(Mark One) | |
þ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended March 31, 2016 | |
OR | |
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from to . |
Delaware | 37-1702463 |
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) |
2277 Plaza Drive, Suite 500 | |
Sugar Land, Texas (Address of principal executive offices) | 77479 (Zip Code) |
Large accelerated filer þ | Accelerated filer o | Non-accelerated filer o | Smaller reporting company o | |||
(Do not check if smaller reporting company.) |
Page No. | ||
March 31, 2016 | December 31, 2015 | ||||||
(unaudited) | |||||||
(in millions, except unit data) | |||||||
ASSETS | |||||||
Current assets: | |||||||
Cash and cash equivalents | $ | 145.9 | $ | 187.3 | |||
Accounts receivable, net of allowance for doubtful accounts of $0.3 and $0.3, including $0.1 and $0.3 due from affiliates at March 31, 2016 and December 31, 2015, respectively | 100.7 | 88.9 | |||||
Inventories | 226.8 | 252.5 | |||||
Prepaid expenses and other current assets, including $0.8 and $2.0 due from affiliates at March 31, 2016 and December 31, 2015, respectively | 74.2 | 100.3 | |||||
Total current assets | 547.6 | 629.0 | |||||
Property, plant and equipment, net of accumulated depreciation | 1,559.8 | 1,549.5 | |||||
Other long-term assets | 9.5 | 10.5 | |||||
Total assets | $ | 2,116.9 | $ | 2,189.0 | |||
LIABILITIES AND PARTNERS' CAPITAL | |||||||
Current liabilities: | |||||||
Note payable and capital lease obligations | $ | 1.7 | $ | 1.6 | |||
Accounts payable, including $4.8 and $5.4 due to affiliates at March 31, 2016 and December 31, 2015, respectively | 240.9 | 254.3 | |||||
Personnel accruals, including $2.1 and $4.0 due to affiliates at March 31, 2016 and December 31, 2015, respectively | 12.0 | 21.7 | |||||
Accrued taxes other than income taxes | 24.5 | 22.1 | |||||
Accrued expenses and other current liabilities, including $3.9 and $9.8 due to affiliates at March 31, 2016 and December 31, 2015, respectively | 48.6 | 31.8 | |||||
Total current liabilities | 327.7 | 331.5 | |||||
Long-term liabilities: | |||||||
Long-term debt and capital lease obligations, net of current portion, including $31.5 due to affiliates at March 31, 2016 and December 31, 2015 | 571.9 | 572.2 | |||||
Other long-term liabilities, including $0.7 and $0.8 due to affiliates at March 31, 2016 and December 31, 2015, respectively | 3.9 | 3.9 | |||||
Total long-term liabilities | 575.8 | 576.1 | |||||
Commitments and contingencies | |||||||
Partners' capital: | |||||||
Common unitholders, 147,600,000 units issued and outstanding at March 31, 2016 and December 31, 2015 | 1,213.4 | 1,281.4 | |||||
General partner interest | — | — | |||||
Total partners' capital | 1,213.4 | 1,281.4 | |||||
Total liabilities and partners' capital | $ | 2,116.9 | $ | 2,189.0 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(unaudited) | |||||||
(in millions, except per unit data) | |||||||
Net sales | $ | 834.0 | $ | 1,304.4 | |||
Operating costs and expenses: | |||||||
Cost of product sold (exclusive of depreciation and amortization) | 722.3 | 1,056.1 | |||||
Direct operating expenses (exclusive of depreciation and amortization) | 117.7 | 87.0 | |||||
Selling, general and administrative expenses (exclusive of depreciation and amortization) | 18.5 | 18.1 | |||||
Depreciation and amortization | 31.5 | 34.0 | |||||
Total operating costs and expenses | 890.0 | 1,195.2 | |||||
Operating income (loss) | (56.0 | ) | 109.2 | ||||
Other income (expense): | |||||||
Interest expense and other financing costs | (10.8 | ) | (11.3 | ) | |||
Interest income | — | 0.1 | |||||
Loss on derivatives, net | (1.2 | ) | (51.4 | ) | |||
Other income, net | — | 0.1 | |||||
Total other expense | (12.0 | ) | (62.5 | ) | |||
Income (loss) before income tax expense | (68.0 | ) | 46.7 | ||||
Income tax expense (benefit) | — | — | |||||
Net income (loss) | $ | (68.0 | ) | $ | 46.7 | ||
Net income (loss) per common unit – basic | $ | (0.46 | ) | $ | 0.32 | ||
Net income (loss) per common unit – diluted | $ | (0.46 | ) | $ | 0.32 | ||
Weighted-average common units outstanding: | |||||||
Basic | 147.6 | 147.6 | |||||
Diluted | 147.6 | 147.6 |
Common Units Issued | Common Unitholders | General Partner Interest | Total Partners' Capital | |||||||||||
(unaudited) | ||||||||||||||
(in millions, except unit data) | ||||||||||||||
Balance at December 31, 2015 | 147,600,000 | $ | 1,281.4 | $ | — | $ | 1,281.4 | |||||||
Net loss | — | (68.0 | ) | — | (68.0 | ) | ||||||||
Balance at March 31, 2016 | 147,600,000 | $ | 1,213.4 | $ | — | $ | 1,213.4 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(unaudited) | |||||||
(in millions) | |||||||
Cash flows from operating activities: | |||||||
Net income (loss) | $ | (68.0 | ) | $ | 46.7 | ||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | |||||||
Depreciation and amortization | 31.5 | 34.0 | |||||
Amortization of deferred financing costs | 0.5 | 0.4 | |||||
Share-based compensation | 0.7 | 2.8 | |||||
Loss on derivatives, net | 1.2 | 51.4 | |||||
Current period settlements on derivative contracts | 21.4 | (6.3 | ) | ||||
Changes in assets and liabilities: | |||||||
Accounts receivable | (11.8 | ) | 2.8 | ||||
Inventories | 25.7 | 16.2 | |||||
Prepaid expenses and other current assets | 3.6 | 6.7 | |||||
Other long-term assets | — | 0.1 | |||||
Accounts payable | (10.4 | ) | (8.1 | ) | |||
Accrued expenses and other liabilities | 8.7 | 2.0 | |||||
Other long-term liabilities | (0.1 | ) | (0.2 | ) | |||
Net cash provided by operating activities | 3.0 | 148.5 | |||||
Cash flows from investing activities: | |||||||
Capital expenditures | (44.0 | ) | (41.7 | ) | |||
Net cash used in investing activities | (44.0 | ) | (41.7 | ) | |||
Cash flows from financing activities: | |||||||
Payment of capital lease obligations | (0.4 | ) | (0.3 | ) | |||
Distributions to common unitholders – affiliates | — | (38.2 | ) | ||||
Distributions to common unitholders – non-affiliates | — | (16.4 | ) | ||||
Net cash used in financing activities | (0.4 | ) | (54.9 | ) | |||
Net increase (decrease) in cash and cash equivalents | (41.4 | ) | 51.9 | ||||
Cash and cash equivalents, beginning of period | 187.3 | 370.2 | |||||
Cash and cash equivalents, end of period | $ | 145.9 | $ | 422.1 | |||
Supplemental disclosures: | |||||||
Cash paid for interest net of capitalized interest of $1.5 and $0.4 in 2016 and 2015, respectively | $ | 2.2 | $ | 2.7 | |||
Non-cash investing and financing activities: | |||||||
Construction in process additions included in accounts payable | $ | 17.8 | $ | 13.8 | |||
Change in accounts payable related to construction in process additions | $ | (2.8 | ) | $ | (6.1 | ) |
Phantom Units | Weighted- Average Grant-Date Fair Value | |||||
Non-vested at January 1, 2016 | 511,591 | $ | 19.68 | |||
Granted | — | — | ||||
Vested | — | — | ||||
Forfeited | (6,911 | ) | 19.51 | |||
Non-vested at March 31, 2016 | 504,680 | $ | 19.69 |
March 31, 2016 | December 31, 2015 | ||||||
(in millions) | |||||||
Finished goods | $ | 90.3 | $ | 104.7 | |||
Raw materials and precious metals | 75.0 | 72.6 | |||||
In-process inventories | 21.2 | 35.7 | |||||
Parts and supplies | 40.3 | 39.5 | |||||
Total Inventories | $ | 226.8 | $ | 252.5 |
March 31, 2016 | December 31, 2015 | ||||||
(in millions) | |||||||
Land and improvements | $ | 28.9 | $ | 28.7 | |||
Buildings | 47.2 | 47.8 | |||||
Machinery and equipment | 2,157.3 | 2,142.2 | |||||
Automotive equipment | 23.8 | 23.9 | |||||
Furniture and fixtures | 8.3 | 8.2 | |||||
Leasehold improvements | 0.8 | 0.8 | |||||
Construction in progress | 143.3 | 116.8 | |||||
2,409.6 | 2,368.4 | ||||||
Accumulated depreciation | 849.8 | 818.9 | |||||
Total property, plant and equipment, net | $ | 1,559.8 | $ | 1,549.5 |
March 31, 2016 | December 31, 2015 | ||||||
(in millions) | |||||||
6.5% Senior Notes due 2022 | $ | 500.0 | $ | 500.0 | |||
Intercompany credit facility | 31.5 | 31.5 | |||||
Capital lease obligations | 48.1 | 48.5 | |||||
Total debt | 579.6 | 580.0 | |||||
Unamortized debt issuance cost | (6.0 | ) | (6.2 | ) | |||
Current portion of capital lease obligations | (1.7 | ) | (1.6 | ) | |||
Long-term debt, net of current portion | $ | 571.9 | $ | 572.2 |
• | common units; and |
• | a general partner interest, which is not entitled to any distributions, and which is held by the general partner. |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions, except per unit data) | |||||||
Net income (loss) | $ | (68.0 | ) | $ | 46.7 | ||
Net income (loss) per common unit, basic | $ | (0.46 | ) | $ | 0.32 | ||
Net income (loss) per common unit, diluted | $ | (0.46 | ) | $ | 0.32 | ||
Weighted-average common units outstanding, basic | 147.6 | 147.6 | |||||
Weighted-average common units outstanding, diluted | 147.6 | 147.6 |
Operating Leases | Unconditional Purchase Obligations(1) | ||||||
(in millions) | |||||||
Nine months ending December 31, 2016 | $ | 1.0 | $ | 131.4 | |||
Year Ending December 31, | |||||||
2017 | 0.5 | 123.8 | |||||
2018 | 0.3 | 120.2 | |||||
2019 | 0.2 | 119.7 | |||||
2020 | 0.1 | 107.1 | |||||
Thereafter | 0.2 | 735.9 | |||||
$ | 2.3 | $ | 1,338.1 |
(1) | This amount includes approximately $784.1 million payable ratably over fifteen years pursuant to petroleum transportation service agreements between Coffeyville Resources Refining & Marketing, LLC ("CRRM") and each of TransCanada Keystone Pipeline Limited Partnership and TransCanada Keystone Pipeline, LP (together, "TransCanada"). The purchase obligation reflects the exchange rate between the Canadian dollar and the U.S. dollar as of March 31, 2016, where applicable. Under the agreements, CRRM receives transportation of at least 25,000 barrels per day of crude oil with a delivery point at Cushing, Oklahoma for a term of 20 years on TransCanada's Keystone pipeline system. |
• | Level 1 — Quoted prices in active markets for identical assets or liabilities |
• | Level 2 — Other significant observable inputs (including quoted prices in active markets for similar assets or liabilities) |
• | Level 3 — Significant unobservable inputs (including CVR Refining's own assumptions in determining the fair value) |
March 31, 2016 | |||||||||||||||
Level 1 | Level 2 | Level 3 | Total | ||||||||||||
(in millions) | |||||||||||||||
Location and Description | |||||||||||||||
Other current assets (derivative agreements) | $ | — | $ | 22.1 | $ | — | $ | 22.1 | |||||||
Total Assets | $ | — | $ | 22.1 | $ | — | $ | 22.1 | |||||||
Other current liabilities (derivative agreements) | — | (0.1 | ) | — | (0.1 | ) | |||||||||
Other current liabilities (biofuel blending obligation) | — | (0.5 | ) | — | (0.5 | ) | |||||||||
Total Liabilities | $ | — | $ | (0.6 | ) | $ | — | $ | (0.6 | ) |
December 31, 2015 | |||||||||||||||
Level 1 | Level 2 | Level 3 | Total | ||||||||||||
(in millions) | |||||||||||||||
Location and Description | |||||||||||||||
Other current assets (derivative agreements) | $ | — | $ | 44.7 | $ | — | $ | 44.7 | |||||||
Total Assets | $ | — | $ | 44.7 | $ | — | $ | 44.7 | |||||||
Other current liabilities (derivative agreements) | — | (0.1 | ) | — | (0.1 | ) | |||||||||
Other current liabilities (biofuel blending obligation) | — | (2.7 | ) | — | (2.7 | ) | |||||||||
Total Liabilities | $ | — | $ | (2.8 | ) | $ | — | $ | (2.8 | ) |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Current period settlements on derivative contracts | $ | 21.4 | $ | (6.3 | ) | ||
Loss on derivatives, net | (1.2 | ) | (51.4 | ) |
As of March 31, 2016 | |||||||||||||||||||
Description | Gross Current Assets | Gross Amounts Offset | Net Current Assets Presented | Cash Collateral Not Offset | Net Amount | ||||||||||||||
(in millions) | |||||||||||||||||||
Commodity Swaps | $ | 22.4 | $ | (0.3 | ) | $ | 22.1 | $ | — | $ | 22.1 | ||||||||
Total | $ | 22.4 | $ | (0.3 | ) | $ | 22.1 | $ | — | $ | 22.1 |
As of March 31, 2016 | |||||||||||||||||||
Description | Gross Current Liabilities | Gross Amounts Offset | Net Current Liabilities Presented | Cash Collateral Not Offset | Net Amount | ||||||||||||||
(in millions) | |||||||||||||||||||
Commodity Swaps | $ | 0.1 | $ | — | $ | 0.1 | $ | — | $ | 0.1 | |||||||||
Total | $ | 0.1 | $ | — | $ | 0.1 | $ | — | $ | 0.1 |
As of December 31, 2015 | |||||||||||||||||||
Description | Gross Current Assets | Gross Amounts Offset | Net Current Assets Presented | Cash Collateral Not Offset | Net Amount | ||||||||||||||
(in millions) | |||||||||||||||||||
Commodity Swaps | $ | 44.8 | $ | (0.1 | ) | $ | 44.7 | $ | — | $ | 44.7 | ||||||||
Total | $ | 44.8 | $ | (0.1 | ) | $ | 44.7 | $ | — | $ | 44.7 |
As of December 31, 2015 | |||||||||||||||||||
Description | Gross Current Liabilities | Gross Amounts Offset | Net Current Liabilities Presented | Cash Collateral Not Offset | Net Amount | ||||||||||||||
(in millions) | |||||||||||||||||||
Commodity Swaps | $ | 0.1 | $ | — | $ | 0.1 | $ | — | $ | 0.1 | |||||||||
Total | $ | 0.1 | $ | — | $ | 0.1 | $ | — | $ | 0.1 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Direct operating expenses (exclusive of depreciation and amortization) | $ | 3.0 | $ | 4.6 | |||
Selling, general and administrative expenses (exclusive of depreciation and amortization) | 12.6 | 12.6 | |||||
Total | $ | 15.6 | $ | 17.2 |
• | statements, other than statements of historical fact, that address activities, events or developments that we expect, believe or anticipate will or may occur in the future; |
• | statements relating to future financial or operational performance, future distributions, future capital sources and capital expenditures; and |
• | any other statements preceded by, followed by or that include the words "anticipates," "believes," "expects," "plans," "intends," "estimates," "projects," "could," "should," "may" or similar expressions. |
• | our ability to make cash distributions on the common units; |
• | the price volatility of crude oil, other feedstocks and refined products, and variable nature of our distributions; |
• | the ability of our general partner to modify or revoke our distribution policy at any time; |
• | our ability to forecast our future financial condition or results of operations and our future revenues and expenses; |
• | the effects of transactions involving forward and derivative instruments; |
• | our ability in the future to obtain an adequate crude oil supply pursuant to supply agreements or at all; |
• | our continued access to crude oil and other feedstock and refined products pipelines; |
• | the level of competition from other petroleum refiners; |
• | changes in our credit profile; |
• | potential operating consequences from accidents, fire, severe weather, floods, or other natural disasters, or other operating hazards resulting in unscheduled downtime; |
• | our continued ability to secure RINs, as well as environmental and other governmental permits necessary for the operation of our business; |
• | changes in laws, regulations and policies with respect to the export of crude oil or other hydrocarbons; |
• | costs of compliance with existing, or compliance with new, environmental laws and regulations, as well as the potential liabilities arising from, and capital expenditures required to, remediate current or future contamination; |
• | the seasonal nature of our business; |
• | our dependence on significant customers; |
• | our potential inability to obtain or renew permits; |
• | our ability to continue safe, reliable operations without unplanned maintenance events prior to and when approaching the end-of-cycle turnaround operations; |
• | new regulations concerning the transportation of hazardous chemicals, risks of terrorism, and the security of chemical manufacturing facilities; |
• | the risk of security breaches; |
• | our lack of asset diversification; |
• | the potential loss of our transportation cost advantage over our competitors; |
• | our ability to comply with employee safety laws and regulations; |
• | potential disruptions in the global or U.S. capital and credit markets; |
• | the success of our acquisition and expansion strategies; |
• | our reliance on CVR Energy's senior management team; |
• | the risk of a substantial increase in costs or work stoppages associated with negotiating collective bargaining agreements with the unionized portion of our workforce; |
• | the potential shortage of skilled labor or loss of key personnel; |
• | successfully defending against third-party claims of intellectual property infringement; |
• | our indebtedness; |
• | our potential inability to generate sufficient cash to service all of our indebtedness; |
• | the limitations contained in our debt agreements that limit our flexibility in operating our business; |
• | the dependence on our subsidiaries for cash to meet our debt obligations; |
• | our limited operating history as a stand-alone entity; |
• | potential increases in costs and distraction of management resulting from the requirements of being a publicly traded partnership; |
• | exemptions we will rely on in connection with the NYSE corporate governance requirements; |
• | risks relating to our relationships with CVR Energy; |
• | risks relating to the control of our general partner by CVR Energy; |
• | the conflicts of interest faced by our senior management team, which operates both us and CVR Energy, and our general partner; |
• | limitations on duties owed by our general partner that are included in the partnership agreement; |
• | changes in our treatment as a partnership for U.S. income or state tax purposes; and |
• | instability and volatility in the capital and credit markets. |
Three Months Ended March 31, | |||||
2016 | 2015 | ||||
(in millions) | |||||
Loss on derivatives, net | 1.2 | 51.4 | |||
Major scheduled turnaround expenses(1) | 29.4 | — |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Consolidated Statements of Operations Data | |||||||
Net sales | $ | 834.0 | $ | 1,304.4 | |||
Cost of product sold(1) | 722.3 | 1,056.1 | |||||
Direct operating expenses(1)(2) | 88.3 | 87.0 | |||||
Major scheduled turnaround expenses | 29.4 | — | |||||
Selling, general and administrative expenses(1) | 18.5 | 18.1 | |||||
Depreciation and amortization | 31.5 | 34.0 | |||||
Operating income (loss) | (56.0 | ) | 109.2 | ||||
Interest expense and other financing costs | (10.8 | ) | (11.3 | ) | |||
Interest income | — | 0.1 | |||||
Loss on derivatives, net | (1.2 | ) | (51.4 | ) | |||
Other income, net | — | 0.1 | |||||
Income (loss) before income tax expense | (68.0 | ) | 46.7 | ||||
Income tax expense | — | — | |||||
Net income (loss) | $ | (68.0 | ) | $ | 46.7 | ||
Gross profit (loss)(3) | $ | (37.5 | ) | $ | 127.3 | ||
Refining margin(4) | $ | 111.7 | $ | 248.3 | |||
Adjusted EBITDA(5) | $ | 35.1 | $ | 161.7 | |||
Available cash for distribution(6) | $ | — | $ | 111.8 |
As of March 31, 2016 | As of December 31, 2015 | ||||||
(audited) | |||||||
(in millions) | |||||||
Balance Sheet Data | |||||||
Cash and cash equivalents | $ | 145.9 | $ | 187.3 | |||
Working capital (1) | 219.9 | 297.5 | |||||
Total assets (1) | 2,116.9 | 2,189.0 | |||||
Total debt, including current portion (1) | 573.6 | 573.8 | |||||
Total partners' capital | 1,213.4 | 1,281.4 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Cash Flow Data | |||||||
Net cash flow provided by (used in): | |||||||
Operating activities | $ | 3.0 | $ | 148.5 | |||
Investing activities | (44.0 | ) | (41.7 | ) | |||
Financing activities | (0.4 | ) | (54.9 | ) | |||
Net cash flow | $ | (41.4 | ) | $ | 51.9 | ||
Capital expenditures for property, plant and equipment | $ | 44.0 | $ | 41.7 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(dollars per barrel) | |||||||
Key Operating Statistics | |||||||
Per crude oil throughput barrel: | |||||||
Refining margin(4) | $ | 6.67 | $ | 13.68 | |||
Gross profit (loss)(3) | $ | (2.24 | ) | $ | 7.02 | ||
Direct operating expenses and major scheduled turnaround expenses(1)(2) | $ | 7.02 | $ | 4.79 | |||
Direct operating expenses and major scheduled turnaround expenses per barrel sold(1)(7) | $ | 6.40 | $ | 4.44 | |||
Barrels sold (barrels per day)(7) | 201,970 | 217,686 |
Three Months Ended March 31, | |||||||||||
2016 | 2015 | ||||||||||
% | % | ||||||||||
Refining Throughput and Production Data (bpd) | |||||||||||
Throughput: | |||||||||||
Sweet | 170,728 | 87.2 | 175,376 | 81.6 | |||||||
Medium | 1,513 | 0.8 | 6,630 | 3.1 | |||||||
Heavy sour | 11,914 | 6.0 | 19,658 | 9.1 | |||||||
Total crude oil throughput | 184,155 | 94.0 | 201,664 | 93.8 | |||||||
All other feedstocks and blendstocks | 11,704 | 6.0 | 13,359 | 6.2 | |||||||
Total throughput | 195,859 | 100.0 | 215,023 | 100.0 | |||||||
Production: | |||||||||||
Gasoline | 105,878 | 54.2 | 109,096 | 50.2 | |||||||
Distillate | 77,996 | 39.9 | 89,436 | 41.1 | |||||||
Other (excluding internally produced fuel) | 11,519 | 5.9 | 18,857 | 8.7 | |||||||
Total refining production (excluding internally produced fuel) | 195,393 | 100.0 | 217,389 | 100.0 | |||||||
Product price (dollars per gallon): | |||||||||||
Gasoline | $ | 1.04 | $ | 1.48 | |||||||
Distillate | 1.05 | 1.69 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
Market Indicators (dollars per barrel) | |||||||
West Texas Intermediate (WTI) NYMEX | $ | 33.63 | $ | 48.57 | |||
Crude Oil Differentials: | |||||||
WTI less WTS (light/medium sour) | 0.13 | 0.99 | |||||
WTI less WCS (heavy sour) | 13.62 | 13.62 | |||||
NYMEX Crack Spreads: | |||||||
Gasoline | 15.84 | 18.54 | |||||
Heating Oil | 11.91 | 27.06 | |||||
NYMEX 2-1-1 Crack Spread | 13.88 | 22.80 | |||||
PADD II Group 3 Basis: | |||||||
Gasoline | (5.88 | ) | (3.50 | ) | |||
Ultra Low Sulfur Diesel | (1.01 | ) | (4.52 | ) | |||
PADD II Group 3 Product Crack Spread: | |||||||
Gasoline | 9.97 | 15.04 | |||||
Ultra Low Sulfur Diesel | 10.90 | 22.54 | |||||
PADD II Group 3 2-1-1 | 10.43 | 18.79 |
(1) | Our cost of product sold, direct operating expenses and selling, general and administrative expenses for the three months ended March 31, 2016 and 2015 are shown exclusive of depreciation and amortization, which is comprised of the following components: |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Depreciation and amortization excluded from cost of product sold | $ | 1.5 | $ | 1.6 | |||
Depreciation and amortization excluded from direct operating expenses | 29.4 | 31.9 | |||||
Depreciation and amortization excluded from selling, general and administrative expenses | 0.6 | 0.5 | |||||
Total depreciation and amortization | $ | 31.5 | $ | 34.0 |
(2) | Direct operating expense is presented on a per crude oil throughput barrel basis. In order to derive the direct operating expenses per crude oil throughput barrel, we utilize the total direct operating expenses, which do not include depreciation or amortization expense, and divide by the applicable number of crude oil throughput barrels for the period. |
(3) | Gross profit (loss) is a measurement calculated as the difference between net sales and cost of product sold (exclusive of depreciation and amortization), direct operating expenses (exclusive of depreciation and amortization), major scheduled turnaround expenses and depreciation and amortization. Each of the components used in this calculation are taken directly from our Condensed Consolidated Statements of Operations. In order to derive the gross profit (loss) per crude oil throughput barrel, we utilize the total dollar figures for gross profit (loss) as derived above and divide by the applicable number of crude oil throughput barrels for the period. |
(4) | Refining margin per crude oil throughput barrel is a measurement calculated as the difference between net sales and cost of product sold (exclusive of depreciation and amortization). Refining margin is a non-GAAP measure that management believes is important to investors in evaluating the performance of our refineries as a general indication of the amount above our cost of product sold at which we are able to sell refined products. Each of the components used in this calculation (net sales and cost of product sold (exclusive of depreciation and amortization)) are taken directly from our Condensed Consolidated Statements of Operations. Our calculation of refining margin may differ from similar calculations of other companies in our industry, thereby limiting its usefulness as a comparative measure. In order to derive the refining margin per crude oil throughput barrel, we utilize the total dollar figures for refining margin as derived above and divide by the applicable number of crude oil throughput barrels for the period. We believe that refining margin and refining margin per crude oil throughput barrel are important to enable investors to better understand and evaluate our ongoing operating results and allow for greater transparency in the review of our overall financial, operational and economic performance. |
(5) | EBITDA and Adjusted EBITDA. EBITDA represents net income (loss) before (i) interest expense and other financing costs, net of interest income, (ii) income tax expense and (iii) depreciation and amortization. Adjusted EBITDA represents EBITDA adjusted for (i) FIFO impact (favorable) unfavorable, (ii) share-based compensation, non-cash, (iii) loss on extinguishment of debt, (iv) major scheduled turnaround expenses, (v) (gain) loss on derivatives, net and (vi) current period settlements on derivative contracts. We present Adjusted EBITDA because it is the starting point for our available cash for distribution. EBITDA and Adjusted EBITDA are not recognized terms under GAAP and should not be substituted for net income (loss) or cash flow from operations. Management believes that EBITDA and Adjusted EBITDA enable investors to better understand our ability to make distributions to our common unitholders, help investors evaluate our ongoing operating results and allow for greater transparency in reviewing our overall financial, operational and economic performance. EBITDA and Adjusted EBITDA presented by other companies may not be comparable to our presentation, since each company may define these terms differently. Below is a reconciliation of net income (loss) to EBITDA and EBITDA to Adjusted EBITDA for the three months ended March 31, 2016 and 2015: |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Net income (loss) | $ | (68.0 | ) | $ | 46.7 | ||
Add: | |||||||
Interest expense and other financing costs, net of interest income | 10.8 | 11.2 | |||||
Income tax expense | — | — | |||||
Depreciation and amortization | 31.5 | 34.0 | |||||
EBITDA | (25.7 | ) | 91.9 | ||||
Add: | |||||||
FIFO impact, unfavorable(a) | 8.8 | 24.5 | |||||
Share-based compensation, non-cash | — | 0.2 | |||||
Major scheduled turnaround expenses(b) | 29.4 | — | |||||
Loss on derivatives, net | 1.2 | 51.4 | |||||
Current period settlements on derivative contracts(c) | 21.4 | (6.3 | ) | ||||
Adjusted EBITDA | $ | 35.1 | $ | 161.7 |
(a) | FIFO is our basis for determining inventory value on a GAAP basis. Changes in crude oil prices can cause fluctuations in the inventory valuation of our crude oil, work in process and finished goods, thereby resulting in a favorable FIFO impact when crude oil prices increase and an unfavorable FIFO impact when crude oil prices decrease. The FIFO impact is calculated based upon inventory values at the beginning of the accounting period and at the end of the accounting period. In order to derive the FIFO impact per crude oil throughput barrel, we utilize the total dollar figures for the FIFO impact and divide by the number of crude oil throughput barrels for the period. |
(b) | Represents expense associated with major scheduled turnaround activities at the Coffeyville refinery. |
(c) | Represents the portion of loss on derivatives, net related to contracts that matured during the respective periods and settled with counterparties. There are no premiums paid or received at the inception of the derivative contracts and upon settlement, there is no cost recovery associated with these contracts. |
(6) | Available cash for distribution is generally equal to Adjusted EBITDA reduced for cash needed for (i) debt service, (ii) reserves for environmental and maintenance capital expenditures, (iii) reserves for major scheduled turnaround expenses and, to the extent applicable, (iv) reserves for future operating or capital needs that the board of directors of our general partner deems necessary or appropriate, if any. Available cash for distribution may be increased by the release of previously established cash reserves, if any, and other excess cash, at the discretion of the board of directors of our general partner. Available cash for distribution is not a recognized term under GAAP. Available cash for distribution should not be considered in isolation or as an alternative to net income (loss) or operating income (loss), as a measure of operating performance. In addition, available cash for distribution is not presented as, and should not be considered an alternative to cash flows from operations or as a measure of liquidity. Available cash for distribution as reported by the Partnership may not be comparable to similarly titled measures of other entities, thereby limiting its usefulness as a comparative measure. |
Three Months Ended March 31, 2016 | |||
(in millions, except per unit data) | |||
Reconciliation of Adjusted EBITDA to Available cash for distribution | |||
Adjusted EBITDA | $ | 35.1 | |
Adjustments: | |||
Less: | |||
Cash needs for debt service | (10.0 | ) | |
Reserves for environmental and maintenance capital expenditures | (16.4 | ) | |
Reserves for major scheduled turnaround expenses | (8.7 | ) | |
Available cash for distribution | $ | — | |
Available cash for distribution, per unit | $ | — | |
Common units outstanding (in thousands) | 147,600 |
(7) | Direct operating expense is presented on a per barrel sold basis. Barrels sold are derived from the barrels produced and shipped from the refineries. We utilize total direct operating expenses, which does not include depreciation or amortization expense, and divide by the applicable number of barrels sold for the period to derive the metric. |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Coffeyville Refinery Financial Results | |||||||
Net sales | $ | 528.0 | $ | 851.7 | |||
Cost of product sold (exclusive of depreciation and amortization) | 462.7 | 700.9 | |||||
Direct operating expenses (exclusive of depreciation and amortization) | 47.6 | 50.4 | |||||
Major scheduled turnaround expenses | 29.4 | — | |||||
Depreciation and amortization | 16.9 | 19.4 | |||||
Gross profit (loss) | $ | (28.6 | ) | $ | 81.0 | ||
Plus: | |||||||
Direct operating expenses and major scheduled turnaround expenses (exclusive of depreciation and amortization) | 77.0 | 50.4 | |||||
Depreciation and amortization | 16.9 | 19.4 | |||||
Refining margin | $ | 65.3 | $ | 150.8 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(dollars per barrel) | |||||||
Coffeyville Refinery Key Operating Statistics | |||||||
Per crude oil throughput barrel: | |||||||
Refining margin | $ | 6.75 | $ | 13.21 | |||
Gross profit (loss) | $ | (2.96 | ) | $ | 7.10 | ||
Direct operating expenses and major scheduled turnaround expenses (exclusive of depreciation and amortization) | $ | 7.96 | $ | 4.42 | |||
Direct operating expenses and major scheduled turnaround expenses (exclusive of depreciation and amortization) per barrel sold | $ | 6.89 | $ | 3.97 | |||
Barrels sold (barrels per day) | 122,838 | 140,974 |
Three Months Ended March 31, | |||||||||
2016 | 2015 | ||||||||
% | % | ||||||||
Coffeyville Refinery Throughput and Production Data (bpd) | |||||||||
Throughput: | |||||||||
Sweet | 92,938 | 80.3 | 100,532 | 73.4 | |||||
Medium | 1,513 | 1.3 | 6,630 | 4.8 | |||||
Heavy sour | 11,914 | 10.3 | 19,658 | 14.3 | |||||
Total crude oil throughput | 106,365 | 91.9 | 126,820 | 92.5 | |||||
All other feedstocks and blendstocks | 9,344 | 8.1 | 10,227 | 7.5 | |||||
Total throughput | 115,709 | 100.0 | 137,047 | 100.0 | |||||
Production: | |||||||||
Gasoline | 64,033 | 54.8 | 67,853 | 48.3 | |||||
Distillate | 47,147 | 40.3 | 59,415 | 42.3 | |||||
Other (excluding internally produced fuel) | 5,768 | 4.9 | 13,228 | 9.4 | |||||
Total refining production (excluding internally produced fuel) | 116,948 | 100.0 | 140,496 | 100.0 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(in millions) | |||||||
Wynnewood Refinery Financial Results | |||||||
Net sales | $ | 304.8 | $ | 451.7 | |||
Cost of product sold (exclusive of depreciation and amortization) | 259.4 | 355.6 | |||||
Direct operating expenses (exclusive of depreciation and amortization) | 40.6 | 36.6 | |||||
Major scheduled turnaround expenses | — | — | |||||
Depreciation and amortization | 12.7 | 12.5 | |||||
Gross profit (Loss) | $ | (7.9 | ) | $ | 47.0 | ||
Plus: | |||||||
Direct operating expenses and major scheduled turnaround expenses (exclusive of depreciation and amortization) | 40.6 | 36.6 | |||||
Depreciation and amortization | 12.7 | 12.5 | |||||
Refining margin | $ | 45.4 | $ | 96.1 |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(dollars per barrel) | |||||||
Wynnewood Refinery Key Operating Statistics | |||||||
Per crude oil throughput barrel: | |||||||
Refining margin | $ | 6.41 | $ | 14.27 | |||
Gross profit (loss) | $ | (1.11 | ) | $ | 6.98 | ||
Direct operating expenses and major scheduled turnaround expenses (exclusive of depreciation and amortization) | $ | 5.74 | $ | 5.43 | |||
Direct operating expenses and major scheduled turnaround expenses (exclusive of depreciation and amortization) per barrel sold | $ | 5.64 | $ | 5.30 | |||
Barrels sold (barrels per day) | 79,132 | 76,712 |
Three Months Ended March 31, | |||||||||
2016 | 2015 | ||||||||
% | % | ||||||||
Wynnewood Refinery Throughput and Production Data (bpd) | |||||||||
Throughput: | |||||||||
Sweet | 77,790 | 97.1 | 74,844 | 96.0 | |||||
Medium | — | — | 0 | 0.0 | |||||
Heavy sour | — | — | — | — | |||||
Total crude oil throughput | 77,790 | 97.1 | 74,844 | 96.0 | |||||
All other feedstocks and blendstocks | 2,360 | 2.9 | 3,132 | 4.0 | |||||
Total throughput | 80,150 | 100.0 | 77,976 | 100.0 | |||||
Production: | |||||||||
Gasoline | 41,845 | 53.4 | 41,243 | 53.7 | |||||
Distillate | 30,849 | 39.3 | 30,021 | 39.0 | |||||
Other (excluding internally produced fuel) | 5,751 | 7.3 | 5,629 | 7.3 | |||||
Total refining production (excluding internally produced fuel) | 78,445 | 100.0 | 76,893 | 100.0 |
Three Months Ended March 31, 2016 | Three Months Ended March 31, 2015 | Total Variance | |||||||||||||||||||||||||||||||||
Volume(1) | $ per barrel | Sales $(2) | Volume(1) | $ per barrel | Sales $(2) | Volume(1) | Sales $(2) | Price Variance | Volume Variance | ||||||||||||||||||||||||||
(in millions) | |||||||||||||||||||||||||||||||||||
Gasoline | 10.8 | $ | 43.60 | $ | 470.1 | 10.7 | $ | 62.36 | 667.6 | 0.1 | $ | (197.5 | ) | $ | (202.2 | ) | $ | 4.6 | |||||||||||||||||
Distillate | 7.4 | $ | 44.07 | $ | 324.2 | 8.2 | $ | 70.88 | 581.0 | (0.8 | ) | $ | (256.8 | ) | $ | (197.3 | ) | $ | (59.6 | ) |
Three Months Ended March 31, 2016 | 2016 Estimate(1) | |||||||
Actual | ||||||||
(in millions) | ||||||||
Coffeyville refinery: | ||||||||
Maintenance | $ | 17.7 | $ | 74.0 | ||||
Growth | 18.2 | 48.0 | ||||||
Coffeyville refinery total capital spending | 35.9 | 122.0 | ||||||
Wynnewood refinery | ||||||||
Maintenance | 5.8 | 40.0 | ||||||
Growth | 0.2 | 4.0 | ||||||
Wynnewood refinery total capital spending | 6.0 | 44.0 | ||||||
Other: | ||||||||
Maintenance | 1.8 | 10.0 | ||||||
Growth | 0.3 | 4.0 | ||||||
Other total capital spending | 2.1 | 14.0 | ||||||
Total capital spending | $ | 44.0 | $ | 180.0 |
(1) | Includes amounts already spent during the three months ended March 31, 2016. |
Three Months Ended March 31, | |||||||
2016 | 2015 | ||||||
(unaudited) | |||||||
(in millions) | |||||||
Net cash provided by (used in): | |||||||
Operating activities | $ | 3.0 | $ | 148.5 | |||
Investing activities | (44.0 | ) | (41.7 | ) | |||
Financing activities | (0.4 | ) | (54.9 | ) | |||
Net increase in cash and cash equivalents | $ | (41.4 | ) | $ | 51.9 |
Exhibit Number | Exhibit Title | |
31.1* | Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer and President. | |
31.2* | Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer and Treasurer. | |
32.1* | Section 1350 Certification of Chief Executive Officer and President. | |
32.2* | Section 1350 Certification of Chief Financial Officer and Treasurer. | |
101* | The following financial information for CVR Refining, LP's Quarterly Report on Form 10-Q for the quarter ended March 31, 2016 formatted in XBRL ("Extensible Business Reporting Language") includes: (i) Condensed Consolidated Balance Sheets (unaudited), (ii) Condensed Consolidated Statements of Operations (unaudited), (iii) Condensed Consolidated Statement of Changes in Partners' Capital (unaudited), (iv) Condensed Consolidated Statements of Cash Flows (unaudited), and (v) the Notes to Condensed Consolidated Financial Statements (unaudited), tagged in detail. |
* | Filed herewith. |
CVR Refining, LP | |||
By: | CVR Refining GP, LLC, its general partner | ||
May 2, 2016 | By: | /s/ JOHN J. LIPINSKI | |
Chief Executive Officer and President | |||
(Principal Executive Officer) | |||
May 2, 2016 | By: | /s/ SUSAN M. BALL | |
Chief Financial Officer and Treasurer | |||
(Principal Financial and Accounting Officer) | |||
By: | /s/ JOHN J. LIPINSKI |
John J. Lipinski | |
Chief Executive Officer and President | |
CVR Refining GP, LLC | |
the general partner of CVR Refining, LP | |
(Principal Executive Officer) |
By: | /s/ SUSAN M. BALL |
Susan M. Ball | |
Chief Financial Officer and Treasurer | |
CVR Refining GP, LLC | |
the general partner of CVR Refining, LP | |
(Principal Financial and Accounting Officer) |
By: | /s/ JOHN J. LIPINSKI |
John J. Lipinski | |
Chief Executive Officer and President | |
CVR Refining GP, LLC | |
the general partner of CVR Refining, LP | |
(Principal Executive Officer) |
By: | /s/ SUSAN M. BALL |
Susan M. Ball | |
Chief Financial Officer and Treasurer | |
CVR Refining GP, LLC | |
the general partner of CVR Refining, LP | |
(Principal Financial and Accounting Officer) |
Document and Entity Information - shares |
3 Months Ended | |
---|---|---|
Mar. 31, 2016 |
Apr. 26, 2016 |
|
Document and Entity Information | ||
Entity Registrant Name | CVR Refining, LP | |
Entity Central Index Key | 0001558785 | |
Document Type | 10-Q | |
Document Period End Date | Mar. 31, 2016 | |
Amendment Flag | false | |
Current Fiscal Year End Date | --12-31 | |
Entity Current Reporting Status | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Common Stock, Units Outstanding | 147,600,000 | |
Document Fiscal Year Focus | 2016 | |
Document Fiscal Period Focus | Q1 |
CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions |
Mar. 31, 2016 |
Dec. 31, 2015 |
---|---|---|
Statement of Financial Position [Abstract] | ||
Accounts receivable, allowance for doubtful accounts | $ 0.3 | $ 0.3 |
Accounts receivable, due from affiliates | 0.1 | 0.3 |
Prepaid expenses and other current assets, due from affiliates | 0.8 | 2.0 |
Accounts payable, due to affiliates | 4.8 | 5.4 |
Personnel accruals, due to affiliates | 2.1 | 4.0 |
Accrued expenses and other current liabilities, with affiliates | 3.9 | 9.8 |
Long term debt and capital lease obligations, net of current portion, due to affiliates | 31.5 | 31.5 |
Other long-term liabilities, due to affiliates | $ 0.7 | $ 0.8 |
Common unitholders, units issued (in units) | 147,600,000 | 147,600,000 |
Common units outstanding (in units) | 147,600,000 | 147,600,000 |
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS' CAPITAL - 3 months ended Mar. 31, 2016 - USD ($) $ in Millions |
Total |
Common units |
General Partner Interest |
---|---|---|---|
Balance (in units) at Dec. 31, 2015 | 147,600,000 | ||
Balance at Dec. 31, 2015 | $ 1,281.4 | $ 1,281.4 | $ 0.0 |
Increase (Decrease) in Stockholders' Equity | |||
Net loss | (68.0) | $ (68.0) | |
Balance (in units) at Mar. 31, 2016 | 147,600,000 | ||
Balance at Mar. 31, 2016 | $ 1,213.4 | $ 1,213.4 | $ 0.0 |
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions |
3 Months Ended | |
---|---|---|
Mar. 31, 2016 |
Mar. 31, 2015 |
|
Statement of Cash Flows [Abstract] | ||
Capitalized interest | $ 1.5 | $ 0.4 |
Formation of the Partnership, Organization and Nature of Business |
3 Months Ended |
---|---|
Mar. 31, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Formation of the Partnership, Organization and Nature of Business | (1) Formation of the Partnership, Organization and Nature of Business CVR Refining, LP and subsidiaries (referred to as "CVR Refining" or the "Partnership") is an independent petroleum refiner and marketer of high value transportation fuels. CVR Refining is a Delaware limited partnership, formed in September 2012 by Coffeyville Resources, LLC (referred to as "CRLLC"), a wholly-owned subsidiary of CVR Energy, Inc. (referred to as "CVR Energy") in contemplation of an initial public offering. As of March 31, 2016, CRLLC owned 100% of the Partnership's noneconomic general partner interest and approximately 66% of the Partnership's outstanding limited partner interests. As of March 31, 2016, Icahn Enterprises L.P. ("IEP") and its affiliates owned approximately 82% of CVR Energy's outstanding shares. Offerings of CVR Refining, LP CVR Refining completed the initial public offering of its common units representing limited partner interests (the "Initial Public Offering") on January 23, 2013. The common units, which are listed on the NYSE, began trading on January 17, 2013 under the symbol "CVRR." On May 20, 2013, the Partnership completed an underwritten offering (the "Underwritten Offering") by selling additional common units to the public. In connection with the Underwritten Offering, American Entertainment Properties Corporation ("AEPC"), an affiliate of IEP, also purchased common units in a privately negotiated transaction with a subsidiary of CVR Energy, which was completed on May 29, 2013. On June 30, 2014, the Partnership completed a second underwritten offering (the "Second Underwritten Offering"). Additionally, on July 24, 2014, the Partnership sold additional common units to the public in connection with the underwriters' exercise of their option to purchase additional common units. Immediately subsequent to the closing of the underwriters' option for the Second Underwritten Offering and as of March 31, 2016, public security holders held approximately 34% of all outstanding limited partner interests (including common units owned by affiliates of IEP, representing approximately 4% of all outstanding limited partner interests), and CVR Refining Holdings held approximately 66% of all outstanding limited partner interests. In addition, CVR Refining Holdings, LLC (“CVR Refining Holdings”) owns 100% of the Partnership’s general partner, CVR Refining GP, LLC ("CVR Refining GP"), which holds a non-economic general partner interest. The Partnership has adopted a policy pursuant to which it will distribute all of the available cash it generates each quarter. The available cash for distribution for each quarter will be determined by the board of directors of the Partnership's general partner following the end of such quarter. The partnership agreement does not require that the Partnership make cash distributions on a quarterly basis or at all, and the board of directors of the general partner of the Partnership can change the distribution policy at any time. The Partnership is party to a services agreement pursuant to which the Partnership and its general partner obtain certain management and other services from CVR Energy. The Partnership's general partner manages the Partnership's activities subject to the terms and conditions specified in the Partnership's partnership agreement. The operations of the general partner, in its capacity as general partner, are managed by its board of directors. Actions by the general partner that are made in its individual capacity are made by CVR Refining Holdings as the sole member of the Partnership's general partner and not by the board of directors of the general partner. The members of the board of directors of the Partnership's general partner are not elected by the Partnership's common unitholders and are not subject to re-election on a regular basis. The officers of the general partner manage the day-to-day affairs of the business. |
Basis of Presentation |
3 Months Ended |
---|---|
Mar. 31, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Basis of Presentation | (2) Basis of Presentation The accompanying condensed consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles ("GAAP") and in accordance with the rules and regulations of the Securities and Exchange Commission (the "SEC"). These condensed consolidated financial statements should be read in conjunction with the December 31, 2015 audited consolidated financial statements and notes thereto included in CVR Refining's Annual Report on Form 10-K for the year ended December 31, 2015, which was filed with the SEC on February 19, 2016 (the "2015 Form 10-K"). The condensed consolidated financial statements include certain selling, general and administrative expenses (exclusive of depreciation and amortization) and direct operating expenses (exclusive of depreciation and amortization) that CVR Energy and its affiliates incurred on behalf of the Partnership. These related party transactions are governed by the services agreement. See Note 14 ("Related Party Transactions") for additional discussion of the services agreement and billing and allocation of certain costs. The amounts charged or allocated to the Partnership are not necessarily indicative of the cost that the Partnership would have incurred had it operated as an independent entity. In the opinion of the Partnership's management, the accompanying condensed consolidated financial statements reflect all adjustments (consisting only of normal recurring adjustments) that are necessary to fairly present the financial position of the Partnership as of March 31, 2016 and December 31, 2015, the results of operations of the Partnership for the three month periods ended March 31, 2016 and 2015, the changes in partners' capital for the Partnership for the three month period ended March 31, 2016 and the cash flows of the Partnership for the three month periods ended March 31, 2016 and 2015. The preparation of the condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2016 or any other interim or annual period. |
Recent Accounting Pronouncements |
3 Months Ended |
---|---|
Mar. 31, 2016 | |
Accounting Changes and Error Corrections [Abstract] | |
Recent Accounting Pronouncements | (3) Recent Accounting Pronouncements In May 2014, the Financial Accounting Standards Board ("FASB") issued ASU No. 2014-09, "Revenue from Contracts with Customers" ("ASU 2014-09"), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The standard was originally effective for interim and annual periods beginning after December 15, 2016 and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. On July 9, 2015, the FASB approved a one-year deferral of the effective date making the standard effective for interim and annual periods beginning after December 15, 2017. The FASB will continue to permit entities to adopt the standard on the original effective date if they choose. The Partnership has not yet selected a transition method and is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures. In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs" ("ASU 2015-03"). The new standard requires that all costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. The standard is effective for interim and annual periods beginning after December 15, 2015 and is required to be applied on a retrospective basis. Early adoption is permitted. The Partnership adopted ASU 2015-03 as of January 1, 2016 and applied the standard retrospectively to the Condensed Consolidated Balance Sheet. Refer to Note 8 ("Long-Term Debt") for further details. In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”). The new standard revises accounting for operating leases by a lessee, among other changes, and requires a lessee to recognize a liability to make lease payments and an asset representing its right to use the underlying asset for the lease term in the balance sheet. The standard is effective for the first interim and annual periods beginning after December 15, 2018, with early adoption permitted. At adoption, ASU 2016-02 will be applied using a modified retrospective approach. The Partnership is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures. |
Share-Based Compensation |
3 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Share-Based Compensation | (4) Share-Based Compensation Certain employees of CVR Refining and employees of CVR Energy and its subsidiaries who perform services for CVR Refining participate in the equity compensation plans of CVR Refining's affiliates. Accordingly, CVR Refining has recorded compensation expense for these plans in accordance with Staff Accounting Bulletin ("SAB") Topic 1-B ("Allocations of Expenses and Related Disclosures in Financial Statements of Subsidiaries, Divisions or Lesser Business Components of Another Entity") and in accordance with guidance regarding the accounting for share-based compensation granted to employees of an equity method investee. All compensation expense related to these plans for full-time employees of CVR Refining has been allocated 100% to CVR Refining. For employees of CVR Energy performing services for CVR Refining, CVR Refining recorded share-based compensation relative to the percentage of time spent by each employee providing services to CVR Refining as compared to the total calculated share-based compensation by CVR Energy. Long-Term Incentive Plan—CVR Energy CVR Energy has a Long-Term Incentive Plan ("CVR Energy LTIP") that permits the grant of options, stock appreciation rights, restricted shares, restricted stock units, dividend equivalent rights, share awards and performance awards (including performance share units, performance units and performance based restricted stock). As of March 31, 2016, only performance units and an immaterial amount of restricted stock units remain outstanding under the CVR Energy LTIP. Individuals who are eligible to receive awards and grants under the CVR Energy LTIP include CVR Energy's or its subsidiaries' (including CVR Refining) employees, officers, consultants and directors. Performance Unit Awards In December 2015, CVR Energy entered into a performance unit award agreement (the "2015 Performance Unit Award Agreement") with its Chief Executive officer. Compensation cost for the 2015 Performance Unit Award Agreement will be recognized over the performance cycle from January 1, 2016 to December 31, 2016. The performance unit award represents the right to receive, upon vesting, a cash payment equal to a defined threshold in accordance with the award agreement, multiplied by a performance factor that is based upon the achievement of certain operating objectives. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the performance unit awards. Assuming a target performance threshold and that the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at March 31, 2016, there was approximately $1.3 million of total unrecognized compensation cost related to the 2015 Performance Unit Award Agreement to be recognized over a weighted-average period of approximately 0.8 years. Total compensation expense recorded for the three months ended March 31, 2016 related to the performance unit awards was approximately $0.4 million. As of March 31, 2016, the Partnership had a liability of $0.4 million for its allocated portion of the 2015 Performance Unit Award Agreement, which is recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheet. Incentive Unit Awards CVR Energy has granted awards of incentive units and distribution equivalent rights to certain employees of CRLLC, CVR Energy and CVR GP, LLC. The awards are generally graded-vesting awards, which are expected to vest over three years with one-third of the award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. Each incentive unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (i) the average fair market value of one unit of the Partnership's common units in accordance with the award agreement, plus (ii) the per unit cash value of all distributions declared and paid by the Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, are remeasured at each subsequent reporting date until they vest. Assuming the allocation of costs from CVR Energy remains consistent with the allocation percentages in place at March 31, 2016, there was approximately $3.6 million of total unrecognized compensation cost related to the incentive unit awards to be recognized over a weighted-average period of approximately 1.5 years. Inclusion of the vesting table is not considered meaningful due to changes in allocation percentages that may occur from time to time. The unrecognized compensation expense has been determined by the number of incentive units and associated distribution equivalent rights and respective allocation percentages for individuals for whom, as of March 31, 2016 compensation expense has been allocated to the Partnership. Total compensation expense recorded for the three months ended March 31, 2016 and 2015 related to the awards was approximately $0.2 million and $1.0 million, respectively. The Partnership will be responsible for reimbursing CVR Energy for its allocated portion of the awards. As of March 31, 2016 and December 31, 2015, the Partnership had a liability of approximately $2.0 million and $1.8 million, respectively, for its allocated portion of non-vested incentive units and associated distribution equivalent rights, which is recorded in accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets. Long-Term Incentive Plan – CVR Refining CVR Refining has a long-term incentive plan ("CVR Refining LTIP") that provides for the grant of options, unit appreciation rights, restricted units, phantom units, unit awards, substitute awards, other-unit based awards, cash awards, performance awards, and distribution equivalent rights. The maximum number of common units issuable under the CVR Refining LTIP is 11,070,000. Individuals who are eligible to receive awards under the CVR Refining LTIP include (i) employees of the Partnership and its subsidiaries, (ii) employees of the general partner, (iii) members of the board of directors of the general partner and (iv) certain employees, consultants and directors of CRLLC and CVR Energy who perform services for the benefit of the Partnership. Awards of phantom units and distribution equivalent rights have been granted to employees of the Partnership and its subsidiaries, its general partner and certain employees of CRLLC and CVR Energy who perform services solely for the benefit of the Partnership. The awards are generally graded-vesting awards, which are expected to vest over three years with one-third of the award vesting each year. Compensation expense is recognized on a straight-line basis over the vesting period of the respective tranche of the award. Each phantom unit and distribution equivalent right represents the right to receive, upon vesting, a cash payment equal to (i) the average fair market value of one unit of the Partnership's common units in accordance with the award agreement, plus (ii) the per unit cash value of all distributions declared and paid by the Partnership from the grant date to and including the vesting date. The awards, which are liability-classified, are remeasured at each subsequent reporting date until they vest. A summary of phantom unit activity and changes under the CVR Refining LTIP during the three months ended March 31, 2016 is presented below:
As of March 31, 2016, there was approximately $4.4 million of total unrecognized compensation cost related to the awards under the CVR Refining LTIP to be recognized over a weighted-average period of 1.5 years. Total compensation expense recorded for the three months ended March 31, 2016 and 2015 related to the awards under the CVR Refining LTIP was approximately $0.3 million and $1.4 million, respectively. As of March 31, 2016 and December 31, 2015, the Partnership had a liability of approximately $2.5 million and $2.3 million, respectively, for non-vested phantom unit awards and associated distribution equivalent rights, which is recorded in personnel accruals and accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets. In December 2014, CVR Energy granted an award of 227,927 incentive units in the form of stock appreciation rights ("SARs") to an executive of CVR Energy. In April 2015, the award granted was canceled and replaced by an award of notional units in the form of SARs by CVR Refining pursuant to the CVR Refining LTIP. The replacement award is structured on the same economic and other terms as the incentive unit award and did not result in a material impact. Each SAR vests over three years and entitles the executive to receive a cash payment in an amount equal to the excess of the fair market value of one unit of the Partnership's common units for the first ten trading days in the month prior to vesting over the grant price of the SAR. The fair value will be adjusted to include all distributions declared and paid by the Partnership during the vesting period. The fair value of each SAR is estimated at the end of each reporting period using the Black-Scholes option-pricing model. Assumptions utilized to value the award have been omitted due to immateriality of the award. Total compensation expense for the three months ended March 31, 2016 and the liability related to the SARs as of March 31, 2016 were not material. |
Inventories |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventories | (5) Inventories Inventories consist primarily of domestic and foreign crude oil, blending stock and components, work-in-progress and refined fuels and by-products. For all periods presented, inventories are valued at the lower of the first-in, first-out ("FIFO") cost or market for refined fuels and by-products. Refinery unfinished and finished products inventory values were determined using the ability-to-bear process, whereby raw materials and production costs are allocated to work-in-process and finished products based on their relative fair values. Other inventories, including other raw materials, spare parts, and supplies, are valued at the lower of moving-average cost, which approximates FIFO, or market. The cost of inventories includes inbound freight costs. Inventories consisted of the following:
|
Property, Plant and Equipment |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant, and Equipment | (6) Property, Plant and Equipment Property, plant and equipment consisted of the following:
Capitalized interest recognized as a reduction in interest expense for the three months ended March 31, 2016 and 2015 totaled approximately $1.5 million and $0.4 million, respectively. Land, buildings and equipment that are under a capital lease obligation had an original carrying value of approximately $24.8 million at both March 31, 2016 and December 31, 2015. Amortization of assets held under capital leases is included in depreciation expense. |
Cost Classifications |
3 Months Ended |
---|---|
Mar. 31, 2016 | |
Costs and Expenses [Abstract] | |
Cost Classifications | (7) Cost Classifications Cost of product sold (exclusive of depreciation and amortization) includes cost of crude oil, other feedstocks, blendstocks, purchased refined products, renewable identification numbers ("RINs") and freight and distribution expenses. For the three months ended March 31, 2016 and 2015, cost of product sold excluded depreciation and amortization of approximately $1.5 million and $1.6 million, respectively. Direct operating expenses (exclusive of depreciation and amortization) includes direct costs of labor, maintenance and services, energy and utility costs, property taxes, environmental compliance costs as well as chemicals and catalysts and other direct operating expenses. Direct operating expenses also include allocated share-based compensation from CVR Energy and its subsidiaries, as discussed in Note 4 ("Share-Based Compensation"). For the three months ended March 31, 2016 and 2015, direct operating expenses excluded depreciation and amortization of approximately $29.4 million and $31.9 million, respectively. Selling, general and administrative expenses (exclusive of depreciation and amortization) consist primarily of direct and allocated legal expenses, treasury, accounting, marketing, human resources, information technology and maintaining the corporate and administrative offices in Texas and Kansas. Selling, general and administrative expenses also include allocated share-based compensation from CVR Energy and its subsidiaries as discussed in Note 4 ("Share-Based Compensation"). For the three months ended March 31, 2016 and 2015, selling, general and administrative expenses excluded depreciation and amortization of approximately $0.6 million and $0.5 million, respectively. |
Long-Term Debt |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Long-Term Debt | (8) Long-Term Debt Long-term debt consisted of the following:
During the first quarter of 2016, the Partnership adopted ASU 2015-03, which requires that costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. Prior to adoption of the ASU, all debt issuance costs were presented as assets. As a result of adoption of the standard, debt issuance costs of $6.0 million and $6.2 million were reclassified as a direct deduction from the carrying value of the related debt balances as of March 31, 2016 and December 31, 2015, respectively, in the Condensed Consolidated Balance Sheets. Debt issuance costs related to the asset-based lending facilities continue to be presented as assets in the Condensed Consolidated Balance Sheets. 2022 Senior Notes The Partnership has $500.0 million aggregate principal amount of 6.5% Senior Notes due 2022 (the "2022 Notes") outstanding, which were issued by CVR Refining, LLC ("Refining LLC") and Coffeyville Finance Inc. ("Coffeyville Finance") on October 23, 2012. The 2022 Notes were issued at par and mature on November 1, 2022, unless earlier redeemed or repurchased by the issuers. Interest is payable on the 2022 Notes semi-annually on May 1 and November 1 of each year, commencing on May 1, 2013. The 2022 Notes contain customary covenants for a financing of this type that limit, subject to certain exceptions, the incurrence of additional indebtedness or guarantees, the creation of liens on assets, the ability to dispose of assets, the ability to make certain payments on contractually subordinated debt, the ability to merge, consolidate with or into another entity and the ability to enter into certain affiliate transactions. The 2022 Notes provide that the Partnership can make distributions to holders of its common units provided, among other things, it has a minimum fixed charge coverage ratio and there is no default or event of default under the 2022 Notes. As of March 31, 2016, the Partnership was in compliance with the covenants contained in the 2022 Notes. At March 31, 2016, the estimated fair value of the 2022 Notes was approximately $442.5 million. This estimate of fair value is Level 2 as it was determined by quotations obtained from a broker dealer who makes a market in these and similar securities. Amended and Restated Asset Based (ABL) Credit Facility The Partnership has a senior secured asset based revolving credit facility (the "Amended and Restated ABL Credit Facility") with a group of lenders and Wells Fargo Bank, National Association ("Wells Fargo"), as administrative agent and collateral agent. The Amended and Restated ABL Credit Facility has an aggregate principal amount of up to $400.0 million with an incremental facility, which permits an increase in borrowings of up to $200.0 million subject to receipt of additional lender commitments and certain other conditions. The proceeds of the loans may be used for capital expenditures and working capital and general corporate purposes of the Partnership and its subsidiaries. The Amended and Restated ABL Credit Facility provides for loans and letters of credit in an amount up to the aggregate availability under the facility, subject to meeting certain borrowing base conditions, with sub-limits of 10% of the total facility commitment for swingline loans and 90% of the total facility commitment for letters of credit. The Amended and Restated ABL Credit Facility is scheduled to mature on December 20, 2017. The Amended and Restated ABL Credit Facility also contains customary covenants for a financing of this type that limit the ability of the Partnership and its subsidiaries to, among other things, incur liens, engage in a consolidation, merger, purchase or sale of assets, pay dividends, incur indebtedness, make advances, investments and loans, enter into affiliate transactions, issue equity interests or create subsidiaries and unrestricted subsidiaries. The Amended and Restated ABL Credit Facility also contains a fixed charge coverage ratio financial covenant, as defined therein. The Partnership was in compliance with the covenants of the Amended and Restated ABL Credit Facility as of March 31, 2016. As of March 31, 2016, the Partnership had availability under the Amended and Restated ABL Credit Facility of $245.3 million and had letters of credit outstanding of approximately $28.0 million. There were no borrowings outstanding under the Amended and Restated ABL Credit Facility as of March 31, 2016. Availability under the Amended and Restated ABL Credit Facility was limited by borrowing base conditions as of March 31, 2016. Intercompany Credit Facility The Partnership maintains a $250.0 million senior unsecured revolving credit facility (the "intercompany credit facility") with CRLLC as the lender, to be used to fund growth capital expenditures. The intercompany credit facility has a term of six years and bears interest at a rate of LIBOR plus 3% per annum, payable quarterly. The intercompany credit facility contains covenants that require the Partnership to, among other things, notify CRLLC of the occurrence of any default or event of default and provide CRLLC with information in respect of the Partnership's business and financial status as it may reasonably require, including, but not limited to, copies of its unaudited quarterly financial statements and its audited annual financial statements. The Partnership was in compliance with the covenants of the intercompany credit facility as of March 31, 2016. In addition, the intercompany credit facility contains customary events of default, including, among others, failure to pay any sum payable when due; the occurrence of a default under other indebtedness in excess of $25.0 million; and the occurrence of an event that results in either (i) CRLLC no longer directly or indirectly controlling the general partner, or (ii) CRLLC and its affiliates no longer owning a majority of the Partnership's equity interests. As of March 31, 2016, the Partnership had borrowings of $31.5 million outstanding and $218.5 million available under the intercompany credit facility. Capital Lease Obligations CVR Refining maintains two leases, accounted for as a capital lease and a finance obligation, related to Magellan Pipeline Terminals, L.P. ("Magellan Pipeline") and Excel Pipeline LLC ("Excel Pipeline"). The underlying assets and related depreciation are included in property, plant and equipment. The capital lease relates to a sales-lease back agreement with Sunoco Pipeline, L.P. for its membership interest in the Excel Pipeline. The lease has 163 months remaining through September 2029. The financing agreement relates to the Magellan Pipeline terminals, bulk terminal and loading facility. The lease has 162 months remaining and will expire in September 2029. |
Partners' Capital and Partnership Distributions |
3 Months Ended | ||||||||
---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||
Equity [Abstract] | |||||||||
Partners' Capital and Partnership Distributions | (9) Partners' Capital and Partnership Distributions The Partnership had two types of partnership interests outstanding at March 31, 2016:
At March 31, 2016, the Partnership had a total of 147,600,000 common units issued and outstanding, of which 97,315,764 common units were owned by CVR Refining Holdings representing approximately 66% of the total Partnership common units outstanding. The board of directors of the Partnership's general partner has adopted a policy for the Partnership to distribute all available cash generated on a quarterly basis. Cash distributions will be made to the common unitholders of record on the applicable record date, generally within 60 days after the end of each quarter. Available cash for distribution for each quarter will be determined by the board of directors of the general partner following the end of such quarter. Available cash for distribution for each quarter will generally equal Adjusted EBITDA reduced for (i) cash needed for debt service, (ii) reserves for environmental and maintenance capital expenditures, (iii) reserves for major scheduled turnaround expenses and, (iv) to the extent applicable, reserves for future operating or capital needs that the board of directors of the general partner deems necessary or appropriate, if any. Adjusted EBITDA represents EBITDA (net income before interest expense and other financing costs, net of interest income; income tax expense; and depreciation and amortization) adjusted for (i) FIFO impact (favorable) unfavorable, (ii) share-based compensation, non-cash, (iii) loss on extinguishment of debt, (iv) major scheduled turnaround expenses, (v) (gain) loss on derivatives, net, and (vi) current period settlements on derivative contracts. Available cash for distribution may be increased by the release of previously established cash reserves, if any, and other excess cash, at the discretion of the board of directors of the general partner. The board of directors of the general partner may modify the cash distribution policy at any time, and the partnership agreement does not require the board of directors of the general partner to make distributions at all. |
Net Income (Loss) per Common Unit |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net Income (Loss) per Common Unit | (10) Net Income (Loss) per Common Unit The Partnership's net income (loss) is allocated wholly to the common units as the general partner does not have an economic interest. Basic and diluted net income (loss) per common unit is calculated by dividing net income (loss) by the weighted-average number of common units outstanding during the period and, when applicable, giving effect to unvested common units granted under the CVR Refining LTIP. There were no dilutive awards outstanding during the three months ended March 31, 2016 and 2015, as all unvested awards under the CVR Refining LTIP were liability-classified awards. The following table illustrates the Partnership's calculation of net income per common unit for the three months ended March 31, 2016 and 2015:
|
Commitments and Contingencies |
3 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Commitments and Contingencies Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Commitments and Contingencies | (11) Commitments and Contingencies Leases and Unconditional Purchase Obligations The minimum required payments for CVR Refining's operating lease agreements and unconditional purchase obligations are as follows:
CVR Refining leases various equipment, including real properties, under long-term operating leases expiring at various dates. For each of the three months ended March 31, 2016 and 2015, lease expense totaled approximately $0.5 million. The lease agreements have various remaining terms. Some agreements are renewable, at CVR Refining's option, for additional periods. It is expected, in the ordinary course of business, that leases will be renewed or replaced as they expire. Additionally, in the normal course of business, CVR Refining has long-term commitments to purchase storage capacity and pipeline transportation services. For the three months ended March 31, 2016 and 2015, total expense of approximately $29.9 million and $25.7 million, respectively, was incurred related to long-term commitments. Crude Oil Supply Agreement On August 31, 2012, CRRM and Vitol Inc. ("Vitol") entered into an Amended and Restated Crude Oil Supply Agreement (as amended, the "Vitol Agreement"). Under the Vitol Agreement, Vitol supplies the petroleum business with crude oil and intermediation logistics, which helps to reduce the Partnership's inventory position and mitigate crude oil pricing risk. The Vitol Agreement will automatically renew for successive one-year terms (each such term, a "Renewal Term") unless either party provides the other with notice of nonrenewal at least 180 days prior to expiration of any Renewal Term. The Vitol Agreement currently extends through December 31, 2016. Litigation From time to time, CVR Refining is involved in various lawsuits arising in the normal course of business, including matters such as those described below under "Environmental, Health and Safety ("EHS") Matters." Liabilities related to such litigation are recognized when the related costs are probable and can be reasonably estimated. These provisions are reviewed at least quarterly and adjusted to reflect the impacts of negotiations, settlements, rulings, advice of legal counsel, and other information and events pertaining to a particular case. It is possible that management's estimates of the outcomes will change due to uncertainties inherent in litigation and settlement negotiations. Except as described below, there were no new proceedings or material developments in proceedings that CVR Refining previously reported in its 2015 Form 10-K. In the opinion of management, the ultimate resolution of any other litigation matters is not expected to have a material adverse effect on the accompanying condensed consolidated financial statements. There can be no assurance that management's beliefs or opinions with respect to liability for potential litigation matters will prove to be accurate. Environmental, Health and Safety ("EHS") Matters CRRM, Coffeyville Resources Crude Transportation, LLC ("CRCT"), Coffeyville Resources Terminal, LLC ("CRT") and Wynnewood Refining Company, LLC ("WRC") are subject to various stringent federal, state, and local EHS rules and regulations. Liabilities related to EHS matters are recognized when the related costs are probable and can be reasonably estimated. Estimates of these costs are based upon currently available facts, existing technology, site-specific costs, and currently enacted laws and regulations. In reporting EHS liabilities, no offset is made for potential recoveries. CRRM, CRCT, WRC and CRT own and/or operate manufacturing and ancillary operations at various locations directly related to petroleum refining and distribution. Therefore, CRRM, CRCT, WRC and CRT have exposure to potential EHS liabilities related to past and present EHS conditions at these locations. Under the Comprehensive Environmental Response, Compensation, and Liability Act ("CERCLA"), the Resource Conservation and Recovery Act ("RCRA"), and related state laws, certain persons may be liable for the release or threatened release of hazardous substances. These persons include the current owner or operator of property where a release or threatened release occurred, any persons who owned or operated the property when the release occurred, and any persons who disposed of, or arranged for the transportation or disposal of, hazardous substances at a contaminated property. Liability under CERCLA is strict, and under certain circumstances, joint and several, so that any responsible party may be held liable for the entire cost of investigating and remediating the release of hazardous substances. Similarly, the Oil Pollution Act generally subjects owners and operators of facilities to strict, joint and several liability for all containment and clean-up costs, natural resource damages, and potential governmental oversight costs arising from oil spills into the waters of the United States, which has been broadly interpreted to include most water bodies including intermittent streams. CRRM, CRCT, WRC and CRT are subject to extensive and frequently changing federal, state and local environmental and health and safety laws and regulations governing the emission and release of hazardous substances into the environment, the treatment and discharge of waste water and the storage, handling, use and transportation of petroleum and the characteristics and composition of gasoline and diesel fuels. The ultimate impact of complying with evolving laws and regulations is not always clearly known or determinable due in part to the fact that the Partnership's operations may change over time and certain implementing regulations for laws, such as the federal Clean Air Act, have not yet been finalized, are under governmental or judicial review or are being revised. These laws and regulations could result in increased capital, operating and compliance costs. As previously reported, CVR Refining is party to, or otherwise subject to: (i) administrative orders and consent decrees with federal, state and local environmental authorities, as applicable, addressing corrective actions under RCRA, the Clean Air Act and the Clean Water Act; (ii) the Mobile Source Air Toxic II ("MSAT II") rule which requires reductions of benzene in gasoline; (iii) the Renewable Fuel Standard ("RFS"), which requires refiners to either blend "renewable fuels" in with their transportation fuels or purchase renewable fuel credits, known as RINs, in lieu of blending; and (iv) "Tier 3" gasoline sulfur standards. Except as otherwise described below, there have been no new developments or material changes to the environmental accruals or expected capital expenditures related to compliance with the foregoing environmental matters from those provided in the 2015 Form 10-K. CRRM, CRCT, WRC and CRT each believe it is in substantial compliance with existing EHS rules and regulations. There can be no assurance that the EHS matters described or referenced herein or other EHS matters which may develop in the future will not have a material adverse effect on CVR Refining's business, financial condition or results of operations. At March 31, 2016, CVR Refining's Condensed Consolidated Balance Sheets included total environmental accruals of $3.5 million, compared with $3.6 million at December 31, 2015. Management periodically reviews and, as appropriate, revises its environmental accruals. Based on current information and regulatory requirements, management believes that the accruals established for environmental expenditures are adequate. Environmental expenditures are capitalized when such expenditures are expected to result in future economic benefits. For the three months ended March 31, 2016 and 2015, capital expenditures were approximately $3.6 million and $10.6 million, respectively. These expenditures were incurred for environmental compliance and efficiency of the operations. The cost of RINs for the three months ended March 31, 2016 and 2015 was approximately $43.1 million and $36.6 million, respectively. As of March 31, 2016 and December 31, 2015, CVR Refining's biofuel blending obligation was approximately $24.3 million and $9.5 million, respectively, which is recorded in accrued expenses and other current liabilities in the Condensed Consolidated Balance Sheets. |
Fair Value Measurements |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Measurements | (12) Fair Value Measurements In accordance with ASC Topic 820 — Fair Value Measurements and Disclosures ("ASC 820"), the Partnership utilizes the market approach to measure fair value for its financial assets and liabilities. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets, liabilities or a group of assets or liabilities, such as a business. ASC 820 utilizes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three broad levels. The following is a brief description of those three levels:
The following table sets forth the assets and liabilities measured at fair value on a recurring basis, by input level, as of March 31, 2016 and December 31, 2015:
As of March 31, 2016 and December 31, 2015, the only financial assets and liabilities that are measured at fair value on a recurring basis are CVR Refining's derivative instruments and uncommitted biofuel blending obligation. Additionally, the fair value of the debt issuances is disclosed in Note 8 ("Long-Term Debt"). The commodity derivative contracts and the uncommitted biofuel blending obligation, which use fair value measurements and are valued using broker quoted market prices of similar instruments, are considered level 2 inputs. CVR Refining had no transfers of assets or liabilities between any of the above levels during the three months ended March 31, 2016. |
Derivative Financial Instruments |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Financial Instruments | (13) Derivative Financial Instruments Loss on derivatives, net and current period settlements on derivative contracts were as follows:
CVR Refining is subject to price fluctuations caused by supply conditions, weather, economic conditions, interest rate fluctuations and other factors. To manage price risk on crude oil and other inventories and to fix margins on certain future production, CVR Refining from time to time enters into various commodity derivative transactions. CVR Refining has adopted accounting standards which impose extensive record-keeping requirements in order to designate a derivative financial instrument as a hedge. CVR Refining holds derivative instruments, such as exchange-traded crude oil futures and certain over-the-counter forward swap agreements, which it believes provide an economic hedge on future transactions, but such instruments are not designated as hedges for GAAP purposes. Gains or losses related to the change in fair value and periodic settlements of these derivative instruments are classified as gain (loss) on derivatives, net in the Condensed Consolidated Statements of Operations. There are no premiums paid or received at inception of the derivative contracts and upon settlement, there is no cost recovery associated with these contracts. CVR Refining maintains a margin account to facilitate other commodity derivative activities. A portion of this account may include funds available for withdrawal. These funds are included in cash and cash equivalents within the Condensed Consolidated Balance Sheets. The maintenance margin balance is included within other current assets within the Condensed Consolidated Balance Sheets. Dependent upon the position of the open commodity derivatives, the amounts are accounted for as other current assets or other current liabilities within the Condensed Consolidated Balance Sheets. From time to time, CVR Refining may be required to deposit additional funds into this margin account. For the three months ended March 31, 2016 and 2015, the Partnership recognized net losses of $0.3 million and $1.0 million, respectively, which are recorded in loss on derivatives, net in the Condensed Consolidated Statement of Operations. Commodity Swaps CVR Refining enters into commodity swap contracts in order to fix the margin on a portion of future production. Additionally, CVR Refining may enter into price and basis swaps in order to fix the price on a portion of its commodity purchases and product sales. The physical volumes are not exchanged and these contracts are net settled with cash. The contract fair value of the commodity swaps is reflected on the Condensed Consolidated Balance Sheets with changes in fair value currently recognized in the Condensed Consolidated Statements of Operations. Quoted prices for similar assets or liabilities in active markets (Level 2) are considered to determine the fair values for the purpose of marking to market the hedging instruments at each period end. At December 31, 2015, CVR Refining had open commodity hedging instruments consisting of 2.5 million barrels of crack spreads, primarily to fix the margin on a portion of its future gasoline and distillate production. During the first quarter of 2016, the Partnership settled a number of the open crack spread positions and entered into offsetting positions to effectively lock the gain on the remaining open positions to be settled during 2016. At March 31, 2016, the Partnership had open commodity hedging instruments consisting of 0.6 million barrels net of crack spreads and 1.0 million barrels of price and basis swaps. The fair value of the outstanding contracts at March 31, 2016 was a net unrealized gain of $22.0 million, of which $22.1 million was included in current assets and $0.1 million was included in current liabilities. For the three months ended March 31, 2016 and 2015, CVR Refining recognized a net loss of $0.9 million and a net loss of $50.4 million, respectively. These recognized losses are recorded in loss on derivatives, net in the Condensed Consolidated Statements of Operations. Counterparty Credit Risk CVR Refining's exchange-traded crude oil futures and certain over-the-counter forward swap agreements are potentially exposed to concentrations of credit risk as a result of economic conditions and periods of uncertainty and illiquidity in the credit and capital markets. CVR Refining manages credit risk on its exchange-traded crude oil futures by completing trades with an exchange clearinghouse, which subjects the trades to mandatory margin requirements until the contract settles. CVR Refining also monitors the creditworthiness of its commodity swap counterparties and assesses the risk of nonperformance on a quarterly basis. Counterparty credit risk identified as a result of this assessment is recognized as a valuation adjustment to the fair value of the commodity swaps recorded in the Condensed Consolidated Balance Sheets. As of March 31, 2016, the counterparty credit risk adjustment was not material to the condensed consolidated financial statements. Additionally, CVR Refining does not require any collateral to support commodity swaps into which it enters; however, it does have master netting arrangements that allow for the setoff of amounts receivable from and payable to the same party, which mitigates the risk associated with nonperformance. Offsetting Assets and Liabilities The commodity swaps and other commodity derivatives agreements discussed above include multiple derivative positions with a number of counterparties for which CVR Refining has entered into agreements governing the nature of the derivative transactions. Each of the counterparty agreements provides for the right to setoff each individual derivative position to arrive at the net receivable due from the counterparty or payable owed by CVR Refining. As a result of the right to setoff, CVR Refining's recognized assets and liabilities associated with the outstanding derivative positions have been presented net in the Condensed Consolidated Balance Sheets. In accordance with guidance issued by the FASB related to "Disclosures about Offsetting Assets and Liabilities," the tables below outline the gross amounts of the recognized assets and liabilities and the gross amounts offset in the Condensed Consolidated Balance Sheets for the various types of open derivative positions. The offsetting assets and liabilities for CVR Refining's derivatives as of March 31, 2016 are recorded as current assets and current liabilities in prepaid expenses and other current assets and accrued expenses and other current liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows:
The offsetting assets and liabilities for CVR Refining's derivatives as of December 31, 2015 are recorded as current assets and current liabilities in prepaid expenses and other current assets and accrued expenses and other current liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows:
|
Related Party Transactions |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Related Party Transactions [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Related Party Transactions | (14) Related Party Transactions CVR Refining is party to, or otherwise subject to certain agreements with CVR Energy and its subsidiaries (including CVR Partners and its subsidiary) that govern the business relations among each party including: the (i) Feedstock and Shared Services Agreement; (ii) Coke Supply Agreement; (iii) Environmental Agreement; (iv) Services Agreement and (v) Limited Partnership Agreement. Except as otherwise described below, there have been no new developments or material changes to these agreements from those provided in the 2015 Form 10-K. Amounts owed to CVR Refining and CRRM from CVR Energy and its subsidiaries with respect to these agreements are included in accounts receivable and prepaid expenses and other current assets on the Condensed Consolidated Balance Sheets. Conversely, amounts owed to CVR Energy and its subsidiaries by CVR Refining and CRRM with respect to these agreements are included in accounts payable, personnel accruals, accrued expenses and other current liabilities, long-term debt and other long-term liabilities, on CVR Refining's Condensed Consolidated Balance Sheets. Feedstock and Shared Services Agreement CRRM is party to a feedstock and shared services agreement with Coffeyville Resources Nitrogen Fertilizers, LLC ("CRNF") under which the two parties provide feedstocks and other services to one another. These feedstocks and services are utilized in the respective production processes of CRRM's Coffeyville, Kansas refinery and CRNF's nitrogen fertilizer plant. Pursuant to the feedstock agreement, CRRM and CRNF have agreed to transfer hydrogen to one another; provided, CRRM is not required to sell hydrogen to CRNF if such hydrogen is required for operation of CRRM's refinery, if such sale would adversely affect the Partnership's classification as a partnership for federal income tax purposes, or if such sale would not be in CRRM's best interest. Net monthly sales of hydrogen to CRNF have been reflected as net sales for CVR Refining, when applicable. Net monthly receipts of hydrogen from CRNF have been reflected in cost of product sold (exclusive of depreciation and amortization) for CVR Refining. For the three months ended March 31, 2016 and 2015, CVR Refining recognized $1.1 million and $6.5 million, respectively, of cost of product sold (exclusive of depreciation and amortization) related to the purchase of hydrogen from the nitrogen fertilizer facility. At March 31, 2016 and December 31, 2015, payables included in accounts payable on the Condensed Consolidated Balance Sheets associated with unpaid balances related to hydrogen were approximately $0.0 million and $0.5 million, respectively. CRNF is also obligated to make available to CRRM any nitrogen produced by the Linde air separation plant that is not required for the operation of the nitrogen fertilizer plant, as determined by CRNF in a commercially reasonable manner. Direct operating expenses associated with nitrogen purchased by CRRM from CRNF for the three months ended March 31, 2016 and 2015 were nominal. No amounts were paid by CRNF to CRRM for any of the periods presented. The agreement also provides a mechanism pursuant to which CRNF transfers a tail gas stream to CRRM. For each of the three months ended March 31, 2016 and 2015, direct operating expenses generated from the purchase of tail gas from CRNF were nominal. In April 2011, in connection with the tail gas stream, CRRM installed a pipe between the Coffeyville, Kansas refinery and the nitrogen fertilizer plant to transfer the tail gas. CRNF agreed to pay CRRM the cost of installing the pipe over the next three years and in the fourth year provided an additional 15% to cover the cost of capital. At March 31, 2016 and December 31, 2015, a liability of approximately $0.2 million was included in other current liabilities and approximately $0.7 million and $0.8 million, respectively, was included in other non-current liabilities in the Condensed Consolidated Balance Sheets. At March 31, 2016 and December 31, 2015, payables were approximately $0.0 million and $0.2 million, respectively, and were included in accounts payable on the Condensed Consolidated Balance Sheets associated with amounts yet to be paid related to components of the feedstock and shared services agreement, other than amounts associated with hydrogen purchases discussed above. At March 31, 2016 and December 31, 2015, receivables of approximately $0.8 million and $0.7 million, respectively, were included in prepaid expenses and other current assets on the Condensed Consolidated Balance Sheets associated with receivables related to components of the feedstock and shared services agreement. Coke Supply Agreement CRRM is party to a coke supply agreement with CRNF pursuant to which CRRM supplies CRNF with pet coke. This agreement provides that CRRM must deliver to CRNF during each calendar year an annual required amount of pet coke equal to the lesser of (i) 100 percent of the pet coke produced at CRRM's Coffeyville, Kansas petroleum refinery or (ii) 500,000 tons of pet coke. CRNF is also obligated to purchase this annual required amount. If during a calendar month CRRM produces more than 41,667 tons of pet coke, then CRNF will have the option to purchase the excess at the purchase price provided for in the agreement. If CRNF declines to exercise this option, CRRM may sell the excess to a third party. The price CRNF pays pursuant to the pet coke supply agreement is based on the lesser of a pet coke price derived from the price received for urea ammonium nitrate ("UAN") (the "UAN-based price") or a pet coke price index. The UAN-based price begins with a pet coke price of $25 per ton based on a price per ton for UAN that excludes transportation cost ("netback price") of $205 per ton, and adjusts up or down $0.50 per ton for every $1.00 change in the netback price. The UAN-based price has a ceiling of $40 per ton and a floor of $5 per ton. CRNF pays any taxes associated with the sale, purchase, transportation, delivery, storage or consumption of the pet coke. Amounts payable under the feedstock and shared services agreements can be offset with any amount receivable for pet coke. Net sales associated with the transfer of pet coke from CRRM to CRNF were approximately $0.4 million and $2.1 million for the three months ended March 31, 2016 and 2015, respectively. Receivables of approximately $0.1 million and $0.3 million, related to the coke supply agreement were included in accounts receivable on the Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015, respectively. Services Agreement CVR Refining obtains certain management and other services from CVR Energy pursuant to a services agreement between the Partnership, CVR Refining GP and CVR Energy. Net amounts incurred under the services agreement for the three months ended March 31, 2016 and 2015 were as follows:
At March 31, 2016 and December 31, 2015, payables and liabilities of approximately $7.5 million and $13.9 million, respectively, were included in accounts payable, personnel accruals and accrued expenses and other current liabilities on the Condensed Consolidated Balance Sheets with respect to amounts billed in accordance with the services agreement. Limited Partnership Agreement The partnership agreement provides that the Partnership will reimburse its general partner for all direct and indirect expenses it incurs or payments it makes on behalf of the Partnership (including salary, bonus, incentive compensation and other amounts paid to any person to perform services for the Partnership or for its general partner in connection with operating the Partnership). For the three months ended March 31, 2016 and 2015, approximately $1.9 million and $2.3 million, respectively, were incurred under the partnership agreement. Intercompany Credit Facility As of March 31, 2016, the Partnership had borrowings of $31.5 million outstanding under the intercompany credit facility. For each of the three months ended March 31, 2016 and 2015, the Partnership paid $0.3 million of interest to CRLLC. See Note 8 ("Long-Term Debt") for additional discussion of the intercompany credit facility. Insight Portfolio Group Insight Portfolio Group LLC ("Insight Portfolio Group") is an entity formed by Mr. Carl C. Icahn in order to maximize the potential buying power of a group of entities with which Mr. Icahn has a relationship in negotiating with a wide range of suppliers of goods, services and tangible and intangible property at negotiated rates. In January 2013, CVR Energy acquired a minority equity interest in Insight Portfolio Group. The Partnership participates in Insight Portfolio Group's buying group through its relationship with CVR Energy. The Partnership may purchase a variety of goods and services as members of the buying group at prices and on terms that management believes would be more favorable than those which would be achieved on a stand-alone basis. |
Basis of Presentation (Policies) |
3 Months Ended |
---|---|
Mar. 31, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Basis of Presentation | The accompanying condensed consolidated financial statements have been prepared in accordance with U.S. generally accepted accounting principles ("GAAP") and in accordance with the rules and regulations of the Securities and Exchange Commission (the "SEC"). These condensed consolidated financial statements should be read in conjunction with the December 31, 2015 audited consolidated financial statements and notes thereto included in CVR Refining's Annual Report on Form 10-K for the year ended December 31, 2015, which was filed with the SEC on February 19, 2016 (the "2015 Form 10-K"). The condensed consolidated financial statements include certain selling, general and administrative expenses (exclusive of depreciation and amortization) and direct operating expenses (exclusive of depreciation and amortization) that CVR Energy and its affiliates incurred on behalf of the Partnership. These related party transactions are governed by the services agreement. See Note 14 ("Related Party Transactions") for additional discussion of the services agreement and billing and allocation of certain costs. The amounts charged or allocated to the Partnership are not necessarily indicative of the cost that the Partnership would have incurred had it operated as an independent entity. In the opinion of the Partnership's management, the accompanying condensed consolidated financial statements reflect all adjustments (consisting only of normal recurring adjustments) that are necessary to fairly present the financial position of the Partnership as of March 31, 2016 and December 31, 2015, the results of operations of the Partnership for the three month periods ended March 31, 2016 and 2015, the changes in partners' capital for the Partnership for the three month period ended March 31, 2016 and the cash flows of the Partnership for the three month periods ended March 31, 2016 and 2015. The preparation of the condensed consolidated financial statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results could differ from those estimates. Results of operations and cash flows for the interim periods presented are not necessarily indicative of the results that will be realized for the year ending December 31, 2016 or any other interim or annual period. |
Recent Accounting Pronouncements | In May 2014, the Financial Accounting Standards Board ("FASB") issued ASU No. 2014-09, "Revenue from Contracts with Customers" ("ASU 2014-09"), which requires an entity to recognize the amount of revenue to which it expects to be entitled for the transfer of promised goods or services to customers. The standard was originally effective for interim and annual periods beginning after December 15, 2016 and permits the use of either the retrospective or cumulative effect transition method. Early adoption is not permitted. On July 9, 2015, the FASB approved a one-year deferral of the effective date making the standard effective for interim and annual periods beginning after December 15, 2017. The FASB will continue to permit entities to adopt the standard on the original effective date if they choose. The Partnership has not yet selected a transition method and is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures. In April 2015, the FASB issued ASU 2015-03, "Simplifying the Presentation of Debt Issuance Costs" ("ASU 2015-03"). The new standard requires that all costs incurred to issue debt be presented in the balance sheet as a direct deduction from the carrying value of the debt. The standard is effective for interim and annual periods beginning after December 15, 2015 and is required to be applied on a retrospective basis. Early adoption is permitted. The Partnership adopted ASU 2015-03 as of January 1, 2016 and applied the standard retrospectively to the Condensed Consolidated Balance Sheet. Refer to Note 8 ("Long-Term Debt") for further details. In February 2016, the FASB issued ASU 2016-02, “Leases” (“ASU 2016-02”). The new standard revises accounting for operating leases by a lessee, among other changes, and requires a lessee to recognize a liability to make lease payments and an asset representing its right to use the underlying asset for the lease term in the balance sheet. The standard is effective for the first interim and annual periods beginning after December 15, 2018, with early adoption permitted. At adoption, ASU 2016-02 will be applied using a modified retrospective approach. The Partnership is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures. |
Share-Based Compensation (Tables) |
3 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of share-based compensation activity | A summary of phantom unit activity and changes under the CVR Refining LTIP during the three months ended March 31, 2016 is presented below:
|
Inventories (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of inventories | Inventories consisted of the following:
|
Property, Plant and Equipment (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summary of costs for property, plant, and equipment | roperty, plant and equipment consisted of the following:
|
Long-Term Debt (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of long-term debt | Long-term debt consisted of the following:
|
Net Income (Loss) per Common Unit (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of computations of the basic and diluted earnings per share | The following table illustrates the Partnership's calculation of net income per common unit for the three months ended March 31, 2016 and 2015:
|
Commitments and Contingencies (Tables) |
3 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Commitments and Contingencies Disclosure [Abstract] | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of minimum required payments for CVR Refining's operating lease agreements and unconditional purchase obligations | The minimum required payments for CVR Refining's operating lease agreements and unconditional purchase obligations are as follows:
|
Fair Value Measurements (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of 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, as of March 31, 2016 and December 31, 2015:
|
Derivative Financial Instruments (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Components of gain (loss) on derivatives, net and current period settlements on derivative contracts | Loss on derivatives, net and current period settlements on derivative contracts were as follows:
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of offsetting assets | The offsetting assets and liabilities for CVR Refining's derivatives as of March 31, 2016 are recorded as current assets and current liabilities in prepaid expenses and other current assets and accrued expenses and other current liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows:
The offsetting assets and liabilities for CVR Refining's derivatives as of December 31, 2015 are recorded as current assets and current liabilities in prepaid expenses and other current assets and accrued expenses and other current liabilities, respectively, in the Condensed Consolidated Balance Sheets as follows:
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of offsetting liabilities |
|
Related Party Transactions (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Related Party Transactions [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of related party transactions | Net amounts incurred under the services agreement for the three months ended March 31, 2016 and 2015 were as follows:
|
Share-Based Compensation - Long-Term Incentive Plan, CVR Energy (Details) $ in Millions |
3 Months Ended |
---|---|
Mar. 31, 2016
USD ($)
| |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Percentage of allocation of share-based compensation expense | 100.00% |
CVR Energy Long Term Incentive Plan | Performance unit awards | Chief Executive Officer | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |
Compensation expenses | $ 0.4 |
Unrecognized compensation cost | $ 1.3 |
Period for recognition for unrecognized compensation expense | 9 months |
Share based arrangement liability | $ 0.4 |
Share Based Compensation - Summary of Phantom Unit Activity and Changes Under CVR Refining LTIP(Details) - CVR Refining LTIP - Phantom Unit Plan |
3 Months Ended |
---|---|
Mar. 31, 2016
$ / shares
shares
| |
Phantom Units | |
Non-vested at January 1, 2016 (in shares) | shares | 511,591 |
Granted (in shares) | shares | 0 |
Vested (in shares) | shares | 0 |
Forfeited (in shares) | shares | (6,911) |
Non-vested at March 31, 2016 (in shares) | shares | 504,680 |
Weighted- Average Grant-Date Fair Value | |
Non-vested at January 1, 2016 (in dollars per share) | $ / shares | $ 19.68 |
Granted (in dollars per share) | $ / shares | 0.00 |
Vested (in dollars per share) | $ / shares | 0.00 |
Forfeited (in dollars per share) | $ / shares | 19.51 |
Non-vested at March 16, 2016 (in dollars per share) | $ / shares | $ 19.69 |
Inventories (Details) - USD ($) $ in Millions |
Mar. 31, 2016 |
Dec. 31, 2015 |
---|---|---|
Inventory Disclosure [Abstract] | ||
Finished goods | $ 90.3 | $ 104.7 |
Raw materials and precious metals | 75.0 | 72.6 |
In-process inventories | 21.2 | 35.7 |
Parts and supplies | 40.3 | 39.5 |
Total Inventories | $ 226.8 | $ 252.5 |
Property, Plant and Equipment - Additional Information (Details) - USD ($) $ in Millions |
3 Months Ended | ||
---|---|---|---|
Mar. 31, 2016 |
Mar. 31, 2015 |
Dec. 31, 2015 |
|
Property, Plant and Equipment [Abstract] | |||
Capitalized interest | $ 1.5 | $ 0.4 | |
Original carrying value of assets under capital lease obligations | $ 24.8 | $ 24.8 |
Cost Classifications (Details) - USD ($) $ in Millions |
3 Months Ended | |
---|---|---|
Mar. 31, 2016 |
Mar. 31, 2015 |
|
Costs and Expenses [Abstract] | ||
Depreciation and amortization not included in cost of product sold | $ 1.5 | $ 1.6 |
Depreciation and amortization not included in direct operating expenses | 29.4 | 31.9 |
Depreciation and amortization not included in selling, general and administrative expenses | $ 0.6 | $ 0.5 |
Long-Term Debt - Schedule of Debt (Details) - USD ($) $ in Millions |
Mar. 31, 2016 |
Dec. 31, 2015 |
---|---|---|
Debt Instrument [Line Items] | ||
Total debt | $ 579.6 | $ 580.0 |
Unamortized debt issuance cost | (6.0) | (6.2) |
Current portion of capital lease obligations | (1.7) | (1.6) |
Long-term debt, net of current portion | $ 571.9 | $ 572.2 |
6.5% Second Lien Senior Secured Notes, due 2022 | ||
Debt Instrument [Line Items] | ||
Stated interest rate (as a percent) | 6.50% | 6.50% |
Senior Notes | 6.5% Second Lien Senior Secured Notes, due 2022 | ||
Debt Instrument [Line Items] | ||
Total debt | $ 500.0 | $ 500.0 |
Line of Credit | Intercompany credit facility | ||
Debt Instrument [Line Items] | ||
Total debt | 31.5 | 31.5 |
Capital Lease Obligations | ||
Debt Instrument [Line Items] | ||
Total debt | $ 48.1 | $ 48.5 |
Partners' Capital and Partnership Distributions (Details) |
3 Months Ended | |
---|---|---|
Mar. 31, 2016
partnership_interest
shares
|
Dec. 31, 2015
shares
|
|
Equity [Abstract] | ||
Number of types of partnership interests outstanding | partnership_interest | 2 | |
Common units issued (in units) | 147,600,000 | 147,600,000 |
Related Party Transaction [Line Items] | ||
Maximum period after the end of each quarter of cash distribution to common unitholders | 60 days | |
CVR Refining Holdings | ||
Related Party Transaction [Line Items] | ||
Number of issued and outstanding common units owned | 97,315,764 | |
Percentage of outstanding units owned by CVR Refining Holdings | 66.00% |
Net Income (Loss) per Common Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions |
3 Months Ended | |
---|---|---|
Mar. 31, 2016 |
Mar. 31, 2015 |
|
Earnings Per Share [Abstract] | ||
Net income (loss) | $ (68.0) | $ 46.7 |
Net income (loss) per common unit, basic (in dollars per unit) | $ (0.46) | $ 0.32 |
Net income (loss) per common unit, diluted (in dollars per unit) | $ (0.46) | $ 0.32 |
Weighted-average common units outstanding, basic (in units) | 147.6 | 147.6 |
Weighted-average common units outstanding, diluted (in units) | 147.6 | 147.6 |
Commitments and Contingencies - Crude Oil Supply Agreement (Details) - CRRM - New Vitol Agreement |
3 Months Ended |
---|---|
Mar. 31, 2016 | |
Gain Contingencies [Line Items] | |
Renewal term of agreement | 1 year |
Number of days for prior notice of nonrenewal | 180 days |
Commitments and Contingencies - Environmental, Health and Safety Matters (Details) - USD ($) $ in Millions |
3 Months Ended | ||
---|---|---|---|
Mar. 31, 2016 |
Mar. 31, 2015 |
Dec. 31, 2015 |
|
Environmental, Health, and Safety ("EHS") Matters | |||
Environmental costs capitalized in the period | $ 3.6 | $ 10.6 | |
Environmental Health and Safety Matters | |||
Environmental, Health, and Safety ("EHS") Matters | |||
Environmental accruals | 3.5 | $ 3.6 | |
Cost of renewable identification numbers | 43.1 | $ 36.6 | |
Biofuel blending obligation recorded in accrued expenses and other current liabilities | $ 24.3 | $ 9.5 |
Derivative Financial Instruments - Schedule of Gain (Loss) on Derivatives (Details) - USD ($) $ in Millions |
3 Months Ended | |
---|---|---|
Mar. 31, 2016 |
Mar. 31, 2015 |
|
Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||
Current period settlements on derivative contracts | $ 21.4 | $ (6.3) |
Loss on derivatives, net | $ (1.2) | $ (51.4) |
Derivative Financial Instruments - Additional Information (Details) bbl in Millions, $ in Millions |
3 Months Ended | 12 Months Ended | |
---|---|---|---|
Mar. 31, 2016
USD ($)
bbl
|
Mar. 31, 2015
USD ($)
|
Dec. 31, 2015
bbl
|
|
Derivative Financial Instruments | |||
Loss on derivatives, net | $ 1.2 | $ 51.4 | |
Commodity Contract | |||
Derivative Financial Instruments | |||
Loss on derivatives, net | 0.3 | 1.0 | |
Commodity swaps | |||
Derivative Financial Instruments | |||
Loss on derivatives, net | 0.9 | $ 50.4 | |
Commodity swaps | Not designated as hedges | |||
Derivative Financial Instruments | |||
Derivative asset (liability) | 22.0 | ||
Portion of net unrealized gain in current assets | 22.1 | ||
Portion of net unrealized gain in current liabilities | $ 0.1 | ||
Crack spreads | Not designated as hedges | |||
Derivative Financial Instruments | |||
Number of barrels | bbl | 0.6 | 2.5 | |
Price and basis swaps | Not designated as hedges | |||
Derivative Financial Instruments | |||
Number of barrels | bbl | 1.0 |
Derivative Financial Instruments - Offsetting Assets (Details) - Current Assets - USD ($) $ in Millions |
Mar. 31, 2016 |
Dec. 31, 2015 |
---|---|---|
Offsetting Assets [Line Items] | ||
Gross Current Assets | $ 22.4 | $ 44.8 |
Gross Amounts Offset | (0.3) | (0.1) |
Net Current Assets Presented | 22.1 | 44.7 |
Cash Collateral Not Offset | 0.0 | 0.0 |
Net Amount | 22.1 | 44.7 |
Commodity swaps | ||
Offsetting Assets [Line Items] | ||
Gross Current Assets | 22.4 | 44.8 |
Gross Amounts Offset | (0.3) | (0.1) |
Net Current Assets Presented | 22.1 | 44.7 |
Cash Collateral Not Offset | 0.0 | 0.0 |
Net Amount | $ 22.1 | $ 44.7 |
Derivative Financial Instruments Derivative Financial Instruments - Offsetting Liabilities (Details) - Current Liabilities - USD ($) $ in Millions |
Mar. 31, 2016 |
Dec. 31, 2015 |
---|---|---|
Offsetting Liabilities [Line Items] | ||
Gross Current Liabilities | $ 0.1 | $ 0.1 |
Gross Amounts Offset | 0.0 | 0.0 |
Net Current Liabilities Presented | 0.1 | 0.1 |
Cash Collateral Not Offset | 0.0 | 0.0 |
Net Amount | 0.1 | 0.1 |
Commodity swaps | ||
Offsetting Liabilities [Line Items] | ||
Gross Current Liabilities | 0.1 | 0.1 |
Gross Amounts Offset | 0.0 | 0.0 |
Net Current Liabilities Presented | 0.1 | 0.1 |
Cash Collateral Not Offset | 0.0 | 0.0 |
Net Amount | $ 0.1 | $ 0.1 |
Related Party Transactions - Additional Information (Details) - USD ($) $ in Millions |
3 Months Ended | ||
---|---|---|---|
Mar. 31, 2016 |
Mar. 31, 2015 |
Dec. 31, 2015 |
|
Services Agreement [Abstract] | |||
Direct operating expenses (exclusive of depreciation and amortization) | $ 117.7 | $ 87.0 | |
Selling, general and administrative expenses (exclusive of depreciation and amortization) | 18.5 | 18.1 | |
Accounts payable, due to affiliates | 4.8 | $ 5.4 | |
Limited Partnership Agreement | |||
Services Agreement [Abstract] | |||
Related party transaction incurred | 1.9 | 2.3 | |
CVR Energy, Inc | Services Agreement | |||
Services Agreement [Abstract] | |||
Direct operating expenses (exclusive of depreciation and amortization) | 3.0 | 4.6 | |
Selling, general and administrative expenses (exclusive of depreciation and amortization) | 12.6 | 12.6 | |
Total | 15.6 | 17.2 | |
Accounts payable, due to affiliates | 7.5 | $ 13.9 | |
CRLLC | Intercompany credit facility | |||
Services Agreement [Abstract] | |||
Intercompany credit facility | 31.5 | ||
Interest paid | $ 0.3 | $ 0.3 |
%KR:_K,"H%98,A;/;!598D23T"B&90VCB
MPW%\2L='9'QDXJ-Q/+=JT$LR(ZF-A(>1E4:O24<:"(/(BV@K,6DEQJED='Q"
MQB #,.3V_!D&(NDG\]DO1]_U$A4HMF9!JMUUO)8=_J;?31Z:>*>
MF&Y$K/&E:N[Z5NPZS6)VR'?B5][LBKIU7F6GVAS3C&RE[(1R&7C*Y5ZUGY>+
M4FP[?9JJ\Z9OR/J+3A[._>6ER5W\!U!+ P04 " 'B*)(/5E#3@(" U
M!@ & 'AL+W=O 1&@V/
MW>6#S+^T^ 502P,$% @ !XBB2&[[DYVK 0 %@0 !D !X;"]W;W)K
M 2$GL=!W7AG:?S@<4W^0PO\HXW\(N;1FA+SNC\R\;^UX@.O)3T9I>0
MUO^?V9!0NW"\]6:10F@H/21083M"D^@5"0*B7]-G.\I(W!YOK%_2=4&]1?AX G5
M3UGY-HC-**F@%KWR+SA\A:F$^TA8HG)I)67O/.H;A!(MWL9=FK0/X\W^,,'6
M 7P"\!EPR)+P,5&2^5EX4>06!V+'UG8BON#FR$,CRNA,=:>[(-0%[[78[!]R
M=HU$4\QYC.'+F#F"!?8Y!5]+<>;_P/DZ?+NJ<)O@VP\*#^L$NU6"72+8_;?$
MM9A/?R5ABYYJL$T:'4=*[$T:U(5WGLY'GM[D/;S(.]' =V$;:1RYH \OF_I?
M(WH(4K*[>TK:\']F0T'MX_$AG.TX4J/AL;M]D/F7%G\ 4$L#!!0 ( >(
MHDA0[UQ.GP$ +$# 9 >&PO=V]R:W-H965T&UL=53;;J,P$/T5BP^("03:1@2I855U'U:J^K#[[,!P46W,VD[H_OWZ0@@E
M[@NVQ^><.6/LR48N/F0+H- GH[T\!*U2PQYC6;; B-SP 7J]4W/!B-)+T6 Y
M"""5)3&*HS!,,2-='^29C;V)/.-G1;L>W@229\:(^'<$RL=#L VN@?>N:94)
MX#S#,Z_J&/2RXST24!^"Y^V^2 W" GYW,,K%'!GO)\X_S.)G=0A"8P$HE,HH
M$#U
02G'4H^$!0X\5#Z3%#2FQ(1I@XR
M@P*BS*"XLVNTPR?R [-3U7)K1X6\D?6]>:14$,GH.3+,I7PI38.:'(7J)K+/
MAK?#,!"TNSZ%IO=8_A=02P,$% @ !XBB2+;N/L^R P )A, !D !X
M;"]W;W)K2(@TDD )ETP$P8,@KO&"TFAQ Y
MH]$BD2L.AH80-(Z60I@(6MPQ6DP$@76,K:ZT[43]Z1Q.]W2)X9$ 'GOYWD*1
M8VV6F!L)N&'7ZR'F1M[!C72\8@(DV&X5G6BP.C--]0J)Z9& 'G:T1XGID7?0
M(S$]$H Q>B/I1(-5+IR>3Y@A"1CB430D
9^,-G+K5TJU&P!D41&&Y1-O2:-72BX85GHH3D"V@N"C)3$*8! D@.&Z
M\?/,SKV)/.-G1>N&O E/GAG#XM^.4-YM_="_3KS7ITJ9"9!G8.0=:T8:6?/&
M$Z3<^L_A9A]:B$7\KDDG)WW/!'_@_,,,?AZW?F!B()04RDA@W5S(GE!JE+3S
MWT'TYFF(T_Y5_<6FJ\,_8$GVG/ZICZK2T0:^=R0E/E/USKM7,N00&\&"4VG_
MO>(L%6=7BN\Q_-FW=6/;KE]9!0/-38 # 8Z$Z&L"&@AH)$!+ 'UD-J\?6.$\
M$[SS1'\8+39G'FZ0WKG"3-J-LFLZ,ZEG+SF*PPQ