an agreement with ASA Ethanol Holdings, LLC to buy two ethanol plants located in Linden, Indiana and Bloomingburg, Ohio and made a $20 million advance payment towards the acquisition of these plants. In January 2010, we completed the acquisition of these plants, including certain inventories, for total consideration of $202 million. Also in December 2009, we received approval from a bankruptcy court to acquire an ethanol plant located near Jefferson, Wisconsin from Renew Energy LLC and made a $1 million advance payment towards the acquisition of this plant. We completed the acquisition of this plant, including certain receivables and inventories, in February 2010 for total consideration of $79 million. Disposition of Paulsboro Refinery In December 2010, we sold our Paulsboro Refinery to PBF Holding Company LLC (PBF Holding) for total proceeds of $707 million, including $361 million from the sale of working capital, resulting in a pre-tax loss of $980 million ($610 million after taxes). The sale proceeds consisted of $547 million of cash and a $160 million note secured by the Paulsboro Refinery. The note matures in December 2011 and bears interest at LIBOR plus 700 basis points. PBF Holding has the option to extend the note for six months; however, the interest rate for the additional six months will be LIBOR plus 900 basis points. The results of operations of the Paulsboro Refinery are reflected in discontinued operations, and selected results prior to its sale are shown below (in millions).
Disposition of Delaware City Refinery Assets and Associated Terminal and Pipeline Assets In June 2010, we sold our shutdown Delaware City Refinery assets and associated terminal and pipeline assets to wholly owned subsidiaries of PBF Energy Partners LP (PBF) for $220 million of cash proceeds. The sale resulted in a gain of $92 million ($58 million after taxes) related to the shutdown refinery assets and a gain of $3 million related to the terminal and pipeline assets. The gain on the sale of the shutdown refinery assets resulted from the proceeds we received for the scrap value of the assets and the reversal of certain liabilities recorded in the fourth quarter of 2009 associated with the shutdown of the refinery, which we did not incur because of the sale, and this gain is presented in discontinued operations for the nine months ended September 30, 2010. Results of operations of the Delaware City Refinery are reflected in discontinued operations, and selected results prior to its sale, excluding the gain on the sale, are shown below (in millions):
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Debt, Bank Debt and Credit Facilities (Details) In Millions, unless otherwise specified | 3 Months Ended | 9 Months Ended | 3 Months Ended | 9 Months Ended | 3 Months Ended | 9 Months Ended | 3 Months Ended | 3 Months Ended | 0 Months Ended | |||||||||||||||
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Sep. 30, 2011
USD ($) | Sep. 30, 2011
USD ($) | Sep. 30, 2010
USD ($) | Dec. 31, 2010
USD ($) | Sep. 30, 2011
Maximum [Member]
U S Revolver [Member] | Sep. 30, 2011
U S Revolver [Member]
USD ($) | Sep. 30, 2011
U S Revolver [Member]
USD ($) | Sep. 30, 2010
U S Revolver [Member]
USD ($) | Dec. 31, 2010
U S Revolver [Member]
USD ($) | Sep. 30, 2011
U S Revolver Letter of Credit [Member]
USD ($) | Dec. 31, 2010
U S Revolver Letter of Credit [Member]
USD ($) | Sep. 30, 2011
Canadian Revolver [Member]
USD ($) | Sep. 30, 2011
Canadian Revolver [Member]
USD ($) | Sep. 30, 2010
Canadian Revolver [Member]
USD ($) | Dec. 31, 2010
Canadian Revolver [Member]
USD ($) | Sep. 30, 2011
Canadian Revolver Letter of Credit [Member]
USD ($) | Dec. 31, 2010
Canadian Revolver Letter of Credit [Member]
USD ($) | Sep. 30, 2011
Short Term Revolving Letter of Credit [Member]
USD ($) | Dec. 31, 2010
Short Term Revolving Letter of Credit [Member]
USD ($) | Sep. 30, 2011
One Year Revolving Letter Of Credit [Member]
USD ($) | Dec. 31, 2010
One Year Revolving Letter Of Credit [Member]
USD ($) | Sep. 30, 2011
Other Letter of Credit [Member]
USD ($) | Dec. 31, 2010
Other Letter of Credit [Member]
USD ($) | Aug. 01, 2011
Notes Payable to Banks [Member]
EUR (€) | |
Line of Credit Facility | ||||||||||||||||||||||||
Line of credit facility, maximum borrowing capacity | $ 2,400 | $ 2,400 | $ 115 | $ 115 | $ 200 | $ 300 | ||||||||||||||||||
Line of credit facility, expiration date | November 2012 | December 2012 | June 2012 | June 2012 | ||||||||||||||||||||
Letters of credit outstanding | 0 | 0 | 0 | 74 | 399 | 0 | 0 | 0 | 20 | 20 | 0 | 0 | 300 | 100 | 346 | 176 | ||||||||
Credit Facilities (Textual) | ||||||||||||||||||||||||
Debt to capitalization ratios as per terms of revolver | 0.60 | 0.22 | 0.22 | 0.25 | ||||||||||||||||||||
Borrowings from long-term lines of credit | 0 | 0 | 0 | 0 | ||||||||||||||||||||
Repayments of long-term lines of credit | 0 | 0 | 0 | 0 | ||||||||||||||||||||
Short-term notes (Textual) | ||||||||||||||||||||||||
Short-term note | 2.8 | |||||||||||||||||||||||
Debt instruments maturity date (month, year) | February 2012 | |||||||||||||||||||||||
Accounts Receivable Sales Facility (Textual) | ||||||||||||||||||||||||
Maximum eligible trade receivables | 1,000 | 1,000 | ||||||||||||||||||||||
Extended term of accounts receivable sales facility | June 2012 | |||||||||||||||||||||||
Eligible receivables sold to third party entities and financial institutions | 100 | 100 | 100 | |||||||||||||||||||||
Sale of eligible receivable to third party entities and financial institutions | 0 | 1,225 | ||||||||||||||||||||||
Repayment of eligible receivables | $ 0 | $ 1,325 |
Supplemental Cash Flow Information (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Supplemental Cash Flow Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Changes in current assets and current liabilities | In order to determine net cash provided by operating activities, net income is adjusted by, among other things, changes in current assets and current liabilities as follows (in millions):
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Cash flows related to interest and income taxes | Cash flows related to interest and income taxes were as follows (in millions):
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Cash flows related to discontinued operations | Cash flows related to the discontinued operations of the Paulsboro and Delaware City Refineries have been combined with the cash flows from continuing operations within each category in the consolidated statement of cash flows for the nine months ended September 30, 2010 and are summarized as follows (in millions):
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Impairment Analysis | 9 Months Ended | ||||
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Sep. 30, 2011 | |||||
Impairment Analysis [Abstract] | |||||
IMPAIRMENT ANALYSIS |
In late 2008, the U.S. and worldwide economies experienced severe disruptions in their capital and commodities markets resulting in a significant slowdown that persisted throughout 2009. This slowdown negatively impacted refining industry fundamentals and the demand and price for our refined products. Because of this negative impact, we decided to shut down our Aruba Refinery temporarily in July 2009, and it remained shut until January 2011. We restarted our Aruba Refinery due to improvements in the U.S. and worldwide economies and the resulting improvement in refining industry fundamentals; however, we analyzed our Aruba Refinery for potential impairment as of September 30, 2011 because of its recent temporary shutdown, its negative operating cash flows subsequent to its restart, the sensitivity of its profitability to sour crude oil differentials, and our decision in July 2011 to renew our exploration of strategic alternatives for the refinery, which may include the sale of the refinery. We considered these matters in our impairment analysis and concluded that our Aruba Refinery was not impaired as of September 30, 2011. Our future cash flow estimates for the refinery are based on our expectation that refining industry fundamentals will continue to improve in connection with an increase in the demand for refined products. Should refining industry fundamentals fail to continue to improve or should we decide to sell the refinery, our future cash flow estimates may be negatively impacted and we could ultimately determine that the refinery is impaired. The Aruba Refinery had a net book value of $950 million as of September 30, 2011; therefore, an impairment loss could be material to our results of operations. |
Employee Benefit Plans (Details) (USD $) In Millions | 3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2011 | Sep. 30, 2010 | Sep. 30, 2011 | Sep. 30, 2010 | |
Employee Benefit Plans (Textual) | ||||
Contributions to pension plans | $ 207 | $ 54 | ||
Pension Plans, Defined Benefit [Member] | ||||
Components of net periodic benefit cost: | ||||
Service cost | 28 | 22 | 73 | 65 |
Interest cost | 21 | 21 | 64 | 62 |
Expected return on plan assets | (28) | (28) | (84) | (84) |
Amortization of: | ||||
Prior service cost (credit) | 1 | 1 | 2 | 2 |
Net loss | 3 | 0 | 9 | 1 |
Net periodic benefit cost | 25 | 16 | 64 | 46 |
Other Postretirement Benefit Plans, Defined Benefit [Member] | ||||
Components of net periodic benefit cost: | ||||
Service cost | 4 | 3 | 9 | 8 |
Interest cost | 5 | 6 | 16 | 19 |
Expected return on plan assets | 0 | 0 | 0 | 0 |
Amortization of: | ||||
Prior service cost (credit) | (6) | (5) | (17) | (15) |
Net loss | 0 | 1 | 1 | 3 |
Net periodic benefit cost | $ 3 | $ 5 | $ 9 | $ 15 |
Employee Benefit Plans (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Employee Benefit Plans [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Periodic benefit cost related to our defined benefit plans, net | The components of net periodic benefit cost related to our defined benefit plans were as follows for the three and nine months ended September 30, 2011 and 2010 (in millions):
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Price Risk Management Activities (Tables) | 9 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Price Risk Management Activities [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Volume of outstanding contracts in fair value hedges | As of September 30, 2011, we had the following outstanding commodity derivative instruments that were entered into to hedge crude oil and refined product inventories and commodity derivative instruments related to the physical purchase of crude oil and refined products at a fixed price. The information presents the notional volume of outstanding contracts by type of instrument and year of maturity (volumes in thousands of barrels).
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Volume of outstanding contracts cash flow hedges | As of September 30, 2011, we had the following outstanding commodity derivative instruments that were entered into to hedge forecasted purchases or sales of crude oil and refined products. The information presents the notional volume of outstanding contracts by type of instrument and year of maturity (volumes in thousands of barrels).
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Volume of outstanding contracts in economic hedges | As of September 30, 2011, we had the following outstanding commodity derivative instruments that were entered into as economic hedges and commodity derivative instruments related to the physical purchase of corn at a fixed price. The information presents the notional volume of outstanding contracts by type of instrument and year of maturity (volumes in thousands of barrels, except those identified as corn contracts that are presented in thousands of bushels).
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Volume of outstanding contracts in trading derivatives | As of September 30, 2011, we had the following outstanding commodity derivative instruments that were entered into for trading purposes. The information presents the notional volume of outstanding contracts by type of instrument and year of maturity (volumes represent thousands of barrels, except those identified as natural gas contracts that are presented in billions of British thermal units and corn contracts that are presented in thousands of bushels).
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Fair values of derivative instruments | The tables below, however, are presented on a gross asset and gross liability basis, which results in the reflection of certain assets in liability accounts and certain liabilities in asset accounts. In addition, in Note 12, we included cash collateral on deposit with or received from brokers in the fair value of the commodity derivatives; these cash amounts are not reflected in the tables below.
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Effect of derivative instruments on consolidated statements of income and OCI |
The following tables provide information about the gain or loss recognized in income and other comprehensive income on our derivative instruments and the line items in the consolidated financial statements in which such gains and losses are reflected (in millions).
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Equity (Details) (USD $) In Millions, except Per Share data | 3 Months Ended | 9 Months Ended | 0 Months Ended | 1 Months Ended | |||||||
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Sep. 30, 2011 | Sep. 30, 2010 | Sep. 30, 2011 | Sep. 30, 2010 | Sep. 30, 2011
Parent [Member] | Sep. 30, 2010
Parent [Member] | Sep. 30, 2011
Noncontrolling Interest [Member] | Sep. 30, 2010
Noncontrolling Interest [Member] | Oct. 27, 2011
Dividend Declared [Member] | Nov. 16, 2011
Dividend Declared [Member] | Dec. 14, 2011
Dividend Declared [Member] | |
Reconciliation of the beginning and ending balances of the carrying amount of equity | |||||||||||
Balance at beginning of period | $ 15,025 | $ 14,725 | $ 15,025 | $ 14,725 | $ 0 | $ 0 | |||||
Net income | 1,203 | 292 | 2,044 | 762 | 2,045 | 762 | (1) | 0 | |||
Dividends | (85) | (85) | (85) | (85) | 0 | 0 | |||||
Stock-based compensation expense | 34 | 32 | 34 | 32 | 0 | 0 | |||||
Tax deduction in excess of stock-based compensation expense | 19 | 7 | 19 | 7 | 0 | 0 | |||||
Transactions in connection with stock-based compensation plans: | |||||||||||
Stock issuances | 42 | 12 | 42 | 12 | 0 | 0 | |||||
Stock repurchases | (270) | (2) | (270) | (2) | 0 | 0 | |||||
Contributions from noncontrolling interest | 14 | 0 | 0 | 0 | 14 | 0 | |||||
Recognition of noncontrolling interest in connection with Pembroke Acquisition | 3 | 0 | 0 | 0 | 3 | 0 | |||||
Other comprehensive income (loss) | (266) | 74 | (156) | (51) | (156) | (51) | 0 | 0 | |||
Balance at end of period | $ 16,670 | $ 15,400 | $ 16,670 | $ 15,400 | $ 16,654 | $ 15,400 | $ 16 | $ 0 | |||
Equity (Textual) | |||||||||||
Shares of common stock repurchased | 13.6 | 1.6 | |||||||||
Shares of common stock issued from treasury | 3.9 | 1.6 | |||||||||
Dividends payable, date declared | Oct. 27, 2011 | ||||||||||
Dividends payable, amount per share | $ 0.15 | ||||||||||
Dividends payable, date to be paid | Dec. 14, 2011 | ||||||||||
Dividends payable, date of record | Nov. 16, 2011 |
Segment Information (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Segment Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment information for our three reportable segments | The following table reflects segment activity related to continuing operations (in millions):
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Total assets by reportable segment | Total assets by reportable segment were as follows (in millions):
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Supplemental Cash Flow Information | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Supplemental Cash Flow Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
SUPPLEMENTAL CASH FLOW INFORMATION |
In order to determine net cash provided by operating activities, net income is adjusted by, among other things, changes in current assets and current liabilities as follows (in millions):
The above changes in current assets and current liabilities differ from changes between amounts reflected in the applicable consolidated balance sheets for the respective periods for the following reasons:
During the nine months ended September 30, 2011, we received a noncash contribution of $2 million from the noncontrolling interest for property, plant and equipment related to DGD Holdings. There were no significant noncash investing or financing activities for the nine months ended September 30, 2010. Cash flows related to interest and income taxes were as follows (in millions):
Cash flows related to the discontinued operations of the Paulsboro and Delaware City Refineries have been combined with the cash flows from continuing operations within each category in the consolidated statement of cash flows for the nine months ended September 30, 2010 and are summarized as follows (in millions):
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Inventories | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2011 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventories [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
INVENTORIES |
Inventories consisted of the following (in millions):
As of September 30, 2011 and December 31, 2010, the replacement cost (market value) of LIFO inventories exceeded their LIFO carrying amounts by approximately $7.1 billion and $6.1 billion, respectively. |
Basis of Presentation and Summary of Significant Accounting Policies (Policies) | 9 Months Ended |
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Sep. 30, 2011 | |
Basis of Presentation and Summary of Significant Accounting Policies [Abstract] | |
Basis of Presentation | Basis of Presentation General As used in this report, the terms “Valero,” “we,” “us,” or “our” may refer to Valero Energy Corporation, one or more of its consolidated subsidiaries, or all of them taken as a whole. These unaudited consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X of the Securities Exchange Act of 1934. Accordingly, they do not include all of the information and notes required by GAAP for complete consolidated financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation have been included. All such adjustments are of a normal recurring nature unless disclosed otherwise. Financial information for the three and nine months ended September 30, 2011 and 2010 included in these Condensed Notes to Consolidated Financial Statements is derived from our unaudited consolidated financial statements. Operating results for the three and nine months ended September 30, 2011 are not necessarily indicative of the results that may be expected for the year ending December 31, 2011. The consolidated balance sheet as of December 31, 2010 has been derived from our audited financial statements as of that date. For further information, refer to our consolidated financial statements and notes thereto included in our annual report on Form 10-K for the year ended December 31, 2010. We have evaluated subsequent events that occurred after September 30, 2011 through the filing of this Form 10-Q. Any material subsequent events that occurred during this time have been properly recognized or disclosed in these financial statements. |
Noncontrolling Interests | Because of our controlling financial interests in MLP and DGD Holdings, we have included the financial statements of MLP and DGD Holdings in these consolidated financial statements and have separately disclosed the related noncontrolling interests. |
Reclassifications | Reclassifications As discussed in Note 2, we sold our Paulsboro Refinery in December 2010. As a result, the results of operations of the Paulsboro Refinery have been reclassified to discontinued operations for the three and nine months ended September 30, 2010. In addition, credit card fees previously recognized in 2010 in retail operating expenses have been reclassified to cost of sales as such fees are directly and jointly related to the sale transaction. This reclassification resulted in an increase in cost of sales and a decrease in retail operating expenses of $23 million and $68 million for the three and nine months ended September 30, 2010, respectively. |
Use of Estimates | Use of Estimates The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. On an ongoing basis, we review our estimates based on currently available information. Changes in facts and circumstances may result in revised estimates. |
Description of New Accounting Pronouncements Not yet Adopted | New Accounting Pronouncements In June 2011, the provisions of Accounting Standards Codification (ASC) Topic 220, “Comprehensive Income,” were amended to allow an entity the option to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement or in two separate but consecutive statements. In both choices, the entity is required to present reclassification adjustments on the face of the financial statements for items that are reclassified from other comprehensive income to net income in the statement where those components are presented. These provisions are effective for the first interim or annual period beginning after December 15, 2011, and are to be applied retrospectively, with early adoption permitted. The adoption of this guidance effective January 1, 2012 will not affect our financial position or results of operations because these requirements only affect disclosures. In May 2011, the provisions of ASC Topic 820, “Fair Value Measurement,” were amended to clarify the application of existing fair value measurement requirements and to change certain fair value measurement and disclosure requirements. Amendments that change measurement and disclosure requirements relate to (i) fair value measurement of financial instruments that are managed within a portfolio, (ii) application of premiums and discounts in a fair value measurement, and (iii) additional disclosures about fair value measurements categorized within Level 3 of the fair value hierarchy. These provisions are effective for the first interim or annual period beginning after December 15, 2011. The adoption of this guidance effective January 1, 2012 will not affect our financial position or results of operations, but may result in additional disclosures. |
Receivables | In January 2011, the provisions of ASC Topic 310, “Receivables,” were amended to delay temporarily the effective date of disclosures relating to troubled debt restructurings, which were previously amended in July 2010, in order to allow the Financial Accounting Standards Board time to complete its deliberations on what constitutes a troubled debt restructuring. In April 2011, the provisions of ASC Topic 310 were amended to clarify the guidance on a creditor’s evaluations of whether it has granted a concession to the debtor and whether the debtor is experiencing financial difficulties. These provisions are effective for the first interim or annual period beginning on or after June 15, 2011. The new guidance should be applied retrospectively to restructurings occurring on or after the beginning of the annual period of adoption, with early adoption permitted. The adoption of this guidance effective July 1, 2011 did not affect our financial position or results of operations. |
Debt (Details) (USD $) In Millions, unless otherwise specified | 3 Months Ended | 9 Months Ended | 1 Months Ended | 1 Months Ended | |||||||||||||||||
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Sep. 30, 2011 | Sep. 30, 2010 | Sep. 30, 2011 | Sep. 30, 2010 | Feb. 28, 2010
Notes Due In February 2015 [Member] | Feb. 28, 2010
Notes Due In February 2020 [Member] | Feb. 28, 2010
Notes Issued In February 2010 [Member] | Mar. 31, 2010
Senior Notes Due In June 2015 [Member] | Apr. 30, 2011
Industrial Revenue Bonds Tax Exempt Refunding Bonds [Member] | Apr. 30, 2010
Industrial Revenue Bonds Tax Exempt Refunding Bonds [Member] | Apr. 30, 2011
Tax Exempt Revenue Refunding Bonds Series 1997A [Member] | Apr. 30, 2010
Tax Exempt Revenue Refunding Bonds Series 1997A [Member] | Apr. 30, 2011
Tax Exempt Revenue Refunding Bonds Series 1997B [Member] | Apr. 30, 2010
Tax Exempt Revenue Refunding Bonds Series 1997B [Member] | Apr. 30, 2011
Tax Exempt Revenue Refunding Bonds Series 1997C [Member] | Apr. 30, 2010
Tax Exempt Revenue Refunding Bonds Series 1997C [Member] | Feb. 28, 2011
Senior Notes Due In February 2011 [Member] | Feb. 28, 2011
Gulf Opportunity Zone Revenue Bonds Series 2010 [Member] | May 31, 2011
Senior Notes Due In May 2011 [Member] | Jun. 30, 2010
Debenture Due In June 2010 [Member] | May 31, 2010
Senior Notes Due In May 2014 [Member] | |
Non-Bank Debt (Textual) | |||||||||||||||||||||
Debt repayments | $ 718 | $ 517 | $ 294 | $ 8 | $ 8 | $ 210 | $ 300 | $ 200 | $ 25 | $ 190 | |||||||||||
Interest rate of notes in percentage | 4.50% | 6.125% | 7.50% | 5.45% | 5.45% | 5.40% | 5.40% | 5.40% | 5.40% | 6.75% | 6.125% | 7.25% | 6.75% | ||||||||
Debt instrument maturity date (month, day, year) | Jun. 15, 2015 | May 01, 2014 | |||||||||||||||||||
Redemption value in percentage | 102.50% | 102.25% | |||||||||||||||||||
Debt instruments maturity date (month, year) | February 2015 | February 2020 | |||||||||||||||||||
Notes issued, face amount | 400 | 850 | |||||||||||||||||||
Proceeds from debt, net of issuance costs | 0 | 1,244 | 1,244 | ||||||||||||||||||
Capitalized Interest (Textual) | |||||||||||||||||||||
Interest Costs Incurred, Capitalized | $ 41 | $ 25 | $ 101 | $ 67 |
Earnings Per Common Share (Tables) | 9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2011 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of earnings per common share, basic and diluted | Earnings per common share from continuing operations were computed as follows (dollars and shares in millions, except per share amounts):
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Potentially dilutive securities excluded from calculation of earnings per common share - assuming dilution | The following table reflects potentially dilutive securities (in millions) that were excluded from the calculation of “earnings per common share from continuing operations – assuming dilution” as the effect of including such securities would have been antidilutive. These potentially dilutive securities included common stock options for which the exercise prices were greater than the average market price of our common stock during each respective reporting period.
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