þ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |
FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2016 |
o | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |
FOR THE TRANSITION PERIOD FROM __________TO __________ |
Delaware | 46-0810241 | |
(State of organization) | (I.R.S. Employer | |
Identification No.) |
Large accelerated filer o | Accelerated filer þ | Non-accelerated filer o | Smaller reporting company o |
Page | |
ITEM 1. | FINANCIAL STATEMENTS |
September 30, 2016 | December 31, 2015 | ||||||
(unaudited) | |||||||
ASSETS | |||||||
Current assets: | |||||||
Cash and cash equivalents | $ | 203,763 | $ | 132,953 | |||
Accounts and other receivables, net | 70,884 | 59,581 | |||||
Accounts and other receivables, net - related parties | 10,191 | 8,005 | |||||
Inventories | 51,890 | 35,444 | |||||
Prepaid expenses and other current assets | 5,733 | 6,745 | |||||
Total current assets | 342,461 | 242,728 | |||||
Property, plant and equipment, net | 423,187 | 434,619 | |||||
Other assets, net | 59,402 | 71,237 | |||||
Total assets | $ | 825,050 | $ | 748,584 | |||
LIABILITIES AND PARTNERS’ EQUITY | |||||||
Current liabilities: | |||||||
Accounts payable | $ | 292,542 | $ | 253,325 | |||
Accrued liabilities | 36,959 | 40,707 | |||||
Current portion of long-term debt | 2,500 | 2,500 | |||||
Total current liabilities | 332,001 | 296,532 | |||||
Other non-current liabilities | 92,095 | 31,513 | |||||
Long-term debt | 288,986 | 289,582 | |||||
Total liabilities | 713,082 | 617,627 | |||||
Commitments and contingencies (Note 11) | |||||||
Partners’ equity: | |||||||
General Partner | — | — | |||||
Common unitholders - 62,520,220 and 62,510,039 units issued and outstanding at September 30, 2016 and December 31, 2015, respectively | 111,968 | 130,957 | |||||
Total partners’ equity | 111,968 | 130,957 | |||||
Total liabilities and partners’ equity | $ | 825,050 | $ | 748,584 |
For the Three Months Ended | For the Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
Net sales (1) | $ | 462,257 | $ | 551,813 | $ | 1,298,723 | $ | 1,719,319 | |||||||
Operating costs and expenses: | |||||||||||||||
Cost of sales | 404,207 | 439,678 | 1,134,275 | 1,397,395 | |||||||||||
Direct operating expenses | 25,125 | 24,136 | 73,424 | 71,837 | |||||||||||
Selling, general and administrative expenses | 8,153 | 8,536 | 24,264 | 24,654 | |||||||||||
Depreciation and amortization | 14,581 | 13,697 | 43,454 | 41,281 | |||||||||||
Total operating costs and expenses | 452,066 | 486,047 | 1,275,417 | 1,535,167 | |||||||||||
Operating income | 10,191 | 65,766 | 23,306 | 184,152 | |||||||||||
Interest expense | (8,144 | ) | (11,505 | ) | (28,651 | ) | (34,045 | ) | |||||||
Other income, net | 353 | 40 | 550 | 26 | |||||||||||
Income (loss) before state income tax expense | 2,400 | 54,301 | (4,795 | ) | 150,133 | ||||||||||
State income tax expense | 317 | 525 | 493 | 480 | |||||||||||
Net income (loss) | $ | 2,083 | $ | 53,776 | $ | (5,288 | ) | $ | 149,653 | ||||||
Earnings (loss) per unit | $ | 0.03 | $ | 0.86 | $ | (0.08 | ) | $ | 2.39 | ||||||
Weighted average common units outstanding (in thousands) | 62,520 | 62,510 | 62,515 | 62,508 | |||||||||||
Cash distribution per unit | $ | 0.14 | $ | 1.04 | $ | 0.22 | $ | 2.45 |
(1) | Includes sales to related parties of $82,717 and $97,014 for the three months and $222,711 and $281,136 for the nine months ended September 30, 2016 and 2015, respectively. |
ALON USA PARTNERS, LP AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited, dollars in thousands) | |||||||
For the Nine Months Ended | |||||||
September 30, | |||||||
2016 | 2015 | ||||||
Cash flows from operating activities: | |||||||
Net income (loss) | $ | (5,288 | ) | $ | 149,653 | ||
Adjustments to reconcile net income (loss) to cash provided by operating activities: | |||||||
Depreciation and amortization | 43,454 | 41,281 | |||||
Unit-based compensation | 53 | 40 | |||||
Deferred income taxes | — | (736 | ) | ||||
Amortization of debt issuance costs | 1,335 | 1,750 | |||||
Amortization of original issuance discount | 480 | 445 | |||||
Changes in operating assets and liabilities: | |||||||
Accounts and other receivables, net | (7,064 | ) | (3,770 | ) | |||
Accounts and other receivables, net - related parties | (2,186 | ) | (184 | ) | |||
Inventories | (16,446 | ) | 3,998 | ||||
Prepaid expenses and other current assets | 1,012 | 202 | |||||
Other assets, net | 4,573 | (5,067 | ) | ||||
Accounts payable | 22,268 | 45,194 | |||||
Accrued liabilities | (2,134 | ) | (16,835 | ) | |||
Other non-current liabilities | 18,400 | 3,261 | |||||
Net cash provided by operating activities | 58,457 | 219,232 | |||||
Cash flows from investing activities: | |||||||
Capital expenditures | (17,199 | ) | (12,108 | ) | |||
Capital expenditures for turnarounds and catalysts | (9,679 | ) | (3,214 | ) | |||
Net cash used in investing activities | (26,878 | ) | (15,322 | ) | |||
Cash flows from financing activities: | |||||||
Distributions paid to unitholders | (2,534 | ) | (28,195 | ) | |||
Distributions paid to unitholders - Alon Energy | (11,220 | ) | (124,950 | ) | |||
RINs financing transactions | 54,860 | (8,137 | ) | ||||
Deferred debt issuance costs | — | (1,800 | ) | ||||
Revolving credit facility, net | — | (10,000 | ) | ||||
Payments on long-term debt | (1,875 | ) | (1,875 | ) | |||
Net cash provided by (used in) financing activities | 39,231 | (174,957 | ) | ||||
Net increase in cash and cash equivalents | 70,810 | 28,953 | |||||
Cash and cash equivalents, beginning of period | 132,953 | 106,325 | |||||
Cash and cash equivalents, end of period | $ | 203,763 | $ | 135,278 | |||
Supplemental cash flow information: | |||||||
Cash paid for interest, net of capitalized interest | $ | 27,219 | $ | 31,785 | |||
Cash paid for income tax | $ | 493 | $ | 1,216 | |||
Supplemental disclosure of non-cash activity: | |||||||
Capital expenditures included in accounts payable and accrued liabilities | $ | — | $ | 3,016 |
(1) | Basis of Presentation |
(2) | Fair Value |
• | Level 1 - valued based on quoted prices in active markets for identical assets and liabilities; |
• | Level 2 - valued based on quoted prices for similar assets and liabilities in active markets, and inputs other than quoted prices that are observable for the asset or liability; and |
• | Level 3 - valued based on unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. |
Level 1 | Level 2 | Level 3 | Total | ||||||||||||
As of September 30, 2016 | |||||||||||||||
Assets: | |||||||||||||||
Fair value hedge of consigned inventory | $ | — | $ | 5,569 | $ | — | $ | 5,569 | |||||||
Liabilities: | |||||||||||||||
Commodity contracts (futures and forwards) | 1,033 | — | — | 1,033 | |||||||||||
As of December 31, 2015 | |||||||||||||||
Assets: | |||||||||||||||
Fair value hedge of consigned inventory | $ | — | $ | 11,564 | $ | — | $ | 11,564 | |||||||
Liabilities: | |||||||||||||||
Commodity contracts (futures and forwards) | 40 | — | — | 40 |
(3) | Derivative Financial Instruments |
As of September 30, 2016 | |||||||||||
Asset Derivatives | Liability Derivatives | ||||||||||
Balance Sheet Location | Fair Value | Balance Sheet Location | Fair Value | ||||||||
Derivatives not designated as hedging instruments: | |||||||||||
Commodity contracts (futures and forwards) | Accounts receivable | $ | 427 | Accrued liabilities | $ | 1,460 | |||||
Total derivatives not designated as hedging instruments | 427 | 1,460 | |||||||||
Derivatives designated as hedging instruments: | |||||||||||
Fair value hedge of consigned inventory | Other assets | $ | 5,569 | $ | — | ||||||
Total derivatives designated as hedging instruments | 5,569 | — | |||||||||
Total derivatives | $ | 5,996 | $ | 1,460 |
As of December 31, 2015 | |||||||||||
Asset Derivatives | Liability Derivatives | ||||||||||
Balance Sheet Location | Fair Value | Balance Sheet Location | Fair Value | ||||||||
Derivatives not designated as hedging instruments: | |||||||||||
Commodity contracts (futures and forwards) | Accounts receivable | $ | 59 | Accrued liabilities | $ | 99 | |||||
Total derivatives not designated as hedging instruments | 59 | 99 | |||||||||
Derivatives designated as hedging instruments: | |||||||||||
Fair value hedge of consigned inventory | Other assets | $ | 11,564 | $ | — | ||||||
Total derivatives designated as hedging instruments | 11,564 | — | |||||||||
Total derivatives | $ | 11,623 | $ | 99 |
Gain (Loss) Recognized in Income | |||||||||||||||||
For the Three Months Ended | For the Nine Months Ended | ||||||||||||||||
September 30, | September 30, | ||||||||||||||||
Location | 2016 | 2015 | 2016 | 2015 | |||||||||||||
Fair value hedge of consigned inventory (1) | Interest expense | $ | (1,772 | ) | $ | 5,990 | $ | (5,995 | ) | $ | 4,495 | ||||||
Total derivatives | $ | (1,772 | ) | $ | 5,990 | $ | (5,995 | ) | $ | 4,495 |
(1) | Changes in the fair value hedge are substantially offset in earnings by changes in the hedged item. |
Gain (Loss) Recognized in Income | |||||||||||||||||
For the Three Months Ended | For the Nine Months Ended | ||||||||||||||||
September 30, | September 30, | ||||||||||||||||
Location | 2016 | 2015 | 2016 | 2015 | |||||||||||||
Commodity contracts (futures and forwards) | Cost of sales | $ | (1,199 | ) | $ | 1,251 | $ | 4,998 | $ | 622 | |||||||
Total derivatives | $ | (1,199 | ) | $ | 1,251 | $ | 4,998 | $ | 622 |
Gross Amounts of Recognized Assets/Liabilities | Gross Amounts offset in the Statement of Financial Position | Net Amounts Presented in the Statement of Financial Position | Gross Amounts Not offset in the Statement of Financial Position | Net Amount | |||||||||||||||||||
Financial Instruments | Cash Collateral Pledged | ||||||||||||||||||||||
As of September 30, 2016 | |||||||||||||||||||||||
Derivative Assets: | |||||||||||||||||||||||
Commodity contracts (futures and forwards) | $ | 1,174 | $ | (747 | ) | $ | 427 | $ | (427 | ) | $ | — | $ | — | |||||||||
Fair value hedge of consigned inventory | 5,569 | — | 5,569 | — | — | 5,569 | |||||||||||||||||
Derivative Liabilities: | |||||||||||||||||||||||
Commodity contracts (futures and forwards) | $ | 2,207 | $ | (747 | ) | $ | 1,460 | $ | (427 | ) | $ | — | $ | 1,033 | |||||||||
As of December 31, 2015 | |||||||||||||||||||||||
Derivative Assets: | |||||||||||||||||||||||
Commodity contracts (futures and forwards) | $ | 192 | $ | (133 | ) | $ | 59 | $ | (59 | ) | $ | — | $ | — | |||||||||
Fair value hedge of consigned inventory | 11,564 | — | 11,564 | — | — | 11,564 | |||||||||||||||||
Derivative Liabilities: | |||||||||||||||||||||||
Commodity contracts (futures and forwards) | $ | 232 | $ | (133 | ) | $ | 99 | $ | (59 | ) | $ | — | $ | 40 |
(4) | Inventories |
September 30, 2016 | December 31, 2015 | ||||||
Crude oil, refined products and blendstocks | $ | 39,909 | $ | 24,548 | |||
Crude oil consignment inventory (Note 5) (1) | 838 | (95 | ) | ||||
Materials and supplies | 11,143 | 10,991 | |||||
Total inventories | $ | 51,890 | $ | 35,444 |
(1) | The fair value of the hedged item designated in our fair value hedge reduced the carrying value of our consigned inventory valued at LIFO below zero at December 31, 2015. |
(5) | Inventory Financing Agreement |
(6) | Property, Plant and Equipment, Net |
September 30, 2016 | December 31, 2015 | ||||||
Refining facilities | $ | 725,905 | $ | 709,779 | |||
Accumulated depreciation | (302,718 | ) | (275,160 | ) | |||
Property, plant and equipment, net | $ | 423,187 | $ | 434,619 |
(7) | Additional Financial Information |
(a) | Other Assets, Net |
September 30, 2016 | December 31, 2015 | ||||||
Deferred turnaround and catalyst cost | $ | 38,199 | $ | 43,021 | |||
Receivable from supply and offtake agreement (Note 5) | 6,290 | 6,290 | |||||
Fair value hedge of consigned inventory (Note 3) | 5,569 | 11,564 | |||||
Other | 9,344 | 10,362 | |||||
Total other assets | $ | 59,402 | $ | 71,237 |
(b) | Accounts Payable |
(c) | Accrued Liabilities and Other Non-Current Liabilities |
September 30, 2016 | December 31, 2015 | ||||||
Accrued Liabilities: | |||||||
Taxes other than income taxes, primarily excise taxes | $ | 25,186 | $ | 25,018 | |||
Accrued finance charges | 293 | 394 | |||||
Environmental accrual (Note 11) | 1,716 | 1,716 | |||||
Commodity contracts | 1,460 | 99 | |||||
Other | 8,304 | 13,480 | |||||
Total accrued liabilities | $ | 36,959 | $ | 40,707 | |||
Other Non-Current Liabilities: | |||||||
Consignment inventory obligation (Note 5) | $ | 12,772 | $ | 21,325 | |||
Environmental accrual (Note 11) | 4,722 | 4,725 | |||||
Asset retirement obligations | 3,086 | 2,927 | |||||
RINs financing transactions | 68,978 | — | |||||
Other | 2,537 | 2,536 | |||||
Total other non-current liabilities | $ | 92,095 | $ | 31,513 |
(8) | Indebtedness |
September 30, 2016 | December 31, 2015 | ||||||
Term loan credit facility | $ | 236,486 | $ | 237,082 | |||
Revolving credit facility | 55,000 | 55,000 | |||||
Total debt | 291,486 | 292,082 | |||||
Less: Current portion | 2,500 | 2,500 | |||||
Total long-term debt | $ | 288,986 | $ | 289,582 |
(9) | Partners' Equity (unit values in dollars) |
Cash Available for Distribution per Unit (1) | Distribution Amount Per Unit | Total Distribution Amount | ||||||||||
First Quarter 2016 | $ | — | $ | 0.08 | $ | 5,001 | ||||||
Second Quarter 2016 | 0.14 | — | — | |||||||||
Third Quarter 2016 | 0.15 | 0.14 | 8,753 |
(1) | Represents the aggregate cash available for distribution per unit attributable to the period indicated. This represents the difference between cash available for distribution and distributions paid in the table above. |
(10) | Related Party Transactions |
(a) | Corporate Overhead Allocations |
(b) | Labor Costs |
(c) | Insurance Costs |
(11) | Commitments and Contingencies |
(a) | Commitments |
(b) | Contingencies |
(c) | Environmental |
(12) | Subsequent Event |
ITEM 2. | MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS |
• | changes in general economic conditions and capital markets; |
• | changes in the underlying demand for our products; |
• | the availability, costs and price volatility of crude oil, other refinery feedstocks and refined products; |
• | changes in the spread between West Texas Intermediate (“WTI”) Cushing crude oil and West Texas Sour (“WTS”) crude oil or WTI Midland crude oil; |
• | changes in the spread between Brent crude oil and WTI Cushing crude oil; |
• | the effects of transactions involving forward contracts and derivative instruments; |
• | actions of customers and competitors; |
• | termination of our Supply and Offtake Agreement with J. Aron & Company (“J. Aron”), under which J. Aron is one of our largest suppliers of crude oil and one of our largest customers of refined products. Additionally, upon termination of the Supply and Offtake Agreement, we are obligated to purchase the crude oil and refined product inventories then owned by J. Aron at then current market prices; |
• | changes in fuel and utility costs incurred by our refinery; |
• | disruptions due to equipment interruption, pipeline disruptions or failures at our or third-party facilities; |
• | the execution of planned capital projects; |
• | adverse changes in the credit ratings assigned to our trade credit and debt instruments; |
• | the effects and cost of compliance with the renewable fuel standards program, including the availability, cost and price volatility of renewable identification numbers; |
• | the effects and cost of compliance with current and future state and federal environmental, economic, safety and other laws, policies and regulations; |
• | the effects of seasonality on demand for our products; |
• | operating hazards, accidents, fires, severe weather, floods and other natural disasters, casualty losses and other matters beyond our control, which could result in unscheduled downtime; |
• | the effect of any national or international financial crisis on our business and financial condition; and |
• | the other factors discussed in our Annual Report on Form 10-K for the year ended December 31, 2015 under the caption “Risk Factors.” |
• | Big Spring refinery average throughput for the third quarter of 2016 was 70,063 bpd compared to 75,797 bpd for the third quarter of 2015. The reduced throughput at our Big Spring refinery was the result of a reformer regeneration during the third quarter of 2016. |
• | Operating margin at the Big Spring refinery was $9.22 per barrel for the third quarter of 2016 compared to $16.71 per barrel for the same period in 2015. This decrease in operating margin was primarily due to a lower Gulf Coast 3/2/1 crack spread and increased RINs costs, partially offset by a widening of both the WTI Cushing to WTI Midland and WTI Cushing to WTS spreads and an increased benefit from the contango market environment which reduced the cost of crude. |
• | The average Gulf Coast 3/2/1 crack spread was $13.31 per barrel for the third quarter of 2016 compared to $19.77 per barrel for the third quarter of 2015. |
• | The average WTI Cushing to WTI Midland spread for the third quarter of 2016 was $0.31 per barrel compared to $(0.72) per barrel for the same period in 2015. The average WTI Cushing to WTS spread for the third quarter of 2016 was $0.92 per barrel compared to $(1.46) per barrel for the same period in 2015. The average Brent to WTI Cushing spread for the third quarter of 2016 was $0.74 per barrel compared to $3.78 per barrel for the same period in 2015. |
• | The average RINs cost effect on the Big Spring refinery operating margin was $0.58 per barrel for the third quarter of 2016, compared to $0.27 per barrel for the same period in 2015. |
• | The contango environment in the third quarter of 2016 created an average cost of crude benefit of $0.84 per barrel compared to an average cost of crude benefit of $0.57 per barrel for the same period in 2015. |
• | During the third quarter of 2016, the cash available for distribution was $0.15 per unit, compared to $0.98 per unit during the third quarter of 2015. |
For the Three Months Ended | For the Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(dollars in thousands, except per unit data, per barrel data and pricing statistics) | |||||||||||||||
STATEMENTS OF OPERATIONS DATA: | |||||||||||||||
Net sales (1) | $ | 462,257 | $ | 551,813 | $ | 1,298,723 | $ | 1,719,319 | |||||||
Operating costs and expenses: | |||||||||||||||
Cost of sales | 404,207 | 439,678 | 1,134,275 | 1,397,395 | |||||||||||
Direct operating expenses | 25,125 | 24,136 | 73,424 | 71,837 | |||||||||||
Selling, general and administrative expenses | 8,153 | 8,536 | 24,264 | 24,654 | |||||||||||
Depreciation and amortization | 14,581 | 13,697 | 43,454 | 41,281 | |||||||||||
Total operating costs and expenses | 452,066 | 486,047 | 1,275,417 | 1,535,167 | |||||||||||
Operating income | 10,191 | 65,766 | 23,306 | 184,152 | |||||||||||
Interest expense | (8,144 | ) | (11,505 | ) | (28,651 | ) | (34,045 | ) | |||||||
Other income, net | 353 | 40 | 550 | 26 | |||||||||||
Income (loss) before state income tax expense | 2,400 | 54,301 | (4,795 | ) | 150,133 | ||||||||||
State income tax expense | 317 | 525 | 493 | 480 | |||||||||||
Net income (loss) | $ | 2,083 | $ | 53,776 | $ | (5,288 | ) | $ | 149,653 | ||||||
Earnings (loss) per unit | $ | 0.03 | $ | 0.86 | $ | (0.08 | ) | $ | 2.39 | ||||||
Weighted average common units outstanding (in thousands) | 62,520 | 62,510 | 62,515 | 62,508 | |||||||||||
Cash distribution per unit | $ | 0.14 | $ | 1.04 | $ | 0.22 | $ | 2.45 | |||||||
CASH FLOW DATA: | |||||||||||||||
Net cash provided by (used in): | |||||||||||||||
Operating activities | $ | 11,870 | $ | 84,834 | $ | 58,457 | $ | 219,232 | |||||||
Investing activities | (5,954 | ) | (5,532 | ) | (26,878 | ) | (15,322 | ) | |||||||
Financing activities | 36,027 | (93,908 | ) | 39,231 | (174,957 | ) | |||||||||
OTHER DATA: | |||||||||||||||
Adjusted EBITDA (2) | $ | 25,125 | $ | 79,503 | $ | 67,310 | $ | 225,459 | |||||||
Capital expenditures | 4,499 | 4,322 | 17,199 | 12,108 | |||||||||||
Capital expenditures for turnarounds and catalysts | 1,455 | 1,210 | 9,679 | 3,214 | |||||||||||
KEY OPERATING STATISTICS: | |||||||||||||||
Per barrel of throughput: | |||||||||||||||
Refinery operating margin (3) | $ | 9.22 | $ | 16.71 | $ | 8.52 | $ | 15.95 | |||||||
Refinery direct operating expense (4) | 3.90 | 3.46 | 3.85 | 3.53 | |||||||||||
PRICING STATISTICS: | |||||||||||||||
Crack spreads (per barrel): | |||||||||||||||
Gulf Coast 3/2/1 | $ | 13.31 | $ | 19.77 | $ | 12.57 | $ | 19.08 | |||||||
WTI Cushing crude oil (per barrel) | $ | 44.88 | $ | 46.41 | $ | 41.23 | $ | 50.91 | |||||||
Crude oil differentials (per barrel): | |||||||||||||||
WTI Cushing less WTI Midland | $ | 0.31 | $ | (0.72 | ) | $ | 0.12 | $ | 0.60 | ||||||
WTI Cushing less WTS | 0.92 | (1.46 | ) | 0.53 | 0.02 | ||||||||||
Brent less WTI Cushing | 0.74 | 3.78 | 0.35 | 4.28 | |||||||||||
Product price (dollars per gallon): | |||||||||||||||
Gulf Coast unleaded gasoline | $ | 1.39 | $ | 1.61 | $ | 1.30 | $ | 1.66 | |||||||
Gulf Coast ultra-low sulfur diesel | 1.37 | 1.52 | 1.25 | 1.68 | |||||||||||
Natural gas (per MMBtu) | 2.79 | 2.73 | 2.34 | 2.76 |
September 30, 2016 | December 31, 2015 | ||||||
BALANCE SHEET DATA (end of period): | (dollars in thousands) | ||||||
Cash and cash equivalents | $ | 203,763 | $ | 132,953 | |||
Working capital | 10,460 | (53,804 | ) | ||||
Total assets | 825,050 | 748,584 | |||||
Total debt | 291,486 | 292,082 | |||||
Total debt less cash and cash equivalents | 87,723 | 159,129 | |||||
Total partners’ equity | 111,968 | 130,957 |
THROUGHPUT AND PRODUCTION DATA: | For the Three Months Ended | For the Nine Months Ended | |||||||||||||||||||||
September 30, | September 30, | ||||||||||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||||||||||
bpd | % | bpd | % | bpd | % | bpd | % | ||||||||||||||||
Refinery throughput: | |||||||||||||||||||||||
WTS crude | 34,292 | 48.9 | 30,810 | 40.6 | 32,189 | 46.3 | 35,041 | 47.0 | |||||||||||||||
WTI crude | 32,503 | 46.4 | 42,503 | 56.1 | 34,428 | 49.4 | 36,834 | 49.4 | |||||||||||||||
Blendstocks | 3,268 | 4.7 | 2,484 | 3.3 | 2,969 | 4.3 | 2,687 | 3.6 | |||||||||||||||
Total refinery throughput (5) | 70,063 | 100.0 | 75,797 | 100.0 | 69,586 | 100.0 | 74,562 | 100.0 | |||||||||||||||
Refinery production: | |||||||||||||||||||||||
Gasoline | 33,637 | 48.1 | 37,503 | 49.5 | 33,826 | 48.7 | 37,155 | 49.6 | |||||||||||||||
Diesel/jet | 26,004 | 37.2 | 28,623 | 37.8 | 25,108 | 36.1 | 27,596 | 36.9 | |||||||||||||||
Asphalt | 2,818 | 4.0 | 2,452 | 3.2 | 2,846 | 4.1 | 2,733 | 3.7 | |||||||||||||||
Petrochemicals | 3,861 | 5.5 | 4,588 | 6.1 | 3,611 | 5.2 | 4,770 | 6.4 | |||||||||||||||
Other | 3,661 | 5.2 | 2,595 | 3.4 | 4,084 | 5.9 | 2,510 | 3.4 | |||||||||||||||
Total refinery production (6) | 69,981 | 100.0 | 75,761 | 100.0 | 69,475 | 100.0 | 74,764 | 100.0 | |||||||||||||||
Refinery utilization (7) | 99.1 | % | 100.4 | % | 95.5 | % | 98.5 | % |
(1) | Includes sales to related parties of $82,717 and $97,014 for the three months ended and $222,711 and $281,136 for the nine months ended September 30, 2016 and 2015, respectively. |
(2) | Adjusted EBITDA represents earnings before state income tax expense, interest expense and depreciation and amortization. Adjusted EBITDA is not a recognized measurement under GAAP; however, the amounts included in Adjusted EBITDA are derived from amounts included in our consolidated financial statements. Our management believes that the presentation of Adjusted EBITDA is useful to investors because it is frequently used by securities analysts, investors, and other interested parties in the evaluation of companies in our industry. In addition, our management believes that Adjusted EBITDA is useful in evaluating our operating performance compared to that of other companies in our industry because the calculation of Adjusted EBITDA generally eliminates the effects of state income tax expense, interest expense and the accounting effects of capital expenditures and acquisitions, items that may vary for different companies for reasons unrelated to overall operating performance. |
• | Adjusted EBITDA does not reflect our cash expenditures or future requirements for capital expenditures or contractual commitments; |
• | Adjusted EBITDA does not reflect the interest expense or the cash requirements necessary to service interest or principal payments on our debt; |
• | Adjusted EBITDA does not reflect changes in or cash requirements for our working capital needs; and |
• | Our calculation of Adjusted EBITDA may differ from EBITDA calculations of other companies in our industry, limiting its usefulness as a comparative measure. |
For the Three Months Ended | For the Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(dollars in thousands) | |||||||||||||||
Net income (loss) | $ | 2,083 | $ | 53,776 | $ | (5,288 | ) | $ | 149,653 | ||||||
State income tax expense | 317 | 525 | 493 | 480 | |||||||||||
Interest expense | 8,144 | 11,505 | 28,651 | 34,045 | |||||||||||
Depreciation and amortization | 14,581 | 13,697 | 43,454 | 41,281 | |||||||||||
Adjusted EBITDA | $ | 25,125 | $ | 79,503 | $ | 67,310 | $ | 225,459 |
(3) | Refinery operating margin is a per barrel measurement calculated by dividing the margin between net sales and cost of sales (exclusive of certain inventory adjustments) by the refinery’s throughput volumes. Industry-wide refining results are driven and measured by the margins between refined product prices and the prices for crude oil, which are referred to as crack spreads. We compare our refinery operating margin to these crack spreads to assess our operating performance relative to other participants in our industry. |
(4) | Refinery direct operating expense is a per barrel measurement calculated by dividing direct operating expenses by total throughput volumes. |
(5) | Total refinery throughput represents the total barrels per day of crude and blendstock inputs in the refinery production process. |
(6) | Total refinery production represents the barrels per day of various refined products produced from processing crude and other refinery blendstocks through the crude units and other conversion units. |
(7) | Refinery utilization represents average daily crude throughput divided by crude oil capacity, excluding planned periods of downtime for maintenance and turnarounds. |
For the Nine Months Ended | |||||||
September 30, | |||||||
2016 | 2015 | ||||||
(dollars in thousands) | |||||||
Cash provided by (used in): | |||||||
Operating activities | $ | 58,457 | $ | 219,232 | |||
Investing activities | (26,878 | ) | (15,322 | ) | |||
Financing activities | 39,231 | (174,957 | ) | ||||
Net increase in cash and cash equivalents | $ | 70,810 | $ | 28,953 |
Description | Contract Volume | Wtd Avg Purchase | Wtd Avg Sales | Contract | Market | Gain | |||||||||||||||||
of Activity | (barrels) | Price/BBL | Price/BBL | Value | Value | (Loss) | |||||||||||||||||
(in thousands) | |||||||||||||||||||||||
Forwards-short (Crude) | (168,203 | ) | $ | — | $ | 45.23 | $ | (7,607 | ) | $ | (8,092 | ) | $ | (485 | ) | ||||||||
Forwards-long (Gasoline) | 268,301 | 57.19 | — | 15,344 | 16,149 | 805 | |||||||||||||||||
Forwards-short (Distillate) | (9,784 | ) | — | 61.75 | (604 | ) | (661 | ) | (57 | ) | |||||||||||||
Forwards-short (Jet) | (17,313 | ) | — | 58.12 | (1,006 | ) | (1,080 | ) | (74 | ) | |||||||||||||
Forwards-long (Slurry) | 228 | 35.40 | — | 8 | 8 | — | |||||||||||||||||
Forwards-long (Catfeed) | 23,066 | 53.56 | — | 1,235 | 1,324 | 89 | |||||||||||||||||
Forwards-long (Slop) | 34,641 | 35.23 | — | 1,220 | 1,345 | 125 | |||||||||||||||||
Forwards-short (Propane) | (50,000 | ) | — | 19.85 | (993 | ) | (1,125 | ) | (132 | ) | |||||||||||||
Forwards-long (Butane) | 75,373 | 27.70 | — | 2,088 | 2,244 | 156 | |||||||||||||||||
Futures-long (Crude) | 31,000 | 48.68 | — | 1,509 | 1,495 | (14 | ) | ||||||||||||||||
Futures-short (Gasoline) | (341,000 | ) | — | 57.55 | (19,623 | ) | (20,954 | ) | (1,331 | ) | |||||||||||||
Futures-short (Distillate) | (35,000 | ) | — | 61.33 | (2,146 | ) | (2,261 | ) | (115 | ) |
Exhibit | ||
Number | Description of Exhibit | |
31.1 | Certifications of Chief Executive Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002. | |
31.2 | Certifications of Chief Financial Officer pursuant to §302 of the Sarbanes-Oxley Act of 2002. | |
32.1 | Certifications of Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002. | |
101 | The following financial information from Alon USA Partners, LP’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2016, formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Operations, (iii) Consolidated Statements of Cash Flows and (iv) Notes to the Consolidated Financial Statements. |
Alon USA Partners, LP | |||
By: | Alon USA Partners GP, LLC | ||
its general partner | |||
Date: | October 31, 2016 | By: | /s/ David Wiessman |
David Wiessman | |||
Executive Chairman of the Board | |||
Date: | October 31, 2016 | By: | /s/ Paul Eisman |
Paul Eisman | |||
President, Chief Executive Officer and Director | |||
Date: | October 31, 2016 | By: | /s/ Shai Even |
Shai Even | |||
Senior Vice President and Chief Financial Officer | |||
(Principal Accounting Officer) |
1. | I have reviewed this Quarterly Report on Form 10-Q of Alon USA Partners, LP; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b) | Designed such internal control over financial reporting, or caused such internal controls over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c) | Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d) | Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and |
5. | The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions): |
a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and |
b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting. |
Date: | October 31, 2016 | By: | /s/ Paul Eisman |
Paul Eisman | |||
President, Chief Executive Officer and Director of Alon USA Partners GP, LLC | |||
(the general partner of Alon USA Partners, LP) |
1. | I have reviewed this Quarterly Report on Form 10-Q of Alon USA Partners, LP; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b) | Designed such internal control over financial reporting, or caused such internal controls over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c) | Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d) | Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and |
5. | The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions): |
a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and |
b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting. |
Date: | October 31, 2016 | By: | /s/ Shai Even |
Shai Even | |||
Senior Vice President and Chief Financial Officer of Alon USA Partners GP, LLC | |||
(the general partner of Alon USA Partners, LP) |
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 Partnership as of the dates and for the periods expressed in the Report. |
Date: | October 31, 2016 | By: | /s/ Paul Eisman |
Paul Eisman | |||
President, Chief Executive Officer and Director of Alon USA Partners GP, LLC | |||
(the general partner of Alon USA Partners, LP) | |||
Date: | October 31, 2016 | By: | /s/ Shai Even |
Shai Even | |||
Senior Vice President and Chief Financial Officer of Alon USA Partners GP, LLC | |||
(the general partner of Alon USA Partners, LP) |
Document and Entity Information Document - shares |
9 Months Ended | |
---|---|---|
Sep. 30, 2016 |
Oct. 24, 2016 |
|
Document Information | ||
Entity Registrant Name | Alon USA Partners, LP | |
Entity Central Index Key | 0001556766 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Accelerated Filer | |
Document Type | 10-Q | |
Document Period End Date | Sep. 30, 2016 | |
Document Fiscal Year Focus | 2016 | |
Document Fiscal Period Focus | Q3 | |
Amendment Flag | false | |
Entity Common Stock, Shares Outstanding | 62,520,220 |
Consolidated Balance Sheets Parentheticals - shares |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Common units, shares issued | 62,520,220 | 62,510,039 |
Common units, shares outstanding | 62,520,220 | 62,510,039 |
Consolidated Statements of Operations (unaudited) - USD ($) shares in Thousands, $ in Thousands |
3 Months Ended | 9 Months Ended | ||||
---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|||
Net sales | [1] | $ 462,257 | $ 551,813 | $ 1,298,723 | $ 1,719,319 | |
Operating costs and expenses: | ||||||
Cost of sales | 404,207 | 439,678 | 1,134,275 | 1,397,395 | ||
Direct operating expenses | 25,125 | 24,136 | 73,424 | 71,837 | ||
Selling, general and administrative expenses | 8,153 | 8,536 | 24,264 | 24,654 | ||
Depreciation and amortization | 14,581 | 13,697 | 43,454 | 41,281 | ||
Total operating costs and expenses | 452,066 | 486,047 | 1,275,417 | 1,535,167 | ||
Operating income | 10,191 | 65,766 | 23,306 | 184,152 | ||
Interest expense | (8,144) | (11,505) | (28,651) | (34,045) | ||
Other income, net | 353 | 40 | 550 | 26 | ||
Income (loss) before state income tax expense | 2,400 | 54,301 | (4,795) | 150,133 | ||
State income tax expense | 317 | 525 | 493 | 480 | ||
Net income (loss) | $ 2,083 | $ 53,776 | $ (5,288) | $ 149,653 | ||
Earnings (loss) per unit | $ 0.03 | $ 0.86 | $ (0.08) | $ 2.39 | ||
Weighted average common units outstanding (in thousands) | 62,520 | 62,510 | 62,515 | 62,508 | ||
Cash distribution per unit | $ 0.14 | $ 1.04 | $ 0.22 | $ 2.45 | ||
|
Consolidated Statements of Operations Parentheticals - USD ($) $ in Thousands |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|
Statements of Operations Parentheticals [Abstract] | ||||
Sales to related parties | $ 82,717 | $ 97,014 | $ 222,711 | $ 281,136 |
Basis of Presentation |
9 Months Ended |
---|---|
Sep. 30, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Basis of Presentation | Basis of Presentation As used in this report, the terms “Alon,” the “Partnership,” “we,” “our” and “us” or like terms refer to Alon USA Partners, LP, and its consolidated subsidiaries or to Alon USA Partners, LP or an individual subsidiary. References in this report to “Alon Energy” refer collectively to Alon USA Energy, Inc. and any of its consolidated subsidiaries, other than Alon USA Partners, LP, its subsidiaries and its general partner. We are a Delaware limited partnership formed in August 2012 by Alon Energy and its wholly-owned subsidiary Alon USA Partners GP, LLC (the “General Partner”), which owns 100% of our non-economic general partner interest. These consolidated financial statements and notes are unaudited and 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 the General Partner’s management, the information included in these consolidated financial statements reflects all adjustments, consisting of normal and recurring adjustments, which are necessary for a fair presentation of our consolidated financial position and results of operations for the interim periods presented. All significant intercompany balances and transactions have been eliminated in consolidation. Certain prior year balances may have been aggregated or disaggregated in order to conform to the current year presentation. Our results of operations for the three and nine months ended September 30, 2016 are not necessarily indicative of the operating results that may be realized for the year ending December 31, 2016. Our consolidated balance sheet as of December 31, 2015 has been derived from the audited financial statements as of that date. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015. New Accounting Standards In May 2014, the Financial Accounting Standards Board (“FASB”) and the International Accounting Standards Board jointly issued a comprehensive new revenue recognition standard that provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. This standard is intended to improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets. The standard allows for either full retrospective adoption or modified retrospective adoption. In August 2015, the FASB updated the guidance to include a one-year deferral of the effective date for the new revenue standard, making the requirements of the standard effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted for interim and annual periods beginning after December 15, 2016. We are evaluating the guidance to determine the method of adoption and the impact this standard will have on our consolidated financial statements. In July 2015, the FASB issued an accounting standards update simplifying the measurement of certain inventory. This updated standard simplifies the measurement of inventory by requiring certain inventory to be measured at the lower of cost or net realizable value. The amendments in this accounting standards update are effective for interim and annual periods beginning after December 15, 2016. This accounting standards update does not apply to the subsequent measurement of inventory measured using the last-in, first-out (“LIFO”) or retail inventory method, therefore the adoption of this guidance will not have a material effect on our financial position or results of operations. In February 2016, the FASB issued new guidance on the accounting for leases, which requires lessees to recognize assets and liabilities on the balance sheet for the present value of the rights and obligations created by all leases with terms of more than 12 months. The ASU also will require disclosures designed to give financial statement users information on the amount, timing, and uncertainty of cash flows arising from leases. The requirements from this guidance are effective for interim and annual periods beginning after December 31, 2018. We are evaluating the guidance to determine the impact this standard will have on our consolidated financial statements. In June 2016, the FASB issued an accounting standards update requiring the measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. Financial institutions and other organizations will now use forward-looking information to better inform their credit loss estimates. The requirements from the updated standard are effective for interim and annual periods beginning after December 15, 2019. We are evaluating the guidance to determine the impact this standard will have on our consolidated financial statements. In August 2016, the FASB issued an accounting standards update addressing eight specific cash flow issues with the objective of eliminating the existing diversity in practice. The amendments from this update are effective for interim and annual periods beginning after December 15, 2017. We do not expect application of this standard to have a material effect on our consolidated financial statements. |
Fair Value |
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Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures | Fair Value We determine fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. We classify financial assets and financial liabilities into the following fair value hierarchy:
As required, we utilize valuation techniques that maximize the use of observable inputs (levels 1 and 2) and minimize the use of unobservable inputs (level 3) within the fair value hierarchy. We generally apply the “market approach” to determine fair value. This method uses pricing and other information generated by market transactions for identical or comparable assets and liabilities. Assets and liabilities are classified within the fair value hierarchy based on the lowest level (least observable) input that is significant to the measurement in its entirety. The carrying amounts of our cash and cash equivalents, receivables, payables and accrued liabilities approximate fair value due to the short-term maturities of these assets and liabilities. The reported amounts of long-term debt approximate fair value. Derivative instruments are carried at fair value, which are based on quoted market prices. Derivative instruments are our only assets and liabilities measured at fair value on a recurring basis. The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, in the consolidated balance sheets at September 30, 2016 and December 31, 2015:
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Derivative Financial Instruments |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Instruments and Hedging Activities Disclosure | Derivative Financial Instruments We selectively utilize crude oil and refined product commodity derivative contracts to reduce the risk associated with potential price changes on committed obligations as well as to reduce earnings volatility. We do not speculate using derivative instruments. Credit risk on our derivative instruments is mitigated by transacting with counterparties meeting established collateral and credit criteria. Mark to Market We have certain contracts that serve as economic hedges, which are derivatives used for risk management but not designated as hedges for financial accounting purposes. All economic hedge transactions are recorded at fair value and any changes in fair value between periods are recognized in earnings. We have contracts that are used to fix prices on forecasted purchases of inventory, which we refer to as futures and forwards. Futures represent trades executed on the New York Mercantile Exchange which have not been closed or settled at the end of the reporting period. Forwards represent physical trades for which pricing and quantities have been set, but the physical product delivery has not occurred by the end of the reporting period. Fair Value Hedge Fair value hedges are used to hedge price volatility of certain refining inventories and firm commitments to purchase inventories. The gain or loss on a derivative instrument designated and qualifying as a fair value hedge, as well as the offsetting gain or loss on the hedged item attributable to the hedged risk, is recognized in earnings in the same period. We have certain commodity contracts associated with the Supply and Offtake Agreement discussed in Note 5 that have been accounted for as a fair value hedge, which had purchase volumes of 135 thousand barrels of crude oil as of September 30, 2016. The following tables present the effect of derivative instruments on the consolidated balance sheets:
The following tables present the effect of derivative instruments on the consolidated statements of operations: Derivatives in fair value hedging relationships:
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Derivatives not designated as hedging instruments:
Offsetting Assets and Liabilities Our derivative instruments are subject to master netting arrangements to manage counterparty credit risk associated with derivatives, and we offset the fair value amounts recorded for derivative instruments to the extent possible under these agreements on our consolidated balance sheets. The following table presents offsetting information regarding our derivatives by type of transaction as of September 30, 2016 and December 31, 2015:
Compliance Program Market Risk We are obligated by government regulations to blend a certain percentage of biofuels into the products that we produce and are consumed in the U.S. We purchase biofuels from third parties and blend those biofuels into our products, and each gallon of biofuel purchased includes a renewable identification number, or RIN. To the degree we are unable to blend biofuels at the required percentage, a RINs deficit is generated and we must acquire that number of RINs by the annual reporting deadline in order to remain in compliance with applicable regulations. Alternatively, if we have a RINs surplus, some of those RINs could be sold. Any such sales would be subject to our normal credit evaluation process. We are exposed to market risk related to the volatility in the price of credits needed to comply with these governmental and regulatory programs. We manage this risk by purchasing RINs when prices are deemed favorable utilizing fixed price purchase contracts. We may also sell the RINs with an agreement to repurchase in the future. Some of these contracts are derivative instruments; however, we elect the normal purchase and sale exception and do not record these contracts at their fair values. The cost of meeting our obligations under these compliance programs was $3,712 and $1,868 for the three months ended and $6,620 and $8,369 for the nine months ended September 30, 2016 and 2015, respectively. These amounts are reflected in cost of sales in the consolidated statements of operations. |
Inventories |
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Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure | Inventories Carrying value of inventories consisted of the following:
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At September 30, 2016 and December 31, 2015, the market value of refined products and blendstock inventories was less than inventories on a LIFO cost basis which resulted in recording a lower of cost or market reserve of $7,350 and $9,396, respectively. At September 30, 2016 and December 31, 2015, the market value of crude oil inventories exceeded LIFO costs, net of the fair value hedged item, by $3,937 and $6,387, respectively. |
Inventory Financing Agreement |
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Sep. 30, 2016 | |
Inventory Financing Agreement Disclosure [Abstract] | |
Inventory Financing Agreement | Inventory Financing Agreement We have entered into a Supply and Offtake Agreement and other associated agreements (together the “Supply and Offtake Agreement”) with J. Aron & Company (“J. Aron”). Pursuant to the Supply and Offtake Agreement, (i) J. Aron agreed to sell to us, and we agreed to buy from J. Aron, at market prices, crude oil for processing at the Big Spring refinery and (ii) we agreed to sell, and J. Aron agreed to buy, at market prices, certain refined products produced at the Big Spring refinery. The Supply and Offtake Agreement also provided for the sale, at market prices, of our crude oil and certain refined product inventories to J. Aron, the lease to J. Aron of crude oil and refined product storage facilities, and to identify prospective purchasers of refined products on J. Aron’s behalf. The Supply and Offtake Agreement has an initial term that expires in May 2021. J. Aron may elect to terminate the Supply and Offtake Agreement prior to the expiration of the initial term beginning in May 2018 and upon each anniversary thereof, on six months prior notice. We may elect to terminate in May 2020 on six months prior notice. Following expiration or termination of the Supply and Offtake Agreement, we are obligated to purchase the crude oil and refined product inventories then owned by J. Aron and located at the Big Spring refinery at then current market prices. Associated with the Supply and Offtake Agreement, we have a fair value hedge of our inventory purchase commitment with J. Aron and crude oil inventory consigned to J. Aron (“crude oil consignment inventory”). Additionally, financing charges related to the Supply and Offtake Agreement are recorded as interest expense in the consolidated statements of operations. At September 30, 2016 and December 31, 2015, we had net current payables of $18,455 and net current receivables of $4,975, respectively, with J. Aron for purchases and sales, and a consignment inventory receivable representing a deposit paid to J. Aron of $6,290 and $6,290, respectively. At September 30, 2016 and December 31, 2015, we had non-current liabilities for the original financing of $7,203 and $9,761, respectively, net of the related fair value hedge. Additionally, we had net current receivables of $427 and net current payables $99 at September 30, 2016 and December 31, 2015, respectively, for forward commitments related to month-end consignment inventory target levels differing from projected levels and the associated pricing with these inventory level differences. |
Property, Plant and Equipment, Net |
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Property, Plant and Equipment, Net [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment, Net | Property, Plant and Equipment, Net Property, plant and equipment, net consisted of the following:
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Additional Financial Information |
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Additional Financial Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional Financial Information | Additional Financial Information The following tables provide additional financial information related to the consolidated financial statements.
Included in accounts payable was $123,844 and $91,179 related to RINs financing transactions as of September 30, 2016 and December 31, 2015, respectively.
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Indebtedness |
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Debt Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt Disclosure | Indebtedness Debt consisted of the following:
Outstanding letters of credit under the revolving credit facility were $91,225 and $48,590 at September 30, 2016 and December 31, 2015, respectively. The revolving credit facility contains maintenance financial covenants. At September 30, 2016, we were in compliance with these covenants. |
Partners' Equity |
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Partners' Capital Notes Disclosure | Partners' Equity (unit values in dollars) Cash Distributions We have adopted a policy pursuant to which we will distribute all of the available cash generated each quarter, as defined in the partnership agreement, subject to the approval of the board of directors of the General Partner. The per unit amount of available cash to be distributed each quarter, if any, will be distributed within 60 days following the end of such quarter. The following table summarizes the Partnership’s cash distribution activity during the period:
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Restricted Units Non-employee directors of the General Partner are awarded an annual grant of $25 in restricted units, which vest over a period of three years, assuming continued service at vesting. In May 2016, we granted awards of 7,653 restricted common units at a grant date price of $9.80 per unit. In June 2016, we granted awards of 2,528 restricted common units at a grant date price of $9.89 per unit. |
Related Party Transactions |
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Sep. 30, 2016 | |||||||||||||
Related Party Transactions [Abstract] | |||||||||||||
Related Party Transactions | Related Party Transactions Sales and Receivables Sales to related parties include motor fuels and asphalt sold to other Alon Energy subsidiaries at prices substantially determined by reference to market commodity pricing information. These sales are included in net sales in the consolidated statements of operations. Accounts receivable from related parties includes sales of motor fuels and is shown separately on the consolidated balance sheets. Costs Allocated from Alon Energy The Partnership is a subsidiary of Alon Energy and is operated as a component of the integrated operations of Alon Energy. As such, the executive officers of Alon Energy, who are employed by another subsidiary of Alon Energy, also serve as executive officers of the General Partner and Alon Energy’s other subsidiaries.
Alon Energy performs general corporate and administrative services and functions for us and their other subsidiaries, which include accounting, treasury, cash management, tax, information technology, insurance administration and claims processing, legal, environmental, risk management, audit, payroll and employee benefit processing and internal audit services. Alon Energy allocates the expenses actually incurred in performing these services to the Partnership based primarily on the estimated amount of time the individuals performing such services devote to our business and affairs relative to the amount of time they devote to the business and affairs of Alon Energy’s other subsidiaries. The management of Alon Energy and the General Partner consider these allocations to be reasonable. We record the amount of such allocations as selling, general and administrative expenses. Our allocation for selling, general and administrative expenses were $3,301 and $2,969 for the three months ended and $10,966 and $8,941 for the nine months ended September 30, 2016 and 2015, respectively.
As we are operated as a component of Alon Energy’s integrated operations, we have no employees. As a result, employee expense costs for Alon Energy employees working in our operations have been allocated to us and recorded as payroll expense in direct operating and selling, general and administrative expenses. The allocated portion of Alon Energy’s employee expense costs included in direct operating expenses were $7,391 and $6,848 for the three months ended and $21,723 and $19,872 for the nine months ended September 30, 2016 and 2015, respectively. The allocated portion of Alon Energy’s employee expense costs included in selling, general and administrative expenses were $1,178 and $997 for the three months ended and $3,413 and $4,103 for the nine months ended September 30, 2016 and 2015, respectively.
Insurance costs related to the Big Spring refinery and wholesale marketing operations are allocated to us by Alon Energy based on estimated insurance premiums on a stand-alone basis relative to Alon Energy’s total insurance premium. Our allocation for insurance costs included in direct operating expenses were $1,507 and $1,782 for the three months ended and $3,879 and $5,103 for the nine months ended September 30, 2016 and 2015, respectively. Leasing Agreements In June 2014, we entered into six-year lease agreements with a subsidiary of Alon Energy to lease equipment at the Big Spring refinery. The lease agreements were effective July 1, 2014 and require fixed monthly payments amounting to $4,920 annually. Related to these agreements, we recorded selling, general and administrative expense of $1,230 for the three months ended September 30, 2016 and 2015 and $3,690 for the nine months ended September 30, 2016 and 2015. Transactions with Delek US Holdings, Inc. In May 2015, Delek US Holdings, Inc. (“Delek”) completed the purchase of approximately 48% of Alon Energy’s outstanding common stock from Alon Israel Oil Company, Ltd. We have transactions with Delek that occur in the ordinary course of business. Including amounts prior to the transaction, we purchased refined products from Delek of $175 and $5,192 for the three months ended September 30, 2016 and 2015, respectively, and $960 and $7,592 for the nine months ended September 30, 2016 and 2015, respectively. Distributions During the nine months ended September 30, 2016, we paid cash distributions of $13,754, or $0.22 per unit, of which $11,220 was paid to Alon Energy. During the nine months ended September 30, 2015, we paid cash distributions of $153,145, or $2.45 per unit, of which $124,950 was paid to Alon Energy. |
Commitments and Contingencies |
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Commitments and Contingencies Disclosure [Abstract] | |||||||||||||
Commitments and Contingencies Disclosure | Commitments and Contingencies
In the normal course of business, we have long-term commitments to purchase, at market prices, utilities such as natural gas, electricity and water for use by our refinery, terminals and pipelines. We are also party to various refined product and crude oil supply and exchange agreements, which are typically short-term in nature or provide terms for cancellation.
We are involved in various legal actions arising in the ordinary course of business. We believe the ultimate disposition of these matters will not have a material effect on our financial position, results of operations or liquidity.
We are subject to loss contingencies pursuant to federal, state, and local environmental laws and regulations. These laws and regulations govern the discharge of materials into the environment and may require us to incur future obligations to investigate the effects of the release or disposal of certain petroleum, chemical, and mineral substances at various sites; to remediate or restore these sites and to compensate others for damage to property and natural resources. These contingent obligations relate to sites owned by the Partnership and are associated with past or present operations. We are currently participating in environmental investigations, assessments and cleanups pertaining to the refinery, pipelines and terminals. We may be involved in additional future environmental investigations, assessments and cleanups. The magnitude of future costs are unknown and will depend on factors such as the nature and contamination at many sites, the timing, extent and method of the remedial actions which may be required, and the determination of our liability in proportion to other responsible parties. Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefit are expensed. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment and/or remediation is probable, and the costs can be reasonably estimated. Substantially all amounts accrued are expected to be paid out over the next 15 years. The level of future expenditures for environmental remediation obligations cannot be determined with any degree of reliability. We have accrued environmental remediation obligations of $6,438 ($1,716 current liability and $4,722 non-current liability) at September 30, 2016, and $6,441 ($1,716 accrued liability and $4,725 non-current liability) at December 31, 2015. |
Subsequent Event |
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Sep. 30, 2016 | |
Subsequent Events [Abstract] | |
Subsequent Event | Subsequent Event Distribution Declared On October 26, 2016, the board of directors of the General Partner declared a cash distribution to our common unitholders of approximately $9,378, or $0.15 per common unit. The cash distribution will be paid on November 22, 2016 to unitholders of record at the close of business on November 11, 2016. |
Basis of Presentation (Policies) |
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Sep. 30, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
New Accounting Pronouncements, Policy | New Accounting Standards In May 2014, the Financial Accounting Standards Board (“FASB”) and the International Accounting Standards Board jointly issued a comprehensive new revenue recognition standard that provides accounting guidance for all revenue arising from contracts to provide goods or services to customers. This standard is intended to improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets. The standard allows for either full retrospective adoption or modified retrospective adoption. In August 2015, the FASB updated the guidance to include a one-year deferral of the effective date for the new revenue standard, making the requirements of the standard effective for interim and annual periods beginning after December 15, 2017, with early adoption permitted for interim and annual periods beginning after December 15, 2016. We are evaluating the guidance to determine the method of adoption and the impact this standard will have on our consolidated financial statements. In July 2015, the FASB issued an accounting standards update simplifying the measurement of certain inventory. This updated standard simplifies the measurement of inventory by requiring certain inventory to be measured at the lower of cost or net realizable value. The amendments in this accounting standards update are effective for interim and annual periods beginning after December 15, 2016. This accounting standards update does not apply to the subsequent measurement of inventory measured using the last-in, first-out (“LIFO”) or retail inventory method, therefore the adoption of this guidance will not have a material effect on our financial position or results of operations. In February 2016, the FASB issued new guidance on the accounting for leases, which requires lessees to recognize assets and liabilities on the balance sheet for the present value of the rights and obligations created by all leases with terms of more than 12 months. The ASU also will require disclosures designed to give financial statement users information on the amount, timing, and uncertainty of cash flows arising from leases. The requirements from this guidance are effective for interim and annual periods beginning after December 31, 2018. We are evaluating the guidance to determine the impact this standard will have on our consolidated financial statements. In June 2016, the FASB issued an accounting standards update requiring the measurement of all expected credit losses for financial assets held at the reporting date based on historical experience, current conditions, and reasonable and supportable forecasts. Financial institutions and other organizations will now use forward-looking information to better inform their credit loss estimates. The requirements from the updated standard are effective for interim and annual periods beginning after December 15, 2019. We are evaluating the guidance to determine the impact this standard will have on our consolidated financial statements. In August 2016, the FASB issued an accounting standards update addressing eight specific cash flow issues with the objective of eliminating the existing diversity in practice. The amendments from this update are effective for interim and annual periods beginning after December 15, 2017. We do not expect application of this standard to have a material effect on our consolidated financial statements. |
Fair Value (Tables) |
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Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis | The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, in the consolidated balance sheets at September 30, 2016 and December 31, 2015:
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Derivative Financial Instruments (Tables) |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value | The following tables present the effect of derivative instruments on the consolidated balance sheets:
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Schedule of Fair Value Hedging Instruments, Statements of Financial Performance and Financial Position, Location | The following tables present the effect of derivative instruments on the consolidated statements of operations: Derivatives in fair value hedging relationships:
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Schedule of Derivative Instruments, Gain (Loss) in Statement of Financial Performance | Derivatives not designated as hedging instruments:
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Offsetting Assets | The following table presents offsetting information regarding our derivatives by type of transaction as of September 30, 2016 and December 31, 2015:
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Offsetting Liabilities | The following table presents offsetting information regarding our derivatives by type of transaction as of September 30, 2016 and December 31, 2015:
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Inventories (Tables) |
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Sep. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Inventory | Carrying value of inventories consisted of the following:
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Property, Plant and Equipment, Net (Tables) |
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Sep. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment, Net [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment, Net | Property, plant and equipment, net consisted of the following:
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Additional Financial Information (Tables) |
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Additional Financial Information [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Other Assets | Other Assets, Net
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Schedule of Accrued Liabilities and Other Non-Current Liabilities | Accrued Liabilities and Other Non-Current Liabilities
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Indebtedness (Tables) |
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt Instruments [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Debt | Debt consisted of the following:
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Partners' Equity (Tables) |
9 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Sep. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distributions Made to Members or Limited Partners | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distributions Made to Limited Partner, by Distribution | The following table summarizes the Partnership’s cash distribution activity during the period:
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Fair Value (Details) - Fair Value, Measurements, Recurring - Forward Contracts - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Commodity Contracts | ||
Liabilities: | ||
Derivative Liabilities | $ 1,033 | $ 40 |
Fair Value Hedge | ||
Assets: | ||
Derivative Assets | 5,569 | 11,564 |
Level 1 | Commodity Contracts | ||
Liabilities: | ||
Derivative Liabilities | 1,033 | 40 |
Level 1 | Fair Value Hedge | ||
Assets: | ||
Derivative Assets | 0 | 0 |
Level 2 | Commodity Contracts | ||
Liabilities: | ||
Derivative Liabilities | 0 | 0 |
Level 2 | Fair Value Hedge | ||
Assets: | ||
Derivative Assets | 5,569 | 11,564 |
Level 3 | Commodity Contracts | ||
Liabilities: | ||
Derivative Liabilities | 0 | 0 |
Level 3 | Fair Value Hedge | ||
Assets: | ||
Derivative Assets | $ 0 | $ 0 |
Schedule of Fair Value Hedging Instruments (Details) - Designated as Hedging Instrument - USD ($) $ in Thousands |
3 Months Ended | 9 Months Ended | ||||
---|---|---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
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Derivative Instruments, Gain (Loss) | ||||||
Gain (Loss) on Fair Value Hedges Recognized in Earnings | $ (1,772) | $ 5,990 | $ (5,995) | $ 4,495 | ||
Interest Expense | Forward Contracts | Fair Value Hedge | ||||||
Derivative Instruments, Gain (Loss) | ||||||
Gain (Loss) on Fair Value Hedges Recognized in Earnings | [1] | $ (1,772) | $ 5,990 | $ (5,995) | $ 4,495 | |
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Schedule of Derivative Instruments, Gain (Loss) in Statements of Financial Performance (Details) - Not Designated as Hedging Instrument - USD ($) $ in Thousands |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
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Derivative Instruments, Gain (Loss) | ||||
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | $ (1,199) | $ 1,251 | $ 4,998 | $ 622 |
Cost of Sales | Forward Contracts | Commodity Contracts | ||||
Derivative Instruments, Gain (Loss) | ||||
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | $ (1,199) | $ 1,251 | $ 4,998 | $ 622 |
Derivative Financial Instruments Textuals (Details) bbl in Thousands, $ in Thousands |
3 Months Ended | 9 Months Ended | ||
---|---|---|---|---|
Sep. 30, 2016
USD ($)
bbl
|
Sep. 30, 2015
USD ($)
|
Sep. 30, 2016
USD ($)
bbl
|
Sep. 30, 2015
USD ($)
|
|
Derivative | ||||
Compliance Program Costs | $ | $ 3,712 | $ 1,868 | $ 6,620 | $ 8,369 |
Forward Contracts | Fair Value Hedge | ||||
Derivative | ||||
Notional Amount of Fair Value Hedge Instruments | bbl | 135 | 135 |
Inventories (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
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---|---|---|---|---|---|
Inventory Disclosure [Abstract] | |||||
Crude oil, refined products and blendstocks | $ 39,909 | $ 24,548 | |||
Crude oil consignment inventory (Note 5) (1) | 838 | (95) | [1] | ||
Materials and supplies | 11,143 | 10,991 | |||
Total inventories | $ 51,890 | $ 35,444 | |||
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Inventories Textuals (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Inventory Disclosure [Abstract] | ||
Inventory lower of cost or market reserve | $ 7,350 | $ 9,396 |
Excess of replacement or current costs over stated LIFO value, net of the fair value hedged item | $ 3,937 | $ 6,387 |
Inventory Financing Agreement Textuals (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Accounts payable, net, current | $ 292,542 | $ 253,325 |
Receivable from supply and offtake agreement | 6,290 | 6,290 |
Derivative liabilities | 1,460 | 99 |
Consigned inventory | Forward Contracts | ||
Derivative assets | 427 | |
Derivative liabilities | 99 | |
J.Aron | ||
Accounts payable, net, current | 18,455 | |
Accounts receivable, net, current | 4,975 | |
Receivable from supply and offtake agreement | 6,290 | 6,290 |
Non-current liability for consignment inventory | $ 7,203 | $ 9,761 |
Property, Plant and Equipment, Net (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Property, Plant and Equipment, Net | ||
Refining facilities | $ 725,905 | $ 709,779 |
Accumulated depreciation | (302,718) | (275,160) |
Property, plant and equipment, net | $ 423,187 | $ 434,619 |
Other Assets (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Other Assets [Abstract] | ||
Deferred turnaround and catalyst cost | $ 38,199 | $ 43,021 |
Receivable from supply and offtake agreement (Note 5) | 6,290 | 6,290 |
Fair value hedge of consigned inventory (Note 3) | 5,569 | 11,564 |
Other | 9,344 | 10,362 |
Total other assets | $ 59,402 | $ 71,237 |
Additional Financial Information Accounts Payable Textuals (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Accounts Payable [Abstract] | ||
Accounts payable, RINs financing transactions | $ 123,844 | $ 91,179 |
Accrued Liabilities and Other Non-Current Liabilities (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Accrued Liabilities: | ||
Taxes other than income taxes, primarily excise taxes | $ 25,186 | $ 25,018 |
Accrued finance charges | 293 | 394 |
Environmental accrual (Note 11) | 1,716 | 1,716 |
Commodity contracts | 1,460 | 99 |
Other | 8,304 | 13,480 |
Total accrued liabilities | 36,959 | 40,707 |
Other Non-Current Liabilities: | ||
Consignment inventory obligation (Note 5) | 12,772 | 21,325 |
Environmental accrual (Note 11) | 4,722 | 4,725 |
Asset retirement obligations | 3,086 | 2,927 |
RINs financing transactions | 68,978 | 0 |
Other | 2,537 | 2,536 |
Total other non-current liabilities | $ 92,095 | $ 31,513 |
Indebtedness (Details) - USD ($) $ in Thousands |
Sep. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Debt Instrument | ||
Total debt | $ 291,486 | $ 292,082 |
Less: Current portion | 2,500 | 2,500 |
Total long-term debt | 288,986 | 289,582 |
Term loan credit facility | ||
Debt Instrument | ||
Total debt | 236,486 | 237,082 |
Revolving credit facility | ||
Debt Instrument | ||
Total debt | $ 55,000 | $ 55,000 |
Indebtedness Textuals (Details) - USD ($) $ in Thousands |
9 Months Ended | |
---|---|---|
Sep. 30, 2016 |
Dec. 31, 2015 |
|
Debt Instrument | ||
Letters of credit outstanding, amount | $ 91,225 | $ 48,590 |
Debt instrument, covenant compliance | we were in compliance with these covenants |
Partners' Equity (Details) - USD ($) $ / shares in Units, $ in Thousands |
3 Months Ended | 9 Months Ended | ||||||
---|---|---|---|---|---|---|---|---|
Sep. 30, 2016 |
Jun. 30, 2016 |
Mar. 31, 2016 |
Sep. 30, 2015 |
Sep. 30, 2016 |
Sep. 30, 2015 |
|||
Distribution Made to Limited Partner | ||||||||
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ 0.14 | $ 1.04 | $ 0.22 | $ 2.45 | ||||
Cash Distribution | ||||||||
Distribution Made to Limited Partner | ||||||||
Cash Available for Distributions, Per Unit | [1] | 0.15 | $ 0.14 | $ 0 | ||||
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ 0.14 | $ 0 | $ 0.08 | |||||
Distribution Made to Limited Partner, Cash Distributions Paid | $ 8,753 | $ 0 | $ 5,001 | |||||
|
Partners' Equity Restricted Units (Details) - Restricted Stock - $ / shares |
1 Months Ended | 9 Months Ended | |
---|---|---|---|
Jun. 30, 2016 |
May 31, 2016 |
Sep. 30, 2016 |
|
Share-based Compensation Arrangement by Share-based Payment Award | |||
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period | 3 years | ||
Stock Issued During Period, Shares, Restricted Stock Award, Gross | 2,528 | 7,653 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value | $ 9.89 | $ 9.80 |
Remediation Obligations (Details) - USD ($) $ in Thousands |
9 Months Ended | |
---|---|---|
Sep. 30, 2016 |
Dec. 31, 2015 |
|
Commitments and Contingencies Disclosure [Abstract] | ||
Site Contingency, Time Frame of Disbursements | 15 years | |
Accrual for Environmental Loss Contingencies | $ 6,438 | $ 6,441 |
Accrued Environmental Loss Contingencies, Current | 1,716 | 1,716 |
Accrued Environmental Loss Contingencies, Noncurrent | $ 4,722 | $ 4,725 |
Subsequent Event (Details) - Cash Distribution - Subsequent Event $ / shares in Units, $ in Thousands |
Oct. 26, 2016
USD ($)
$ / shares
|
---|---|
Subsequent Event | |
Distribution Made to Limited Partner, Cash Distributions Declared | $ | $ 9,378 |
Distribution Made to Limited Partner, Distributions Declared, Per Unit | $ / shares | $ 0.15 |
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