x | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
Delaware | 46-3159268 | |||
(State or other Jurisdiction of Incorporation or Organization) | (IRS Employer Identification Number) | |||
4200 W. 115th Street, Suite 350 | ||||
Leawood, Kansas | 66211 | |||
(Address of Principal Executive Offices) | (Zip Code) |
Large accelerated filer | ¨ | Accelerated filer | ¨ | |||
Non-accelerated filer | x (Do not check if a smaller reporting company) | Smaller reporting company | ¨ |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
ASSETS | |||||||
Current Assets: | |||||||
Cash and cash equivalents | $ | 2,623 | $ | 2,234 | |||
Accounts receivable, net | 53,033 | 57,757 | |||||
Gas imbalances | 878 | 1,227 | |||||
Inventories | 14,754 | 13,793 | |||||
Derivative asset at fair value | 148 | — | |||||
Prepayments and other current assets | 3,615 | 2,835 | |||||
Total Current Assets | 75,051 | 77,846 | |||||
Property, plant and equipment, net | 2,007,067 | 2,025,018 | |||||
Goodwill | 343,288 | 343,288 | |||||
Intangible asset, net | 95,038 | 96,546 | |||||
Derivative asset at fair value | 55,967 | — | |||||
Unconsolidated investment | 444,074 | — | |||||
Deferred tax asset | 442,846 | 452,430 | |||||
Deferred financing costs, net | 8,344 | 6,638 | |||||
Deferred charges and other assets | 13,232 | 14,894 | |||||
Total Assets | $ | 3,484,907 | $ | 3,016,660 | |||
LIABILITIES AND PARTNERS' EQUITY | |||||||
Current Liabilities: | |||||||
Accounts payable (including $10,554 at December 31, 2015 related to variable interest entities) | $ | 17,451 | $ | 22,218 | |||
Accounts payable to related parties | 7,086 | 7,755 | |||||
Gas imbalances | 1,199 | 1,605 | |||||
Derivative liabilities at fair value | 351 | — | |||||
Accrued taxes | 15,298 | 13,844 | |||||
Accrued liabilities | 8,234 | 10,206 | |||||
Deferred revenue | 42,901 | 26,511 | |||||
Other current liabilities | 6,687 | 6,880 | |||||
Total Current Liabilities | 99,207 | 89,019 | |||||
Long-term debt | 1,426,000 | 901,000 | |||||
Other long-term liabilities and deferred credits | 6,815 | 5,143 | |||||
Total Long-term Liabilities | 1,432,815 | 906,143 | |||||
Commitments and Contingencies | |||||||
Equity: | |||||||
Class A Shareholders (47,725,000 shares outstanding at June 30, 2016 and December 31, 2015) | 189,356 | 422,310 | |||||
Class B Shareholders (109,504,440 shares outstanding at June 30, 2016 and December 31, 2015) | — | — | |||||
Total Partners' Equity | 189,356 | 422,310 | |||||
Noncontrolling interests | 1,763,529 | 1,599,188 | |||||
Total Equity | 1,952,885 | 2,021,498 | |||||
Total Liabilities and Equity | $ | 3,484,907 | $ | 3,016,660 |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(in thousands, except per share amounts) | |||||||||||||||
Revenues: | |||||||||||||||
Crude oil transportation services | $ | 93,322 | $ | 74,022 | $ | 187,894 | $ | 124,403 | |||||||
Natural gas transportation services | 28,682 | 29,041 | 57,962 | 61,189 | |||||||||||
Sales of natural gas, NGLs, and crude oil | 16,830 | 20,011 | 30,756 | 41,880 | |||||||||||
Processing and other revenues | 8,097 | 9,896 | 15,724 | 20,173 | |||||||||||
Total Revenues | 146,931 | 132,970 | 292,336 | 247,645 | |||||||||||
Operating Costs and Expenses: | |||||||||||||||
Cost of sales (exclusive of depreciation and amortization shown below) | 15,958 | 17,180 | 29,526 | 36,773 | |||||||||||
Cost of transportation services (exclusive of depreciation and amortization shown below) | 14,240 | 13,492 | 30,396 | 24,207 | |||||||||||
Operations and maintenance | 13,864 | 12,408 | 26,341 | 21,983 | |||||||||||
Depreciation and amortization | 21,576 | 20,355 | 43,268 | 40,960 | |||||||||||
General and administrative | 14,458 | 13,701 | 27,995 | 26,390 | |||||||||||
Taxes, other than income taxes | 5,639 | (271 | ) | 13,145 | 11,026 | ||||||||||
Loss on disposal of assets | 1,849 | — | 1,849 | 4,483 | |||||||||||
Total Operating Costs and Expenses | 87,584 | 76,865 | 172,520 | 165,822 | |||||||||||
Operating Income | 59,347 | 56,105 | 119,816 | 81,823 | |||||||||||
Other Income (Expense): | |||||||||||||||
Interest expense, net | (10,441 | ) | (4,479 | ) | (19,118 | ) | (7,919 | ) | |||||||
Unrealized gain on derivative instrument | 18,953 | — | 10,007 | — | |||||||||||
Equity in earnings of unconsolidated investment | 23,321 | — | 23,321 | — | |||||||||||
Other income, net | 221 | 769 | 787 | 1,481 | |||||||||||
Total Other Income (Expense) | 32,054 | (3,710 | ) | 14,997 | (6,438 | ) | |||||||||
Net income before tax | 91,401 | 52,395 | 134,813 | 75,385 | |||||||||||
Deferred income tax expense | (6,792 | ) | (1,772 | ) | (9,583 | ) | (1,772 | ) | |||||||
Net income | 84,609 | 50,623 | 125,230 | 73,613 | |||||||||||
Net income attributable to noncontrolling interests | (81,161 | ) | (45,889 | ) | (114,193 | ) | (63,757 | ) | |||||||
Net income attributable to TEGP | $ | 3,448 | $ | 4,734 | $ | 11,037 | $ | 9,856 | |||||||
Allocation of income for the three and six months ended June 30, 2015: | |||||||||||||||
Net income attributable to TEGP from the beginning of the period to May 11, 2015 | $ | 2,271 | $ | 7,393 | |||||||||||
Net income attributable to TEGP from May 12, 2015 to June 30, 2015 | 2,463 | 2,463 | |||||||||||||
Basic net income per Class A share | $ | 0.07 | $ | 0.05 | $ | 0.23 | $ | 0.05 | |||||||
Diluted net income per Class A share | $ | 0.07 | $ | 0.05 | $ | 0.23 | $ | 0.05 | |||||||
Basic average number of Class A shares outstanding | 47,725 | 47,725 | 47,725 | 47,725 | |||||||||||
Diluted average number of Class A shares outstanding | 47,734 | 47,725 | 47,725 | 47,725 |
Six Months Ended June 30, | |||||||
2016 | 2015 | ||||||
(in thousands) | |||||||
Cash Flows from Operating Activities: | |||||||
Net income | $ | 125,230 | $ | 73,613 | |||
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||||||
Depreciation and amortization | 46,272 | 42,905 | |||||
Equity in earnings of unconsolidated investment | (23,321 | ) | — | ||||
Distributions from unconsolidated investment | 23,321 | — | |||||
Noncash change in fair value of derivative financial instruments | (9,804 | ) | 41 | ||||
Deferred tax expense | 9,583 | 1,772 | |||||
Loss on disposal of assets | 1,849 | 4,483 | |||||
Changes in components of working capital: | |||||||
Accounts receivable and other | 6,613 | (10,215 | ) | ||||
Inventories | (1,683 | ) | (6,068 | ) | |||
Accounts payable and accrued liabilities | (2,398 | ) | 2,389 | ||||
Deferred revenue | 16,174 | 4,198 | |||||
Other operating, net | 1,734 | (1,495 | ) | ||||
Net Cash Provided by Operating Activities | 193,570 | 111,623 | |||||
Cash Flows from Investing Activities: | |||||||
Acquisition of unconsolidated affiliate | (436,022 | ) | — | ||||
Acquisition of Pony Express membership interest | (49,118 | ) | (700,000 | ) | |||
Capital expenditures | (28,491 | ) | (49,544 | ) | |||
Contributions to unconsolidated investment | (14,387 | ) | — | ||||
Distributions from unconsolidated investment in excess of cumulative earnings | 6,335 | — | |||||
Other investing, net | 411 | (4,648 | ) | ||||
Net Cash Used in Investing Activities | (521,272 | ) | (754,192 | ) | |||
Cash Flows from Financing Activities: | |||||||
Borrowings under revolving credit facility, net | 525,000 | 294,000 | |||||
Acquisition of Pony Express membership interest | (425,882 | ) | — | ||||
Proceeds from public offering of TEP common units, net | 261,770 | 551,673 | |||||
Distributions to noncontrolling interests | (109,551 | ) | (46,082 | ) | |||
Proceeds from private placement, net of offering costs | 90,009 | — | |||||
TEGP distributions to Class A shareholders | (18,278 | ) | — | ||||
Contributions from noncontrolling interests | 7,273 | 16,294 | |||||
Proceeds from initial public offering of Class A shares, net | — | 1,315,383 | |||||
Acquisition of Acquired TEP Units | — | (953,600 | ) | ||||
Distribution of Excess Proceeds to Exchange Right Holders | — | (334,068 | ) | ||||
Acquisition of additional Tallgrass Equity units | — | (171,948 | ) | ||||
Distributions to TEGP Predecessor, net | — | (13,533 | ) | ||||
Other financing, net | (2,250 | ) | (14,139 | ) | |||
Net Cash Provided by Financing Activities | 328,091 | 643,980 | |||||
Net Change in Cash and Cash Equivalents | 389 | 1,411 | |||||
Cash and Cash Equivalents, beginning of period | 2,234 | 867 | |||||
Cash and Cash Equivalents, end of period | $ | 2,623 | $ | 2,278 |
Schedule of Noncash Investing and Financing Activities: | |||||||
Property, plant and equipment acquired via the cash management agreement with Tallgrass Development, LP | $ | — | $ | 103,239 | |||
Contributions from noncontrolling interests settled via the cash management agreement with Tallgrass Development, LP | $ | — | $ | 21,525 | |||
Distribution to noncontrolling interests settled via the cash management agreement with Tallgrass Development, LP | $ | — | $ | 22,266 |
TEGP Predecessor | Partners' Equity (excluding noncontrolling interests) | Noncontrolling Interests | Total Equity | ||||||||||||||||
Class A Shares | Class B Shares | ||||||||||||||||||
(in thousands) | |||||||||||||||||||
Balance at January 1, 2016 | $ | — | $ | 422,310 | $ | — | $ | 1,599,188 | $ | 2,021,498 | |||||||||
Net income | — | 11,037 | — | 114,193 | 125,230 | ||||||||||||||
Acquisition of additional 31.3% membership interest in Pony Express | — | (255,617 | ) | — | (173,422 | ) | (429,039 | ) | |||||||||||
Issuance of TEP units to public, net of offering costs | — | 22,159 | — | 239,611 | 261,770 | ||||||||||||||
Distributions to noncontrolling interest | — | — | — | (109,551 | ) | (109,551 | ) | ||||||||||||
Issuance of TEP units in a private placement, net of offering costs | — | 7,592 | — | 82,417 | 90,009 | ||||||||||||||
TEGP distributions to Class A shareholders | — | (18,278 | ) | — | — | (18,278 | ) | ||||||||||||
Contributions from noncontrolling interest | — | — | — | 7,273 | 7,273 | ||||||||||||||
Noncash compensation expense | — | 642 | — | 3,820 | 4,462 | ||||||||||||||
Costs associated with equity issuance | — | (489 | ) | — | — | (489 | ) | ||||||||||||
Balance at June 30, 2016 | $ | — | $ | 189,356 | $ | — | $ | 1,763,529 | $ | 1,952,885 | |||||||||
TEGP Predecessor | Partners' Equity (excluding noncontrolling interests) | Noncontrolling Interests | Total Equity | ||||||||||||||||
Class A Shares | Class B Shares | ||||||||||||||||||
(in thousands) | |||||||||||||||||||
Balance at January 1, 2015 | $ | 146,866 | $ | — | $ | — | $ | 1,648,285 | $ | 1,795,151 | |||||||||
Net income for the period from January 1, 2015 to May 11, 2015 | 7,393 | — | — | 32,196 | $ | 39,589 | |||||||||||||
Issuance of TEP units to the public, net of offering costs | 63,520 | — | — | 488,153 | $ | 551,673 | |||||||||||||
Acquisition of additional 33.3% Pony Express membership interest | (98,446 | ) | — | — | (601,554 | ) | $ | (700,000 | ) | ||||||||||
Distributions to TEGP Predecessor | (4,108 | ) | — | — | (9,425 | ) | $ | (13,533 | ) | ||||||||||
Consolidation of TEGP Predecessor assets | (115,225 | ) | 115,225 | — | — | $ | — | ||||||||||||
Issuance of Class A shares to the public, net of offering costs | — | 1,315,383 | — | — | $ | 1,315,383 | |||||||||||||
Acquisition of Acquired TEP Units from TD | — | (953,600 | ) | — | — | $ | (953,600 | ) | |||||||||||
Distribution of excess Offering proceeds to Exchange Right Holders | — | (334,068 | ) | — | — | $ | (334,068 | ) | |||||||||||
Acquisition of Tallgrass Equity units from Exchange Right Holders | — | (171,948 | ) | — | — | $ | (171,948 | ) | |||||||||||
Deferred tax asset | — | 443,356 | — | — | $ | 443,356 | |||||||||||||
Net income for the period from May 12, 2015 to June 30, 2015 | — | 2,463 | — | 31,561 | $ | 34,024 | |||||||||||||
Issuance of common units under TEP LTIP plan | — | (661 | ) | — | (5,901 | ) | $ | (6,562 | ) | ||||||||||
Distributions to TEP unitholders | — | — | — | (46,082 | ) | $ | (46,082 | ) | |||||||||||
Noncash compensation expense | — | — | — | 6,000 | $ | 6,000 | |||||||||||||
Contributions from noncontrolling interest | — | — | — | 68,651 | $ | 68,651 | |||||||||||||
Distributions to noncontrolling interest | — | — | — | (22,607 | ) | $ | (22,607 | ) | |||||||||||
Distributions to TEP GP Members | — | (7,465 | ) | — | — | $ | (7,465 | ) | |||||||||||
Acquisition of noncontrolling interests | — | — | — | (600 | ) | $ | (600 | ) | |||||||||||
Balance at June 30, 2015 | $ | — | $ | 408,685 | $ | — | $ | 1,588,677 | $ | 1,997,362 |
• | 100% of the outstanding membership interests in Tallgrass MLP GP, LLC ("TEP GP"), which owns the general partner interest in TEP as well as all of the TEP incentive distribution rights ("IDRs"). The general partner interest in TEP is represented by 834,391 general partner units, representing a 1.09% general partner interest in TEP at June 30, 2016. |
• | 20,000,000 TEP common units, representing an approximately 26.14% limited partner interest in TEP at June 30, 2016. |
• | Crude Oil Transportation & Logistics—the ownership and operation of a FERC-regulated crude oil pipeline system; |
• | Natural Gas Transportation & Logistics—the ownership and operation of FERC-regulated interstate natural gas pipelines and integrated natural gas storage facilities; and |
• | Processing & Logistics—the ownership and operation of natural gas processing, treating and fractionation facilities, the provision of water business services primarily to the oil and gas exploration and production industry and the transportation of NGLs. |
Basis Difference | Amortization Period | ||||
(in thousands) | |||||
Long-term debt | $ | 7,002 | 2 - 25 years | ||
Property, plant and equipment | (411,730 | ) | 35 years | ||
Total basis difference | $ | (404,728 | ) |
June 30, 2016 | |||
(in thousands) | |||
Current assets | $ | 170,874 | |
Noncurrent assets | $ | 6,038,268 | |
Current liabilities | $ | 185,793 | |
Noncurrent liabilities | $ | 2,636,680 | |
Members' equity | $ | 3,386,669 |
Period from May 6, 2016 to June 30, 2016 | |||
(in thousands) | |||
Revenue | $ | 98,161 | |
Operating income | $ | 43,832 | |
Net income to Members | $ | 84,741 |
Three Months Ended June 30, 2015 | Six Months Ended June 30, 2015 | ||||||
(in thousands) | |||||||
Revenue | $ | 133,447 | $ | 248,594 | |||
Net income attributable to TEGP | $ | 4,751 | $ | 9,890 |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(in thousands) | |||||||||||||||
Cost of transportation services | $ | 7,295 | $ | 6,233 | $ | 14,551 | $ | 10,591 | |||||||
Charges to TEGP: (1) | |||||||||||||||
Property, plant and equipment, net | $ | 622 | $ | 1,594 | $ | 1,521 | $ | 2,901 | |||||||
Operation and maintenance | $ | 6,323 | $ | 5,825 | $ | 12,461 | $ | 11,248 | |||||||
General and administrative | $ | 10,452 | $ | 9,565 | $ | 19,643 | $ | 18,821 |
(1) | Charges to TEGP, inclusive of Tallgrass Equity, TEP, and Pony Express, include directly charged wages and salaries, other compensation and benefits, and shared services. |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
Receivable from related parties: | |||||||
Rockies Express Pipeline LLC | $ | — | $ | 15 | |||
Total receivable from related parties | $ | — | $ | 15 | |||
Accounts payable to related parties: | |||||||
Tallgrass Operations, LLC | $ | 7,028 | $ | 7,731 | |||
Rockies Express Pipeline LLC | 58 | 7 | |||||
Deeprock Development, LLC | — | 17 | |||||
Total accounts payable to related parties | $ | 7,086 | $ | 7,755 |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
Affiliate gas balance receivables | $ | 23 | $ | 92 | |||
Affiliate gas balance payables | $ | 167 | $ | 227 |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
Crude oil | $ | 5,752 | $ | 2,661 | |||
Materials and supplies | 6,429 | 8,581 | |||||
Natural gas liquids | 351 | 395 | |||||
Gas in underground storage | 2,222 | 2,156 | |||||
Total inventory | $ | 14,754 | $ | 13,793 |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
Crude oil pipelines | $ | 1,180,989 | $ | 1,172,684 | |||
Natural gas pipelines | 552,107 | 550,710 | |||||
Processing and treating assets | 255,767 | 254,073 | |||||
Water business assets | 80,736 | 81,098 | |||||
General and other | 81,876 | 69,181 | |||||
Construction work in progress | 27,182 | 30,699 | |||||
Accumulated depreciation and amortization | (171,590 | ) | (133,427 | ) | |||
Total property, plant and equipment, net | $ | 2,007,067 | $ | 2,025,018 |
Balance Sheet Location | June 30, 2016 | December 31, 2015 | |||||||
(in thousands) | |||||||||
Crude oil derivative contract (1) | Current assets | $ | 148 | $ | — | ||||
Call option derivative (2) | Noncurrent assets | $ | 55,967 | $ | — | ||||
Natural gas derivative contracts (3) | Current liabilities | $ | 351 | $ | — |
(1) | As of June 30, 2016, the fair value of crude oil derivative contracts represents the sale of 85,000 barrels in July 2016. As of December 31, 2015 there were no crude oil derivative contracts outstanding. |
(2) | As discussed in Note 4 – Acquisitions, in conjunction with our acquisition of an additional 31.3% membership interest in Pony Express effective January 1, 2016, TD granted us an 18 month call option to repurchase the newly issued 6,518,000 common units at a price of $42.50. |
(3) | As of June 30, 2016, the fair value shown for commodity contracts was comprised of derivative volumes for short natural gas fixed-price swaps totaling 0.8 Bcf. As of December 31, 2015 there were no natural gas derivative contracts outstanding. |
Location of gain (loss) recognized in income on derivatives | Amount of gain (loss) recognized in income on derivatives | ||||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||||
(in thousands) | |||||||||||||||||
Derivatives not designated as hedging contracts: | |||||||||||||||||
Call option derivative | Unrealized gain on derivative instrument | $ | 18,953 | $ | — | $ | 10,007 | $ | — | ||||||||
Natural gas derivative contracts | Sales of natural gas, NGLs, and crude oil | $ | (307 | ) | $ | (131 | ) | $ | (351 | ) | $ | (41 | ) | ||||
Crude oil derivative contract | Sales of natural gas, NGLs, and crude oil | $ | 148 | $ | — | $ | 148 | $ | — |
Asset Position | |||
(in thousands) | |||
Gross | $ | 148 | |
Netting agreement impact | — | ||
Cash collateral held | — | ||
Net Exposure | $ | 148 |
Asset Fair Value Measurements Using | |||||||||||||||
Total | Quoted prices in active markets for identical assets (Level 1) | Significant other observable inputs (Level 2) | Significant unobservable inputs (Level 3) | ||||||||||||
(in thousands) | |||||||||||||||
As of June 30, 2016 | |||||||||||||||
Call option derivative | $ | 55,967 | $ | — | $ | 55,967 | $ | — | |||||||
Crude oil derivative contract | $ | 148 | $ | — | $ | 148 | $ | — | |||||||
Liability Fair Value Measurements Using | |||||||||||||||
Total | Quoted prices in active markets for identical assets (Level 1) | Significant other observable inputs (Level 2) | Significant unobservable inputs (Level 3) | ||||||||||||
(in thousands) | |||||||||||||||
As of June 30, 2016 | |||||||||||||||
Natural gas derivative contracts | $ | 351 | $ | — | $ | 351 | $ | — |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
Total capacity under the Tallgrass Equity revolving credit facility | $ | 150,000 | $ | 150,000 | |||
Less: Outstanding borrowings under the Tallgrass Equity revolving credit facility | (148,000 | ) | (148,000 | ) | |||
Available capacity under the Tallgrass Equity revolving credit facility | $ | 2,000 | $ | 2,000 |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
Total capacity under the TEP revolving credit facility | $ | 1,750,000 | $ | 1,100,000 | |||
Less: Outstanding borrowings under the TEP revolving credit facility (1) | (1,278,000 | ) | (753,000 | ) | |||
Available capacity under the TEP revolving credit facility | $ | 472,000 | $ | 347,000 |
(1) | As of July 29, 2016, TEP's outstanding borrowings under its revolving credit facility were approximately $1.423 billion. |
Fair Value | |||||||||||||||||||
Quoted prices in active markets for identical assets (Level 1) | Significant other observable inputs (Level 2) | Significant unobservable inputs (Level 3) | Total | Carrying Amount | |||||||||||||||
(in thousands) | |||||||||||||||||||
June 30, 2016 | $ | — | $ | 1,426,000 | $ | — | $ | 1,426,000 | $ | 1,426,000 | |||||||||
December 31, 2015 | $ | — | $ | 901,000 | $ | — | $ | 901,000 | $ | 901,000 |
Three Months Ended | Date Paid | Distributions to Class A Shareholders | Distributions per Class A Share | ||||||||
(in thousands) | |||||||||||
June 30, 2016 | August 12, 2016(1) | $ | 11,693 | $ | 0.245 | ||||||
March 31, 2016 | May 13, 2016 | 10,022 | 0.210 | ||||||||
December 31, 2015 | February 12, 2016 | 8,256 | 0.173 | ||||||||
September 30, 2015 | November 13, 2015 | 6,872 | 0.144 | ||||||||
June 30, 2015 | August 17, 2015 | 3,484 | 0.073 | (2) |
(1) | The distribution announced on July 6, 2016 for the second quarter of 2016 will be paid on August 12, 2016 to Class A shareholders of record at the close of business on July 29, 2016. |
(2) | The first quarterly distribution declared on July 15, 2015 was prorated for the number of days between the closing of TEGP's initial public offering on May 12, 2015 and the end of the second quarter. |
Distributions | ||||||||||||||||||||||
Limited Partner Common Units | General Partner | Distributions per Limited Partner Unit | ||||||||||||||||||||
Three Months Ended | Date Paid | Incentive Distribution Rights | General Partner Units | Total | ||||||||||||||||||
(in thousands, except per unit amounts) | ||||||||||||||||||||||
June 30, 2016 | August 12, 2016(1) | $ | 54,442 | $ | 24,262 | $ | 911 | $ | 79,615 | $ | 0.7550 | |||||||||||
March 31, 2016 | May 13, 2016 | 48,238 | 19,816 | 830 | 68,884 | 0.7050 | ||||||||||||||||
December 31, 2015 | February 12, 2016 | 42,984 | 15,332 | 724 | 59,040 | 0.6400 | ||||||||||||||||
September 30, 2015 | November 13, 2015 | 36,347 | 11,567 | 660 | 48,574 | 0.6000 | ||||||||||||||||
June 30, 2015 | August 14, 2015 | 35,135 | 10,418 | 627 | 46,180 | 0.5800 | ||||||||||||||||
March 31, 2015 | May 14, 2015 | 31,322 | 6,934 | 530 | 38,786 | 0.5200 |
(1) | The distribution announced on July 6, 2016 for the second quarter of 2016 will be paid on August 12, 2016 to unitholders of record at the close of business on July 29, 2016. |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(in thousands, except per share data) | |||||||||||||||
Basic Net Income per Class A Share: | |||||||||||||||
Net income attributable to TEGP | $ | 3,448 | $ | 4,734 | $ | 11,037 | $ | 9,856 | |||||||
Net income attributable to TEGP from the beginning of the period to May 11, 2015 | — | 2,271 | — | 7,393 | |||||||||||
Net income attributable to TEGP subsequent to May 12, 2015 | $ | 3,448 | $ | 2,463 | $ | 11,037 | $ | 2,463 | |||||||
Basic weighted average Class A Shares outstanding | 47,725 | 47,725 | 47,725 | 47,725 | |||||||||||
Basic net income per Class A share | $ | 0.07 | $ | 0.05 | $ | 0.23 | $ | 0.05 | |||||||
Diluted Net Income per Class A Share: | |||||||||||||||
Net income attributable to TEGP subsequent to May 12, 2015 | $ | 3,448 | $ | 2,463 | $ | 11,037 | $ | 2,463 | |||||||
Incremental net income attributable to TEGP including the effect of the assumed issuance of Equity Participation Shares | 1 | — | — | — | |||||||||||
Net income attributable to TEGP including incremental net income from assumed issuance of Equity Participation Shares | $ | 3,449 | $ | 2,463 | $ | 11,037 | $ | 2,463 | |||||||
Basic weighted average Class A Shares outstanding | 47,725 | 47,725 | 47,725 | 47,725 | |||||||||||
Equity Participation Shares equivalent shares | 9 | — | — | — | |||||||||||
Diluted weighted average Class A Shares outstanding | 47,734 | 47,725 | 47,725 | 47,725 | |||||||||||
Diluted net income per Class A Share | $ | 0.07 | $ | 0.05 | $ | 0.23 | $ | 0.05 |
Three Months Ended June 30, 2016 | Three Months Ended June 30, 2015 | ||||||||||||||||||||||
Revenue: | Total Revenue | Inter- Segment | External Revenue | Total Revenue | Inter- Segment | External Revenue | |||||||||||||||||
(in thousands) | |||||||||||||||||||||||
Crude Oil Transportation & Logistics | $ | 93,470 | $ | — | $ | 93,470 | $ | 75,219 | $ | — | $ | 75,219 | |||||||||||
Natural Gas Transportation & Logistics | 30,150 | (1,410 | ) | 28,740 | 30,969 | (1,344 | ) | 29,625 | |||||||||||||||
Processing & Logistics | 24,721 | — | 24,721 | 28,126 | — | 28,126 | |||||||||||||||||
Corporate and Other | — | — | — | — | — | — | |||||||||||||||||
Total Revenue | $ | 148,341 | $ | (1,410 | ) | $ | 146,931 | $ | 134,314 | $ | (1,344 | ) | $ | 132,970 |
Six Months Ended June 30, 2016 | Six Months Ended June 30, 2015 | ||||||||||||||||||||||
Revenue: | Total Revenue | Inter- Segment | External Revenue | Total Revenue | Inter- Segment | External Revenue | |||||||||||||||||
(in thousands) | |||||||||||||||||||||||
Crude Oil Transportation & Logistics | $ | 188,042 | $ | — | $ | 188,042 | $ | 125,600 | $ | — | $ | 125,600 | |||||||||||
Natural Gas Transportation & Logistics | 61,137 | (2,765 | ) | 58,372 | 64,579 | (2,690 | ) | 61,889 | |||||||||||||||
Processing & Logistics | 45,922 | — | 45,922 | 60,156 | — | 60,156 | |||||||||||||||||
Corporate and Other | — | — | — | — | — | — | |||||||||||||||||
Total Revenue | $ | 295,101 | $ | (2,765 | ) | $ | 292,336 | $ | 250,335 | $ | (2,690 | ) | $ | 247,645 |
Three Months Ended June 30, 2016 | Three Months Ended June 30, 2015 | ||||||||||||||||||||||
Operating Income: | Total Operating Income | Inter- Segment | External Operating Income | Total Operating Income | Inter- Segment | External Operating Income | |||||||||||||||||
(in thousands) | |||||||||||||||||||||||
Crude Oil Transportation & Logistics | $ | 53,726 | $ | 1,346 | $ | 55,072 | $ | 45,515 | $ | 1,344 | $ | 46,859 | |||||||||||
Natural Gas Transportation & Logistics | 10,100 | (1,410 | ) | 8,690 | 9,937 | (1,344 | ) | 8,593 | |||||||||||||||
Processing & Logistics | (1,372 | ) | 64 | (1,308 | ) | 3,666 | — | 3,666 | |||||||||||||||
Corporate and Other | (3,107 | ) | — | (3,107 | ) | (3,013 | ) | — | (3,013 | ) | |||||||||||||
Total Operating Income | $ | 59,347 | $ | — | $ | 59,347 | $ | 56,105 | $ | — | $ | 56,105 | |||||||||||
Reconciliation to Net Income: | |||||||||||||||||||||||
Interest expense, net | (10,441 | ) | (4,479 | ) | |||||||||||||||||||
Unrealized gain on derivative instrument | 18,953 | — | |||||||||||||||||||||
Equity in earnings of unconsolidated investment | 23,321 | — | |||||||||||||||||||||
Other income, net | 221 | 769 | |||||||||||||||||||||
Net income before income tax | $ | 91,401 | $ | 52,395 |
Six Months Ended June 30, 2016 | Six Months Ended June 30, 2015 | ||||||||||||||||||||||
Operating Income: | Total Operating Income | Inter- Segment | External Operating Income | Total Operating Income | Inter- Segment | External Operating Income | |||||||||||||||||
(in thousands) | |||||||||||||||||||||||
Crude Oil Transportation & Logistics | $ | 106,392 | $ | 2,691 | $ | 109,083 | $ | 59,788 | $ | 2,690 | $ | 62,478 | |||||||||||
Natural Gas Transportation & Logistics | 20,764 | (2,765 | ) | 17,999 | 22,490 | (2,690 | ) | 19,800 | |||||||||||||||
Processing & Logistics | (1,194 | ) | 74 | (1,120 | ) | 4,720 | — | 4,720 | |||||||||||||||
Corporate and Other | (6,146 | ) | — | (6,146 | ) | (5,175 | ) | — | (5,175 | ) | |||||||||||||
Total Operating Income | $ | 119,816 | $ | — | $ | 119,816 | $ | 81,823 | $ | — | $ | 81,823 | |||||||||||
Reconciliation to Net Income: | |||||||||||||||||||||||
Interest expense, net | (19,118 | ) | (7,919 | ) | |||||||||||||||||||
Unrealized gain on derivative instrument | 10,007 | — | |||||||||||||||||||||
Equity in earnings of unconsolidated investment | 23,321 | — | |||||||||||||||||||||
Other income, net | 787 | 1,481 | |||||||||||||||||||||
Net income before income tax | $ | 134,813 | $ | 75,385 |
Six Months Ended June 30, | |||||||
Capital Expenditures: | 2016 | 2015 | |||||
(in thousands) | |||||||
Crude Oil Transportation & Logistics | $ | 19,160 | $ | 32,501 | |||
Natural Gas Transportation & Logistics | 4,115 | 7,061 | |||||
Processing & Logistics | 5,216 | 9,982 | |||||
Corporate and Other | — | — | |||||
Total capital expenditures | $ | 28,491 | $ | 49,544 |
Assets: | June 30, 2016 | December 31, 2015 | |||||
(in thousands) | |||||||
Crude Oil Transportation & Logistics | $ | 1,425,917 | $ | 1,439,418 | |||
Natural Gas Transportation & Logistics | 1,142,222 | 706,576 | |||||
Processing & Logistics | 408,055 | 409,795 | |||||
Corporate and Other | 508,713 | 460,871 | |||||
Total assets | $ | 3,484,907 | $ | 3,016,660 |
• | TEP's ability to complete and integrate acquisitions from TD or from third parties, including its acquisition of a 25% membership interest in Rockies Express that was completed in May 2016, its purchase of an additional 31.3% membership interest in Pony Express that was completed in January 2016, and its acquisition of water business assets in Weld County, Colorado that was completed in December 2015; |
• | large or multiple customer defaults, including defaults resulting from actual or potential insolvencies; |
• | changes in general economic conditions; |
• | competitive conditions in our industry; |
• | actions taken by third-party operators, processors and transporters; |
• | the demand for TEP's services, including crude oil transportation services, natural gas transportation, storage and processing services and water business services; |
• | our ability to successfully implement our business plan; |
• | our ability to complete internal growth projects on time and on budget; |
• | the price and availability of debt and equity financing; |
• | the level of production of crude oil, natural gas and other hydrocarbons and the resultant market prices of crude oil, natural gas, NGLs, and other hydrocarbons; |
• | the availability and price of natural gas and crude oil, and fuels derived from both, to the consumer compared to the price of alternative and competing fuels; |
• | competition from the same and alternative energy sources; |
• | energy efficiency and technology trends; |
• | operating hazards and other risks incidental to transporting crude oil, transporting, storing and processing natural gas, and transporting, gathering and disposing of water produced in connection with hydrocarbon exploration and production activities; |
• | natural disasters, weather-related delays, casualty losses and other matters beyond our control; |
• | interest rates; |
• | labor relations; |
• | changes in tax status; |
• | the effects of existing and future laws and governmental regulations; |
• | the effects of future litigation; and |
• | certain factors discussed elsewhere in this Quarterly Report. |
• | 100% of the outstanding membership interests in TEP GP, which owns all of the general partner interest in TEP and all of TEP's IDRs. The general partner interest in TEP is represented by 834,391 general partner units, representing an approximate 1.14% general partner interest in TEP at August 3, 2016. |
• | 20,000,000 TEP common units, representing an approximately 27.42% limited partner interest in TEP at August 3, 2016. |
• | Crude Oil Transportation & Logistics—the ownership and operation of a FERC-regulated crude oil pipeline system; |
• | Natural Gas Transportation & Logistics—the ownership and operation of FERC-regulated interstate natural gas pipelines and integrated natural gas storage facilities; and |
• | Processing & Logistics—the ownership and operation of natural gas processing, treating and fractionation facilities, the provision of water business services primarily to the oil and gas exploration and production industry and the transportation of NGLs. |
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(in thousands, except operating data) | |||||||||||||||
Revenues: | |||||||||||||||
Crude oil transportation services | $ | 93,322 | $ | 74,022 | $ | 187,894 | $ | 124,403 | |||||||
Natural gas transportation services | 28,682 | 29,041 | 57,962 | 61,189 | |||||||||||
Sales of natural gas, NGLs, and crude oil | 16,830 | 20,011 | 30,756 | 41,880 | |||||||||||
Processing and other revenues | 8,097 | 9,896 | 15,724 | 20,173 | |||||||||||
Total Revenues | 146,931 | 132,970 | 292,336 | 247,645 | |||||||||||
Operating Costs and Expenses: | |||||||||||||||
Cost of sales (exclusive of depreciation and amortization shown below) | 15,958 | 17,180 | 29,526 | 36,773 | |||||||||||
Cost of transportation services (exclusive of depreciation and amortization shown below) | 14,240 | 13,492 | 30,396 | 24,207 | |||||||||||
Operations and maintenance | 13,864 | 12,408 | 26,341 | 21,983 | |||||||||||
Depreciation and amortization | 21,576 | 20,355 | 43,268 | 40,960 | |||||||||||
General and administrative | 14,458 | 13,701 | 27,995 | 26,390 | |||||||||||
Taxes, other than income taxes | 5,639 | (271 | ) | 13,145 | 11,026 | ||||||||||
Loss on disposal of assets | 1,849 | — | 1,849 | 4,483 | |||||||||||
Total Operating Costs and Expenses | 87,584 | 76,865 | 172,520 | 165,822 | |||||||||||
Operating Income | 59,347 | 56,105 | 119,816 | 81,823 | |||||||||||
Other Income (Expense): | |||||||||||||||
Interest expense, net | (10,441 | ) | (4,479 | ) | (19,118 | ) | (7,919 | ) | |||||||
Unrealized gain on derivative instrument | 18,953 | — | 10,007 | — | |||||||||||
Equity in earnings of unconsolidated investment | 23,321 | — | 23,321 | — | |||||||||||
Other income, net | 221 | 769 | 787 | 1,481 | |||||||||||
Total Other Income (Expense) | 32,054 | (3,710 | ) | 14,997 | (6,438 | ) | |||||||||
Net income before tax | 91,401 | 52,395 | 134,813 | 75,385 | |||||||||||
Deferred income tax expense | (6,792 | ) | (1,772 | ) | (9,583 | ) | (1,772 | ) | |||||||
Net income | 84,609 | 50,623 | 125,230 | 73,613 | |||||||||||
Net income attributable to noncontrolling interests | (81,161 | ) | (45,889 | ) | (114,193 | ) | (63,757 | ) | |||||||
Net income attributable to TEGP | $ | 3,448 | $ | 4,734 | $ | 11,037 | $ | 9,856 | |||||||
Operating Data: | |||||||||||||||
Crude oil transportation average throughput (Bbls/d) (1) | 286,217 | 237,184 | 288,746 | 201,495 | |||||||||||
Gas transportation average firm contracted volumes (MMcf/d) (2) | 1,478 | 1,520 | 1,476 | 1,564 | |||||||||||
Natural gas processing inlet volumes (MMcf/d) | 106 | 130 | 102 | 138 |
(1) | Approximate average daily throughput for the three and six months ended June 30, 2015 is reflective of the volumetric ramp up due to commercial in-service of the Pony Express System beginning in October 2014 and delays in the construction and expansion efforts of third-party pipelines with which Pony Express shares joint tariffs. |
(2) | Excludes firm contracted volumes of Rockies Express. |
Segment Financial Data - Crude Oil Transportation & Logistics (1) | Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(in thousands) | |||||||||||||||
Revenues: | |||||||||||||||
Crude oil transportation services | $ | 93,322 | $ | 74,022 | $ | 187,894 | $ | 124,403 | |||||||
Sales of natural gas, NGLs, and crude oil | 148 | 1,197 | 148 | 1,197 | |||||||||||
Total revenues | 93,470 | 75,219 | 188,042 | 125,600 | |||||||||||
Operating costs and expenses: | |||||||||||||||
Cost of sales | — | 986 | — | 986 | |||||||||||
Cost of transportation services | 14,152 | 11,528 | 28,647 | 20,237 | |||||||||||
Operations and maintenance | 3,210 | 2,015 | 7,041 | 3,430 | |||||||||||
Depreciation and amortization | 12,973 | 11,301 | 25,612 | 22,534 | |||||||||||
General and administrative | 5,336 | 5,155 | 10,370 | 10,310 | |||||||||||
Taxes, other than income taxes | 4,073 | (1,281 | ) | 9,980 | 8,315 | ||||||||||
Total operating costs and expenses | 39,744 | 29,704 | 81,650 | 65,812 | |||||||||||
Operating income | $ | 53,726 | $ | 45,515 | $ | 106,392 | $ | 59,788 |
(1) | Segment results as presented represent total revenue and operating income, including intersegment activity. For reconciliations to the consolidated financial data, see Note 14 – Reporting Segments to the accompanying condensed consolidated financial statements. |
Segment Financial Data - Natural Gas Transportation & Logistics (1) | Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(in thousands) | |||||||||||||||
Revenues: | |||||||||||||||
Natural gas transportation services | $ | 30,092 | $ | 30,385 | $ | 60,727 | $ | 63,879 | |||||||
Sales of natural gas, NGLs, and crude oil | 48 | 574 | 396 | 679 | |||||||||||
Processing and other revenues | 10 | 10 | 14 | 21 | |||||||||||
Total revenues | 30,150 | 30,969 | 61,137 | 64,579 | |||||||||||
Operating costs and expenses: | |||||||||||||||
Cost of sales | 373 | (203 | ) | 1,519 | (129 | ) | |||||||||
Cost of transportation services | 842 | 2,794 | 3,297 | 6,110 | |||||||||||
Operations and maintenance | 7,806 | 7,359 | 13,686 | 13,099 | |||||||||||
Depreciation and amortization | 5,479 | 5,754 | 11,357 | 11,825 | |||||||||||
General and administrative | 4,408 | 4,424 | 8,196 | 8,685 | |||||||||||
Taxes, other than income taxes | 1,142 | 904 | 2,318 | 2,499 | |||||||||||
Total operating costs and expenses | 20,050 | 21,032 | 40,373 | 42,089 | |||||||||||
Operating income | $ | 10,100 | $ | 9,937 | $ | 20,764 | $ | 22,490 |
(1) | Segment results as presented represent total revenue and operating income, including intersegment activity. For reconciliations to the consolidated financial data, see Note 14 – Reporting Segments to the accompanying condensed consolidated financial statements. |
Segment Financial Data - Processing & Logistics (1) | Three Months Ended June 30, | Six Months Ended June 30, | |||||||||||||
2016 | 2015 | 2016 | 2015 | ||||||||||||
(in thousands) | |||||||||||||||
Revenues: | |||||||||||||||
Sales of natural gas, NGLs, and crude oil | $ | 16,634 | $ | 18,240 | $ | 30,212 | $ | 40,004 | |||||||
Processing and other revenues | 8,087 | 9,886 | 15,710 | 20,152 | |||||||||||
Total revenues | 24,721 | 28,126 | 45,922 | 60,156 | |||||||||||
Operating costs and expenses: | |||||||||||||||
Cost of sales | 15,649 | 16,397 | 28,081 | 35,916 | |||||||||||
Cost of transportation services | 592 | 514 | 1,143 | 550 | |||||||||||
Operations and maintenance | 2,848 | 3,034 | 5,614 | 5,454 | |||||||||||
Depreciation and amortization | 3,124 | 3,300 | 6,299 | 6,601 | |||||||||||
General and administrative | 1,607 | 1,109 | 3,283 | 2,220 | |||||||||||
Taxes, other than income taxes | 424 | 106 | 847 | 212 | |||||||||||
Loss on disposal of assets | 1,849 | — | 1,849 | 4,483 | |||||||||||
Total operating costs and expenses | 26,093 | 24,460 | 47,116 | 55,436 | |||||||||||
Operating (loss) income | $ | (1,372 | ) | $ | 3,666 | $ | (1,194 | ) | $ | 4,720 |
(1) | Segment results as presented represent total revenue and operating income, including intersegment activity. For reconciliations to the consolidated financial data, see Note 14 – Reporting Segments to the accompanying condensed consolidated financial statements. |
• | cash generated from our operations; |
• | borrowing capacity available under our revolving credit facilities; and |
• | future issuances of additional partnership units and/or debt securities. |
June 30, 2016 | December 31, 2015 | ||||||
(in thousands) | |||||||
Cash on hand | $ | 2,623 | $ | 2,234 | |||
Total capacity under the TEP revolving credit facility | 1,750,000 | 1,100,000 | |||||
Less: Outstanding borrowings under the TEP revolving credit facility(1) | (1,278,000 | ) | (753,000 | ) | |||
Available capacity under the TEP revolving credit facility | 472,000 | 347,000 | |||||
Total capacity under the Tallgrass Equity revolving credit facility | $ | 150,000 | $ | 150,000 | |||
Less: Outstanding borrowings under the Tallgrass Equity revolving credit facility | (148,000 | ) | (148,000 | ) | |||
Available capacity under the Tallgrass Equity revolving credit facility | $ | 2,000 | $ | 2,000 | |||
Total Liquidity | $ | 476,623 | $ | 351,234 |
(1) | As of July 29, 2016, TEP's outstanding borrowings under the revolving credit facility were approximately $1.423 billion. |
• | an increase in deferred revenue of $16.4 million primarily from deficiency payments collected by Pony Express; and |
• | a decrease of $4.7 million in accounts receivable primarily due to a decrease in incremental barrels shipped at Pony Express in June 2016 compared to December 2015. |
Six Months Ended June 30, | |||||||
2016 | 2015 | ||||||
(in thousands) | |||||||
Net cash provided by (used in): | |||||||
Operating activities | $ | 193,570 | $ | 111,623 | |||
Investing activities | $ | (521,272 | ) | $ | (754,192 | ) | |
Financing activities | $ | 328,091 | $ | 643,980 |
• | net borrowings under the revolving credit facility of $525.0 million; |
• | the issuance of 6,081,138 TEP common units under the TEP's Equity Distribution Agreements for net cash proceeds of $261.8 million; |
• | the issuance of 2,416,987 TEP common units representing TEP limited partnership interests in a private placement transaction for net cash proceeds of $90.0 million; and |
• | contributions from noncontrolling interests of $7.3 million, which primarily consisted of contributions from TD to Pony Express. |
• | $425.9 million for the portion of the acquisition of an additional 31.3% membership interest in Pony Express which exceeds the cumulative capital spending on the underlying assets acquired; |
• | distributions to noncontrolling interests of $109.6 million, consisting of distributions to TEP unitholders of $64.3 million, Tallgrass Equity distributions to the Exchange Right Holders of $41.9 million, and distributions to Pony Express and Water Solutions noncontrolling interests of $3.3 million; and |
• | distributions to Class A shareholders of $18.3 million. |
• | $1.3 billion of net proceeds from the initial public offering of Class A shares in May 2015; |
• | $551.7 million of net proceeds from the public offering of TEP common units in February 2015; |
• | the proceeds from net borrowings under the TEP and Tallgrass Equity revolving credit facilities of $294.0 million; and |
• | contributions from noncontrolling interests of $16.3 million, primarily driven by contributions from TD to Pony Express. |
• | $953.6 million for the acquisition of 20,000,000 TEP common units by Tallgrass Equity as part of the Offering; |
• | $334.1 million for the distribution of proceeds from the Offering to the Exchange Right Holders as part of the reorganization of entities effective concurrent with the Offering; |
• | $171.9 million for the acquisition of additional Tallgrass Equity units as part of the reorganization concurrent with the Offering; |
• | distributions to TEP unitholders of $46.1 million; and |
• | distributions to the TEGP Predecessor Member of $13.5 million. |
• | maintenance capital expenditures, which are cash expenditures incurred (including expenditures for the construction or development of new capital assets) that we expect to maintain our long-term operating income or operating capacity. These expenditures typically include certain system integrity, compliance and safety improvements; and |
• | expansion capital expenditures, which are cash expenditures to increase our operating income or operating capacity over the long-term. Expansion capital expenditures include acquisitions or capital improvements (such as additions to or improvements on the capital assets owned, or acquisition or construction of new capital assets). |
Six Months Ended June 30, | |||||||
2016 | 2015 | ||||||
(in thousands) | |||||||
Maintenance capital expenditures | $ | 4,263 | $ | 4,578 | |||
Expansion capital expenditures | 20,537 | 117,746 | |||||
Total capital expenditures incurred | $ | 24,800 | $ | 122,324 |
Description | Judgments and Uncertainties | Effect if Actual Results Differ from Assumptions | ||
Impairment of Goodwill | ||||
We evaluate goodwill for impairment annually in the third quarter, and whenever events or changes in circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. | We determine fair value using widely accepted valuation techniques, primarily discounted cash flow and market multiple analyses. These techniques are also used when assigning the purchase price to acquired assets and liabilities. These types of analyses require us to make assumptions and estimates regarding industry and economic factors and the profitability of future business strategies. Our impairment analyses require management to apply judgment in estimating future cash flows as well as asset fair values, including forecasting useful lives of the assets, assessing the probability of different outcomes, including anticipated volumes, contract renewals and changes in our regulated rates, and selecting the discount rate that reflects the risk inherent in future cash flows. It is our policy to conduct impairment testing based on our current business strategy in light of present industry and economic conditions, as well as future expectations. | We primarily use a discounted cash flow analysis, supplemented by a market approach analysis, to perform the assessment. Key assumptions in the analysis include the use of an appropriate discount rate, terminal year multiples, and estimated future cash flows including an estimate of operating and general and administrative costs. In estimating cash flows, we incorporate current market information, as well as historical and other factors, into our forecasted commodity prices. If our assumptions are not appropriate, or future events indicate that our goodwill is impaired, our net income would be impacted by the amount by which the carrying value exceeds the fair value of the reporting unit, to the extent of the balance of goodwill. A prolonged period of lower commodity prices may adversely affect our estimate of future operating results, which could result in future goodwill impairment for reporting units due to the potential impact on our operations and cash flows. We completed our impairment testing of goodwill in the third quarter of 2015 using the methodology described herein, and determined there was no impairment. As a result of a decreased commodity prices in late 2015 and into early 2016, which caused a significant drop in the volumes anticipated from several producers from which TMID receives natural gas for processing, we identified a potential impairment trigger with respect to the $79.2 million of goodwill at the TMID reporting unit, which is a component of our Processing & Logistics segment. We tested TMID's goodwill for impairment as of December 31, 2015 and determined that the fair value of the reporting unit exceeds the carrying value by approximately 21%. As a result, no impairment charge was recorded, however our analysis includes assumptions of a gradual recovery of commodity prices and a corresponding increase in volumes over time. If our outlook for long-term commodity prices is not realized, or our producers further decrease volumes, we could have an impairment in the future. While commodity prices do not have a significant direct exposure to the cash flows projected at TMID, the current commodity price environment has had an indirect impact on TMID’s business as certain producers have significantly reduced their anticipated volumes. Keeping all other assumptions constant, an increase in the discount rate applied of approximately 1.38% or a decrease in overall cash flows by more than 16% would result in a step one failure, however we do not believe that these represent reasonably likely assumptions. If the reporting unit fails step one in the future, we would be required to perform step two of the goodwill impairment test and up to $79.2 million of goodwill at the TMID reporting unit could be written off in the period that the impairment is triggered. |
Exhibit No. | Description | |
10.1 | Amendment No. 4 to Credit Agreement, dated as of April 27, 2016, by and among Tallgrass Energy Partners, LP, Barclays Bank PLC, as administrative agent, and a syndicate of lenders named therein (incorporated by reference to Exhibit 10.1 to Tallgrass Energy Partners, LP’s Current Report on Form 8-K filed on April 28, 2016). | |
10.2 | Membership Interest Purchase Agreement, dated as of March 29, 2016, by and between Sempra REX Holdings, LLC and TEP REX Holdings, LLC (as successor by assignment to Rockies Express Holdings, LLC) (incorporated by reference to Exhibit 10.2 to Tallgrass Energy Partners, LP's Quarterly Report on Form 10-Q filed on August 3, 2016). | |
10.3 | Assignment and Assumption Agreement, dated as of May 6, 2016, by and among Rockies Express Holdings, LLC, TEP REX Holdings, LLC and, for the limited purposes set forth therein, Tallgrass Development, LP (incorporated by reference to Exhibit 10.3 to Tallgrass Energy Partners, LP's Quarterly Report on Form 10-Q filed on August 3, 2016). | |
10.4 | Second Amended and Restated Limited Liability Company Agreement of Rockies Express Pipeline LLC, dated effective as of January 1, 2010, among Rockies Express Holdings, LLC (as successor by assignment to Kinder Morgan W2E Pipeline LLC), TEP REX Holdings, LLC (as successor by assignment to Sempra REX Holdings, LLC and P&S Project I, LLC), and P66REX LLC (f/k/a COPREX LLC) (incorporated by reference to Exhibit 10.4 to Tallgrass Energy Partners, LP's Quarterly Report on Form 10-Q filed on August 3, 2016). | |
10.5 | Amendment No. 1 to Second Amended and Restated Limited Liability Company Agreement of Rockies Express Pipeline LLC, dated effective as of November 13, 2012, among Kinder Morgan W2E Pipeline LLC, TEP REX Holdings, LLC (as successor by assignment to Sempra REX Holdings, LLC and P&S Project I, LLC), Rockies Express Holdings, LLC and P66REX LLC (f/k/a COPREX LLC) (incorporated by reference to Exhibit 10.5 to Tallgrass Energy Partners, LP's Quarterly Report on Form 10-Q filed on August 3, 2016). | |
10.6 | Amendment No. 2 to Second Amended and Restated Limited Liability Company Agreement, dated effective as of May 5, 2016, among Sempra REX Holdings, LLC and P&S Project I, LLC, Rockies Express Holdings, LLC and P66REX LLC (incorporated by reference to Exhibit 10.6 to Tallgrass Energy Partners, LP's Quarterly Report on Form 10-Q filed on August 3, 2016). | |
31.1* | Rule 13a-14(a)/15d-14(a) Certification of David G. Dehaemers, Jr. | |
31.2* | Rule 13a-14(a)/15d-14(a) Certification of Gary J. Brauchle. | |
32.1* | Section 1350 Certification of David G. Dehaemers, Jr. | |
32.2* | Section 1350 Certification of Gary J. Brauchle. | |
101.INS* | XBRL Instance Document. | |
101.SCH* | XBRL Taxonomy Extension Schema Document. | |
101.CAL* | XBRL Taxonomy Extension Calculation Linkbase Document. | |
101.DEF* | XBRL Taxonomy Extension Definition Linkbase Document. | |
101.LAB* | XBRL Taxonomy Extension Label Linkbase Document. | |
101.PRE* | XBRL Taxonomy Extension Presentation Linkbase Document. |
* - | filed herewith |
Tallgrass Energy GP, LP | |||||||
(registrant) | |||||||
By: | TEGP Management, LLC, its general partner | ||||||
Date: | August 3, 2016 | By: | /s/ Gary J. Brauchle | ||||
Name: | Gary J. Brauchle | ||||||
Title: | Executive Vice President and Chief Financial Officer |
1. | I have reviewed this Quarterly Report on Form 10-Q of Tallgrass Energy GP, LP; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
By: | /s/ David G. Dehaemers, Jr. | |
David G. Dehaemers, Jr. | ||
President and Chief Executive Officer of TEGP Management, LLC (the general partner of Tallgrass Energy GP, LP) |
1. | I have reviewed this Quarterly Report on Form 10-Q of Tallgrass Energy GP, LP; |
2. | Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; |
3. | Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report; |
4. | The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have: |
a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared; |
b) | Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles; |
c) | Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and |
d) | Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and |
5. | The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions): |
a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and |
b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting. |
By: | /s/ Gary J. Brauchle | |
Gary J. Brauchle | ||
Executive Vice President and Chief Financial Officer of TEGP Management, LLC (the general partner of Tallgrass Energy GP, LP) |
1. | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and |
2. | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership. |
By: | /s/ David G. Dehaemers, Jr. | |
David G. Dehaemers, Jr. | ||
President and Chief Executive Officer of TEGP Management, LLC (the general partner of Tallgrass Energy GP, LP) |
1. | The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and |
2. | The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership. |
By: | /s/Gary J. Brauchle | |
Gary J. Brauchle | ||
Executive Vice President and Chief Financial Officer of TEGP Management, LLC (the general partner of Tallgrass Energy GP, LP) |
Document and Entity Information - shares |
6 Months Ended | |
---|---|---|
Jun. 30, 2016 |
Aug. 03, 2016 |
|
Document Information [Line Items] | ||
Entity Registrant Name | TALLGRASS ENERGY GP, LP | |
Entity Central Index Key | 0001633651 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Non-accelerated Filer | |
Document Type | 10-Q | |
Document Period End Date | Jun. 30, 2016 | |
Document Fiscal Year Focus | 2016 | |
Document Fiscal Period Focus (Q1,Q2,Q3,FY) | Q2 | |
Trading Symbol | TEGP | |
Amendment Flag | false | |
Capital Unit, Class A | ||
Document Information [Line Items] | ||
Entity Common Stock, Shares Outstanding | 47,725,000 | |
Capital Unit, Class B | ||
Document Information [Line Items] | ||
Entity Common Stock, Shares Outstanding | 109,504,440 |
CONDENSED CONSOLIDATED BALANCE SHEETS CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - USD ($) |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Accounts payable (including $10,554 at December 31, 2015 related to variable interest entities) | $ 17,451,000 | $ 22,218,000 |
Common Class A | ||
Limited Partners' Capital Account, Shares Outstanding | 47,725,000 | 47,725,000 |
Common Class B | ||
Limited Partners' Capital Account, Shares Outstanding | 109,504,440 | 109,504,440 |
Variable Interest Entity, Primary Beneficiary | ||
Accounts payable (including $10,554 at December 31, 2015 related to variable interest entities) | $ 0 | $ 10,554,000 |
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (UNAUDITED) - USD ($) $ in Thousands |
Total |
Pony Express Pipeline |
Noncontrolling Interest |
Noncontrolling Interest
Pony Express Pipeline
|
Noncontrolling Interest
Tallgrass Energy Partners
|
Noncontrolling Interest
Tallgrass Energy GP, LP Predecessor
|
Noncontrolling Interest
Tallgrass Energy GP, LP
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest |
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Pony Express Pipeline
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Tallgrass Energy Partners
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Tallgrass Energy GP, LP Predecessor
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Tallgrass Energy GP, LP
|
Common Class A |
Common Class A
Pony Express Pipeline
|
Common Class A
Tallgrass Energy Partners
|
Common Class A
Tallgrass Energy GP, LP Predecessor
|
Common Class A
Tallgrass Energy GP, LP
|
Common Class B |
Common Class B
Pony Express Pipeline
|
Common Class B
Tallgrass Energy Partners
|
Common Class B
Tallgrass Energy GP, LP Predecessor
|
Common Class B
Tallgrass Energy GP, LP
|
Tallgrass Energy GP, LP Predecessor |
Tallgrass Energy GP, LP Predecessor
Pony Express Pipeline
|
Tallgrass Energy GP, LP Predecessor
Tallgrass Energy Partners
|
Tallgrass Energy GP, LP Predecessor
Tallgrass Energy GP, LP Predecessor
|
Tallgrass Energy GP, LP Predecessor
Tallgrass Energy GP, LP
|
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | $ 1,648,285 | $ 1,795,151 | $ 0 | $ 0 | $ 146,866 | ||||||||||||||||||||||
Increase (Decrease) in Partners' Capital [Roll Forward] | |||||||||||||||||||||||||||
Net income | $ 73,613 | ||||||||||||||||||||||||||
Acquisitions | (600) | $ (601,554) | (600) | $ (700,000) | 0 | $ 0 | 0 | $ 0 | 0 | $ (98,446) | |||||||||||||||||
Issuance of TEP units in a private placement, net of offering costs | 0 | $ (488,153) | (1,315,383) | $ (551,673) | (1,315,383) | $ 0 | 0 | $ 0 | 0 | $ (63,520) | |||||||||||||||||
Distributions to noncontrolling interest | 46,082 | $ 0 | 22,607 | 22,607 | 0 | 0 | 0 | ||||||||||||||||||||
Proceeds from private placement, net of offering costs | 0 | ||||||||||||||||||||||||||
Distribution Made to Limited Partner, Cash Distributions Paid | 0 | ||||||||||||||||||||||||||
Contributions from noncontrolling interests | 16,294 | 68,651 | 68,651 | 0 | 0 | 0 | |||||||||||||||||||||
Noncash compensation expense | 6,000 | 6,000 | 0 | 0 | 0 | ||||||||||||||||||||||
Distributions to TEGP Predecessor | 0 | 46,082 | $ 9,425 | 7,465 | 46,082 | $ (13,533) | 7,465 | 0 | $ 0 | 0 | 0 | $ 0 | 0 | 0 | $ (4,108) | ||||||||||||
Partners' Capital Account, Exchanges and Conversions | 0 | 0 | 115,225 | 0 | (115,225) | ||||||||||||||||||||||
Acquisition of Acquired TEP Units | (953,600) | 0 | (953,600) | (953,600) | 0 | 0 | |||||||||||||||||||||
Payments of Capital Distribution | (334,068) | 0 | (334,068) | (334,068) | 0 | 0 | |||||||||||||||||||||
Payments to Acquire Additional Interest in Subsidiaries | 700,000 | $ 0 | $ 171,948 | $ 171,948 | $ 0 | $ 0 | |||||||||||||||||||||
Partners Capital Deferred Tax Asset | 0 | 443,356 | 443,356 | 0 | 0 | ||||||||||||||||||||||
Adjustments Related to Tax Withholding for Share-based Compensation | (5,901) | (6,562) | (661) | 0 | 0 | ||||||||||||||||||||||
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | 1,588,677 | 1,997,362 | 408,685 | 0 | 0 | ||||||||||||||||||||||
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | 2,021,498 | 1,599,188 | 2,021,498 | 422,310 | 0 | 0 | |||||||||||||||||||||
Net income | 125,230 | 114,193 | 125,230 | 11,037 | 0 | 0 | |||||||||||||||||||||
Acquisitions | $ (173,422) | $ (429,039) | $ (255,617) | $ 0 | $ 0 | ||||||||||||||||||||||
Issuance of TEP units in a private placement, net of offering costs | (261,800) | 239,600 | 261,770 | 22,159 | 0 | 0 | |||||||||||||||||||||
Distributions to noncontrolling interest | 109,551 | 425,882 | 109,600 | 109,551 | 0 | 0 | 0 | ||||||||||||||||||||
Proceeds from private placement, net of offering costs | 90,009 | $ 82,417 | 90,009 | $ 7,592 | $ 0 | $ 0 | |||||||||||||||||||||
Distribution Made to Limited Partner, Cash Distributions Paid | 18,278 | 0 | 18,278 | 18,278 | 0 | 0 | |||||||||||||||||||||
Contributions from noncontrolling interests | 7,273 | 7,300 | 7,273 | 0 | 0 | 0 | |||||||||||||||||||||
Noncash compensation expense | 3,820 | 4,462 | 642 | 0 | 0 | ||||||||||||||||||||||
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs | 0 | (489) | (489) | 0 | 0 | ||||||||||||||||||||||
Distributions to TEGP Predecessor | $ 64,300 | ||||||||||||||||||||||||||
Acquisition of Acquired TEP Units | 0 | ||||||||||||||||||||||||||
Payments of Capital Distribution | 0 | ||||||||||||||||||||||||||
Payments to Acquire Additional Interest in Subsidiaries | 49,118 | $ 49,100 | |||||||||||||||||||||||||
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | $ 1,952,885 | $ 1,763,529 | $ 1,952,885 | $ 189,356 | $ 0 | $ 0 |
Description of Business |
6 Months Ended | ||||||||||||||||||||
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Jun. 30, 2016 | |||||||||||||||||||||
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |||||||||||||||||||||
Description of Business | Tallgrass Energy GP, LP ("TEGP" or the "Partnership") is a limited partnership that has elected to be treated as a corporation for U.S. federal income tax purposes. TEGP was formed as part of the reorganization of entities controlled by Tallgrass Equity, LLC ("Tallgrass Equity") to effect the initial public offering of Class A shares of TEGP (the "Offering"), which was completed on May 12, 2015. TEGP's sole cash-generating asset is an approximate 30.35% controlling interest in Tallgrass Equity. Tallgrass Equity's sole cash-generating assets consist of direct and indirect partnership interests in Tallgrass Energy Partners, LP ("TEP") as described below:
The term "TEGP Predecessor" refers to TEGP, as recast to show the effects of the reorganization, for the periods prior to completion of the Offering on May 12, 2015. "We," "us," "our" and similar terms refer to TEGP together with its consolidated subsidiaries or to TEGP Predecessor together with its consolidated subsidiaries, as the context requires, including, in both cases, Tallgrass Equity and TEP (and their respective subsidiaries). TEP is a publicly traded, growth-oriented limited partnership formed to own, operate, acquire and develop midstream energy assets in North America. TEP currently provides crude oil transportation to customers in Wyoming, Colorado, and the surrounding regions through Tallgrass Pony Express Pipeline, LLC ("Pony Express"), which owns a crude oil pipeline commencing in Guernsey, Wyoming and terminating in Cushing, Oklahoma that includes a lateral in Northeast Colorado that commences in Weld County, Colorado, and interconnects with the pipeline just east of Sterling, Colorado (the "Pony Express System"). TEP provides natural gas transportation and storage services for customers in the Rocky Mountain, Midwest and Appalachian regions of the United States through: (1) TEP's 25% membership interest in Rockies Express Pipeline LLC ("Rockies Express"), a Delaware limited liability company which owns the Rockies Express Pipeline, a FERC-regulated natural gas pipeline system extending from Opal, Wyoming and Meeker, Colorado to Clarington, Ohio, (2) the Tallgrass Interstate Gas Transmission system, a FERC-regulated natural gas transportation and storage system located in Colorado, Kansas, Missouri, Nebraska and Wyoming (the "TIGT System"), and (3) the Trailblazer Pipeline system, a FERC-regulated natural gas pipeline system extending from the Colorado and Wyoming border to Beatrice, Nebraska (the "Trailblazer Pipeline"). TEP also provides services for customers in Wyoming at the Casper and Douglas natural gas processing facilities and the West Frenchie Draw natural gas treating facility (collectively, the "Midstream Facilities"), and NGL transportation services in Northeast Colorado. TEP performs water business services in Colorado and Texas through BNN Water Solutions, LLC ("Water Solutions"). TEP's operations are strategically located in and provide services to certain key United States hydrocarbon basins, including the Denver-Julesburg, Powder River, Wind River, Permian and Hugoton-Anadarko Basins and the Niobrara, Mississippi Lime, Eagle Ford, Bakken, Marcellus and Utica shale formations. Our reportable business segments are:
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Summary of Significant Accounting Policies |
6 Months Ended |
---|---|
Jun. 30, 2016 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | Basis of Presentation These condensed consolidated financial statements and related notes for the three and six months ended June 30, 2016 and 2015 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board's Accounting Standards Codification, the single source of generally accepted accounting principles in the United States of America ("GAAP") for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from audited financial statements but does not include all disclosures required by GAAP for annual periods. The condensed consolidated financial statements for the three and six months ended June 30, 2016 and 2015 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair statement of the results for the interim periods. In this report, the Financial Accounting Standards Board is referred to as the FASB and the FASB Accounting Standards Codification is referred to as the Codification or ASC. Certain prior period amounts have been reclassified to conform to the current presentation. Our financial results for the three and six months ended June 30, 2016 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2016. The accompanying condensed consolidated interim financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015 ("2015 Form 10-K") filed with the United States Securities and Exchange Commission (the "SEC") on February 17, 2016. The condensed consolidated financial statements of TEGP for the three and six months ended June 30, 2015 include historical cost basis accounts of the assets of TEGP and were prepared in contemplation of TEGP's initial public offering of Class A shares completed on May 12, 2015 and the acquisition of an approximately 30.35% interest in Tallgrass Equity as described in Note 1 – Description of Business, which was accounted for as a transaction between entities under common control in accordance with ASC 805. Significant intra-entity items have been eliminated in the presentation. Both TEGP and TEGP Predecessor are considered entities under common control and, as such, the transfer between the entities of the assets and liabilities has been recorded by TEGP at historical cost. TEGP, as used herein, refers to the consolidated financial results and operations for TEGP Predecessor prior to the completion of the Offering and to TEGP thereafter. Net income or loss from consolidated subsidiaries that are not wholly-owned by TEGP is attributed to TEGP and noncontrolling interests. This is done in accordance with substantive profit sharing arrangements, which generally follow the allocation of cash distributions and may not follow the respective ownership percentages held by TEGP. Concurrent with TEP's acquisition of an initial 33.3% membership interest in Pony Express effective September 1, 2014, TEP, Tallgrass Development, LP ("TD"), and Pony Express entered into the Second Amended and Restated Limited Liability Agreement of Tallgrass Pony Express Pipeline, LLC ("the Second Amended Pony Express LLC Agreement"), which provided TEP a minimum quarterly preference payment of $16.65 million (prorated to approximately $5.4 million for the quarter ended September 30, 2014) through the quarter ended September 30, 2015. Effective March 1, 2015 with TEP's acquisition of an additional 33.3% membership interest in Pony Express, the Second Amended Pony Express LLC Agreement was further amended (as amended, "the Pony Express LLC Agreement") to increase the minimum quarterly preference payment to $36.65 million (prorated to approximately $23.5 million for the quarter ended March 31, 2015) and extend the term of the preference period through the quarter ended December 31, 2015. The Pony Express LLC Agreement provides that the net income or loss of Pony Express be allocated, to the extent possible, consistent with the allocation of Pony Express cash distributions. Under the terms of the Pony Express LLC Agreement, Pony Express distributions and net income for periods beginning after December 31, 2015 are attributed to TEP and its noncontrolling interests in accordance with the respective ownership interests. A variable interest entity ("VIE") is a legal entity that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity owners who do not have the obligation to absorb expected losses or the right to receive the expected residual returns of the entity. Companies are required to consolidate a VIE if they are its primary beneficiary, which is the enterprise that has a variable interest that could be significant to the VIE and the power to direct the activities that most significantly impact the entity's economic performance. We have presented separately in our condensed consolidated balance sheets, to the extent material, the liabilities of our consolidated VIEs for which creditors do not have recourse to our general credit. Our consolidated VIEs do not have material assets that can only be used to settle specific obligations of the consolidated VIEs. Tallgrass Equity is considered to be a VIE under the applicable authoritative guidance. Based on a qualitative analysis in accordance with the applicable authoritative guidance, we have determined that we are the primary beneficiary as we have the right to receive benefits of Tallgrass Equity that could potentially be significant to Tallgrass Equity. Also, as discussed further under "New Accounting Pronouncements" below, under the new authoritative guidance effective January 1, 2016, TEP is considered to be a VIE. Based on a qualitative analysis, we have determined that TEP GP is the primary beneficiary of TEP and we continue to consolidate TEP accordingly. Pony Express was considered to be a VIE under the applicable authoritative guidance prior to our acquisition of an additional 31.3% membership interest effective January 1, 2016. Effective January 1, 2016, Pony Express is no longer considered to be a VIE. We continue to consolidate our membership interest in Pony Express. Use of Estimates Certain amounts included in or affecting these condensed consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts reported for assets, liabilities, revenues, and expenses during the reporting period, and the disclosure of contingent assets and liabilities at the date of the financial statements. Management evaluates these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods it considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from these estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. New Accounting Pronouncements Revenue Recognition In May 2014, the FASB issued Accounting Standards Update ("ASU") No. 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 provides a comprehensive and converged set of principles-based revenue recognition guidelines which supersede the existing industry and transaction-specific standards. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. To achieve this core principle, entities must apply a five step process to (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 also mandates disclosure of sufficient information to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The disclosure requirements include qualitative and quantitative information about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract. Throughout the first half of 2016, the FASB has issued a series of subsequent updates to the revenue recognition guidance in Topic 606, including ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net), ASU No. 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing, and ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients. The amendments in ASU 2014-09, ASU 2016-08, ASU 2016-10, and ASU 2016-12 are effective for public entities for annual reporting periods beginning after December 15, 2017, and for interim periods within that reporting period. Early application is permitted for annual reporting periods beginning after December 15, 2016. We are currently evaluating the impact of these updates. ASU No. 2015-11, "Inventory (Topic 330): Simplifying the Measurement of Inventory" In July 2015, the FASB issued ASU No. 2015-11, Inventory (Topic 330), Simplifying the Measurement of Inventory. ASU 2015-11 establishes a "lower of cost and net realizable value" model for the measurement of most inventory balances. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The amendments in ASU 2015-11 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2016. Early adoption is permitted. We are currently evaluating the impact of ASU 2015-11. ASU No. 2015-17, "Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes" In November 2015, the FASB issued ASU No. 2015-17, Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes. ASU 2015-17 simplifies the presentation of deferred income taxes. The amendments in this update require that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. The amendments in ASU 2015-17 are effective for financial statements issued for annual periods beginning after December 15, 2016, and interim periods within those annual periods. Earlier application is permitted for all entities as of the beginning of an interim or annual reporting period. The adoption of ASU 2015-17 did not have a material impact on our financial position and results of operations. ASU No. 2016-02, "Leases (Topic 842)" In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). ASU 2016-02 provides a comprehensive update to the lease accounting topic in the Codification intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The amendments in ASU 2016-02 include a revised definition of a lease as well as certain scope exceptions. The changes primarily impact lessee accounting, while lessor accounting is largely unchanged from previous GAAP. The amendments in ASU 2016-02 are effective for public entities for annual reporting periods beginning after December 15, 2018, and for interim periods within that reporting period. Early application is permitted. We are currently evaluating the impact of ASU 2016-02. ASU No. 2016-09, "Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting" In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. ASU 2016-09 simplifies several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. Among other changes, ASU 2016-09 allows an entity to make an entity-wide accounting policy election to either estimate the number of awards expected to vest (consistent with current GAAP) or account for forfeitures when they occur. The amendments in ASU 2016-09 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2016. Early adoption is permitted. We are currently evaluating the impact of ASU 2016-09. ASU No. 2015-16, "Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments" In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments. ASU 2015-16 simplifies the accounting for measurement-period adjustments for provisional amounts recognized in a business combination by eliminating the requirement for an acquirer to retrospectively account for measurement-period adjustments. Under the updated guidance, the acquirer must recognize adjustments in the reporting period in which the adjustment amounts are determined and the effect on earnings as a result of the change to the provisional amounts must be calculated as if the accounting had been completed at the acquisition date. The amendments in ASU 2015-16 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2015. The adoption of ASU 2015-16 did not have a material impact on our financial position and results of operations. ASU No. 2015-02, "Consolidation (Topic 810): Amendments to the Consolidation Analysis" In February 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis. ASU 2015-02 will change the analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities. ASU 2015-02 will modify the evaluation of whether limited partnerships and other similar legal entities are considered VIEs or voting interest entities, eliminate the presumption that a general partner should consolidate a limited partnership, and change certain aspects of the consolidation analysis for reporting entities that are involved with VIEs, particularly for those with fee arrangements and related party relationships. The amendments in ASU 2015-02 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2015. The adoption of ASU 2015-02 did not have a material impact on our financial position and results of operations. ASU No. 2014-12, "Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period" In June 2014, the FASB issued ASU No. 2014-12, Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 provides explicit guidance on accounting for share-based payments requiring a specific performance target to be achieved in order for employees to become eligible to vest in the awards when that performance target may be achieved after the requisite service period for the award. The ASU requires that such performance targets be treated as a performance condition, and should not be reflected in the estimate of the grant-date fair value of the award. Instead, compensation cost should be recognized in the period in which it becomes probable that the performance target will be achieved. ASU 2014-12 is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. The adoption of ASU 2014-12 did not have a material impact on our financial position and results of operations. |
Variable Interest Entity Variable Interest Entity |
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Jun. 30, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Variable Interest Entity | As discussed in Note 2 – Summary of Significant Accounting Policies, upon adoption of the accounting guidance in ASU 2015-02 effective January 1, 2016, we determined that TEP is a VIE of which TEP GP, our consolidated subsidiary, is the primary beneficiary. We continue to consolidate TEP accordingly. We have not provided any additional financial support and have no contractual commitments or obligations to provide additional financial support to TEP. TEGP, as the managing member of Tallgrass Equity, has voting rights disproportionate to its ownership interest. As a result, we have determined that Tallgrass Equity is a VIE of which we are the primary beneficiary and we consolidate Tallgrass Equity accordingly. We have not provided any additional financial support to Tallgrass Equity other than our initial capital contribution to acquire a portion of the approximate 30.35% controlling interest in Tallgrass Equity and have no contractual commitments or obligations to provide additional financial support to Tallgrass Equity. Pony Express was considered to be a VIE under the applicable authoritative guidance prior to our acquisition of an additional 31.3% membership interest effective January 1, 2016. Effective January 1, 2016, Pony Express is no longer considered to be a VIE. We continue to consolidate our membership interest in Pony Express. Other than TEGP's deferred tax asset of approximately $442.8 million and $452.4 million at June 30, 2016 and December 31, 2015, respectively, the assets and liabilities included in our consolidated balance sheets at June 30, 2016 and December 31, 2015 represent the consolidated assets and liabilities of Tallgrass Equity, including the assets and liabilities of TEP and Pony Express. |
Acquisitions |
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Business Combinations [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Acquisitions | Acquisition of a 25% Membership Interest in Rockies Express Pipeline LLC On March 29, 2016, TD's indirect wholly owned subsidiary Rockies Express Holdings, LLC ("REX Holdings") signed a purchase agreement (the "REX Purchase Agreement") with a unit of Sempra U.S. Gas and Power ("Sempra") to acquire Sempra's 25% membership interest in Rockies Express for cash consideration of $440 million, subject to adjustment under the REX Purchase Agreement. On April 28, 2016, we announced that TD offered TEP the right to assume the rights and obligations of REX Holdings under the REX Purchase Agreement. On May 6, 2016, TEP REX Holdings, LLC ("TEP REX"), an indirect wholly-owned subsidiary of TEP, and REX Holdings entered into an Assignment and Assumption Agreement pursuant to which REX Holdings assigned to TEP REX all of its rights under the REX Purchase Agreement and, in exchange, TEP REX assumed all of the rights and obligations of REX Holdings under the REX Purchase Agreement. Subsequently on May 6, 2016, TEP REX closed the purchase of a 25% membership interest in Rockies Express from Sempra pursuant to the REX Purchase Agreement for cash consideration of approximately $436.0 million, after making the adjustments to the purchase price required by the REX Purchase Agreement. Our investment in Rockies Express is recorded under the equity method of accounting and reported as "Unconsolidated investment" on our condensed consolidated balance sheet. As of May 6, 2016, the difference between the fair value of our investment in Rockies Express of $436.0 million and the book value of the underlying net assets of approximately $840.7 million results in a negative basis difference of approximately $404.7 million. The basis difference has been allocated to property, plant and equipment and long-term debt based on their respective fair values at the date of acquisition. The amount of the basis difference allocated to property, plant and equipment is accreted over 35 years, which equates to the 2.86% composite depreciation rate utilized by Rockies Express to depreciate the underlying property, plant and equipment. The amount allocated to long-term debt is amortized over the remaining life of the various debt facilities. The basis difference at June 30, 2016 was allocated as follows:
During the period from May 6, 2016 to June 30, 2016, we recognized equity in earnings from Rockies Express of $23.3 million, inclusive of the amortization of the negative basis difference discussed above, and received distributions from and made contributions to Rockies Express of $29.7 million and $14.4 million, respectively. Summarized financial information for Rockies Express is as follows:
Acquisition of Additional 31.3% Membership Interest in Pony Express Effective January 1, 2016, TEP acquired an additional 31.3% membership interest in Pony Express in exchange for cash consideration of $475 million and 6,518,000 TEP common units (valued at approximately $268.6 million based on the December 31, 2015 closing price of TEP's common units) issued to TD for total consideration of approximately $743.6 million. The transaction increased TEP's aggregate membership interest in Pony Express to 98.0%. As part of the transaction, TD granted TEP an 18 month call option to repurchase the newly issued 6,518,000 common units at a price of $42.50. On the effective date of the acquisition, the call option was valued at $46.0 million. As discussed in Note 8 – Risk Management, on July 21, 2016, we partially exercised the option and repurchased 3,563,146 of the common units, leaving 2,954,854 remaining common units available for repurchase under the call option. The acquisition of the additional 31.3% membership interest in Pony Express represents a transaction between entities under common control and an acquisition of noncontrolling interests. As a result, financial information for periods prior to the transaction have not been recast to reflect the additional 31.3% membership interest. The transaction resulted in a deemed distribution to our general partner as discussed further in Note 10 – Partnership Equity and Distributions. Cash outflows to acquire an additional noncontrolling interest in Pony Express are classified as an investing activity in the accompanying condensed consolidated statements of cash flows to the extent the consideration paid was used to directly fund the construction of the underlying assets by the noncontrolling member. Cash outflows to acquire an additional noncontrolling interest in excess of the cost to construct the underlying assets are classified as financing activities. For the six months ended June 30, 2016, $49.1 million of the $475 million paid to acquire the additional 31.3% membership interest in Pony Express was classified as an investing activity and $425.9 million was classified as a financing activity. TEP Acquisition of BNN Western, LLC On December 16, 2015, Whiting Oil and Gas Corporation ("Whiting"), BNN Redtail, LLC ("Redtail"), and BNN Western, LLC ("Western"), a newly formed Delaware limited liability company, entered into a definitive Transfer, Purchase and Sale Agreement, pursuant to which Redtail acquired 100% of the outstanding membership interests of Western from Whiting in exchange for total cash consideration of $75 million. Western's assets consist of a fresh water delivery and storage system and produced water gathering and produced water disposal system, which together comprise 62 miles of pipeline along with associated fresh water ponds and disposal wells. As part of the transaction with Whiting, Whiting also executed a five-year fresh water service contract and a nine-year gathering and disposal contract. At December 31, 2015, the assets acquired and liabilities assumed in the acquisition were recorded at provisional amounts based on the preliminary purchase price allocation. The $75 million purchase price of the assets was allocated entirely to property, plant and equipment. TEP is in the process of obtaining additional information to identify and measure all assets acquired and liabilities assumed in the acquisition within the measurement period. Such provisional amounts will be adjusted if necessary to reflect any new information about facts and circumstances that existed at the acquisition date that, if known, would have affected the measurement of these amounts. TEGP's unaudited pro forma revenue and net income attributable to partners for the three and six months ended June 30, 2015 is presented below as if the acquisition of Western had been completed on January 1, 2015:
The pro forma financial information is not necessarily indicative of what the actual results of operations or financial position of TEGP would have been if the transactions had in fact occurred on the date or for the period indicated, nor do they purport to project the results of operations or financial position of TEGP for any future periods or as of any date. The pro forma financial information does not give effect to any cost savings, operating synergies, or revenue enhancements expected to result from the transactions or the costs to achieve these cost savings, operating synergies, and revenue enhancements. The pro forma revenue and net income includes adjustments to give effect to TEGP's consolidated interest in the estimated results of operations of Western for the periods presented. |
Related Party Transactions |
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Related Party Transactions [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Related Party Transactions | We have no employees. TD, through its wholly-owned subsidiary Tallgrass Operations, LLC ("Tallgrass Operations"), provided and charged us for direct and indirect costs of services provided to us or incurred on our behalf including employee labor costs, information technology services, employee health and retirement benefits, and all other expenses necessary or appropriate to the conduct of our business. We recorded these costs on the accrual basis in the period in which TD incurred them. On May 17, 2013, in connection with the closing of TEP's initial public offering, TEP and its general partner entered into an Omnibus Agreement with TD and certain of its affiliates, including Tallgrass Operations (the "TEP Omnibus Agreement"). The TEP Omnibus Agreement provides that, among other things, TEP will reimburse TD and its affiliates for all expenses they incur and payments they make on TEP's behalf, including the costs of employee and director compensation and benefits as well as the cost of the provision of certain centralized corporate functions performed by TD, including legal, accounting, cash management, insurance administration and claims processing, risk management, health, safety and environmental, information technology and human resources in each case to the extent reasonably allocable to TEP. In addition, in connection with the closing of the Offering, TEGP entered into an Omnibus Agreement (the "TEGP Omnibus Agreement") with TEGP Management, LLC, Tallgrass Equity and Tallgrass Energy Holdings, LLC (which acts as the general partner of TD). Pursuant to the TEGP Omnibus Agreement, Tallgrass Equity pays a reimbursement to TD for costs associated with TEGP being a public company beginning in the second quarter of 2015, which was $500,000 for the second quarter of 2016. This amount will be periodically reviewed and adjusted as necessary to continue to reflect reasonable allocation of costs to TEGP. There was no interest income from TD recognized for the three and six months ended June 30, 2016. During the six months ended June 30, 2015 we recognized interest income from TD of $0.4 million on the receivable balance under the Pony Express cash management agreement in effect through December 31, 2015. Totals of transactions with affiliated companies are as follows:
Details of balances with affiliates included in "Accounts receivable, net" and "Accounts payable to related parties" in the condensed consolidated balance sheets are as follows:
Balances of gas imbalances with affiliated shippers are as follows:
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Inventory |
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Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory | The components of inventory at June 30, 2016 and December 31, 2015 consisted of the following:
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Property, Plant and Equipment |
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Property, Plant and Equipment [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment | A summary of net property, plant and equipment by classification is as follows:
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Risk Management |
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Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Risk Management | We occasionally enter into derivative contracts with third parties for the purpose of hedging exposures that accompany our normal business activities. Our normal business activities directly and indirectly expose us to risks associated with changes in the market price of crude oil and natural gas, among other commodities. For example, the risks associated with changes in the market price of crude oil and natural gas include, among others (i) pre-existing or anticipated physical crude oil and natural gas sales, (ii) natural gas purchases and (iii) natural gas system use and storage. We have elected not to apply hedge accounting and changes in the fair value of all derivative contracts are recorded in earnings in the period in which the change occurs. Fair Value of Derivative Contracts The following table summarizes the fair values of our derivative contracts included in the condensed consolidated balance sheets:
Effect of Derivative Contracts in the Statements of Income The following table summarizes the impact of derivative contracts for the three and six months ended June 30, 2016 and 2015:
Exercise of Call Option On July 21, 2016, TEP partially exercised the call option granted by TD in January 2016, as discussed in Note 4 – Acquisitions and repurchased 3,563,146 common units for a cash payment of $151.4 million. These TEP common units were deemed canceled upon repurchase by TEP and as of July 21, 2016 are no longer issued and outstanding. As of July 29, 2016, 2,954,854 common units remained available for repurchase under the call option. Credit Risk We have counterparty credit risk as a result of our use of derivative contracts. Counterparties to our crude oil and natural gas derivatives consist of major financial institutions. This concentration of counterparties may impact our overall exposure to credit risk, either positively or negatively, in that the counterparties may be similarly affected by changes in economic, regulatory or other conditions. The counterparty to our call option derivative is TD. Settlement of the call option derivative, when exercised, requires TEP to make a cash payment to TD in exchange for return of the common units. Our over-the-counter swaps are entered into with counterparties outside central trading organizations such as futures, options or stock exchanges. These contracts are with financial institutions with investment grade credit ratings. While we enter into derivative transactions principally with investment grade counterparties and actively monitor their credit ratings, it is nevertheless possible that from time to time losses will result from counterparty credit risk in the future. As of June 30, 2016, the fair value of our natural gas commodity derivative contracts was a liability, resulting in no credit exposure from TEP's counterparties as of that date. The maximum potential exposure to credit losses on our crude oil derivative contract at June 30, 2016 was:
As of June 30, 2016 and December 31, 2015, we did not have any outstanding letters of credit or cash in margin accounts in support of our hedging of commodity price risks associated with the sale of natural gas nor did we have any margin deposits with counterparties associated with natural gas contract positions. Fair Value Derivative assets and liabilities are measured and reported at fair value. Derivative contracts can be exchange-traded or over-the-counter ("OTC"). Exchange-traded derivative contracts typically fall within Level 1 of the fair value hierarchy if they are traded in an active market. We value exchange-traded derivative contracts using quoted market prices for identical securities. OTC derivatives are valued using models utilizing a variety of inputs including contractual terms and commodity and interest rate curves. The selection of a particular model and particular inputs to value an OTC derivative contract depends upon the contractual terms of the instrument as well as the availability of pricing information in the market. We use similar models to value similar instruments. For OTC derivative contracts that trade in liquid markets, such as generic forwards and swaps, model inputs can generally be verified and model selection does not involve significant management judgment. Such contracts are typically classified within Level 2 of the fair value hierarchy. Certain OTC derivative contracts trade in less liquid markets with limited pricing information; as such, the determination of fair value for these derivative contracts is inherently more difficult. Such contracts are classified within Level 3 of the fair value hierarchy. The valuations of these less liquid OTC derivatives are typically impacted by Level 1 and/or Level 2 inputs that can be observed in the market, as well as unobservable Level 3 inputs. Use of a different valuation model or different valuation input values could produce a significantly different estimate of fair value. However, derivative contracts valued using inputs unobservable in active markets are generally not material to our financial statements. When appropriate, valuations are adjusted for various factors including credit considerations. Such adjustments are generally based on available market evidence. In the absence of such evidence, management's best estimate is used. The call option granted by TD is valued using a Black-Scholes option pricing model. Key inputs to the valuation model include the term of the option, risk free rate, the exercise price and current market price, expected volatility and expected distribution yield of the underlying units. The call option valuation is classified within Level 2 of the fair value hierarchy as the value is based on significant observable inputs. The following table summarizes the fair value measurements of our derivative contracts as of June 30, 2016 based on the fair value hierarchy established by the Codification:
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Long-term Debt |
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Debt Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Long-term Debt | Tallgrass Equity Revolving Credit Facility The following table sets forth the available borrowing capacity under the Tallgrass Equity revolving credit facility as of June 30, 2016 and December 31, 2015:
In connection with the Offering, Tallgrass Equity entered into a $150 million senior secured revolving credit facility with Barclays Bank PLC, as administrative agent, and a syndicate of lenders, which will mature on May 12, 2020. Among various other covenants and restrictive provisions, Tallgrass Equity is required to maintain a total leverage ratio of not more than 3.00 to 1.00. As of June 30, 2016, Tallgrass Equity was in compliance with the covenants required under the revolving credit facility. The unused portion of the revolving credit facility is subject to a commitment fee of 0.50%. As of June 30, 2016, the weighted average interest rate on outstanding borrowings under the Tallgrass Equity revolving credit facility was 2.95%. During the six months ended June 30, 2016, Tallgrass Equity's weighted average effective interest rate, including the interest on outstanding borrowings, commitment fees, and amortization of deferred financing costs, was 3.23%. TEP Revolving Credit Facility Effective January 4, 2016, in connection with the acquisition of an additional 31.3% membership interest in Pony Express, TEP exercised the committed accordion feature to increase the total capacity of its revolving credit facility from $1.1 billion to $1.5 billion. In connection with the acquisition of a 25% membership interest in Rockies Express, TEP amended its revolving credit facility to increase the total capacity to $1.75 billion, which increase became effective May 6, 2016. The following table sets forth the available borrowing capacity under the TEP revolving credit facility as of June 30, 2016 and December 31, 2015:
TEP's revolving credit facility contains various covenants and restrictive provisions that, among other things, limit or restrict TEP's ability (as well as the ability of its restricted subsidiaries) to incur or guarantee additional debt, incur certain liens on assets, dispose of assets, make certain distributions (including distributions from available cash, if a default or event of default under the credit agreement then exists or would result from making such a distribution), change the nature of our business, engage in certain mergers or make certain investments and acquisitions, enter into non-arms-length transactions with affiliates and designate certain subsidiaries as "Unrestricted Subsidiaries." In addition, TEP is required to maintain a consolidated leverage ratio of not more than 4.75 to 1.00 (which will be increased to 5.25 to 1.00 for certain measurement periods following the consummation of certain acquisitions) and a consolidated interest coverage ratio of not less than 2.50 to 1.00. As of June 30, 2016, TEP is in compliance with the covenants required under its revolving credit facility. The unused portion of TEP's revolving credit facility is subject to a commitment fee, which ranges from 0.300% to 0.500%, based on TEP's total leverage ratio. As of June 30, 2016, the weighted average interest rate on outstanding borrowings under the TEP revolving credit facility was 2.72%. During the six months ended June 30, 2016, the weighted average effective interest rate under the TEP revolving credit facility, including the interest on outstanding borrowings, commitment fees, and amortization of deferred financing costs, was 2.66%. Fair Value The following table sets forth the carrying amount and fair value of our long-term debt, which is not measured at fair value in the condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015, but for which fair value is disclosed:
The long-term debt borrowed under the revolving credit facility is carried at amortized cost. As of June 30, 2016 and December 31, 2015, the fair value approximates the carrying amount for the borrowings under the revolving credit facilities using a discounted cash flow analysis. We are not aware of any factors that would significantly affect the estimated fair value subsequent to June 30, 2016. |
Partnership Equity and Distributions |
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Partnership Equity and Distributions | Tallgrass Development Purchase Program On February 17, 2016, we announced that the Board of Directors of Tallgrass Energy Holdings, LLC, the sole member of TEGP's general partner and the general partner of TD, has authorized an equity purchase program under which TD may initially purchase up to an aggregate of $100 million of the outstanding Class A shares of TEGP or the outstanding common units of TEP. TD may purchase Class A shares or Common Units from time to time on the open market or in negotiated purchases. The timing and amounts of any such purchases will be subject to market conditions and other factors, and will be in accordance with applicable securities laws and other legal requirements. The purchase plan does not obligate TD to acquire any specific number of Class A shares or Common Units and may be discontinued at any time. No purchases were made under this program during the six months ended June 30, 2016. TEGP Partnership Agreement and Distributions to Holders of Class A Shares In connection with the Offering on May 12, 2015, TEGP entered into an amended and restated partnership agreement. The partnership agreement requires TEGP to distribute its available cash to Class A shareholders on a quarterly basis, subject to certain terms and conditions, beginning with the quarter ended June 30, 2015. The following table details the distributions for the periods indicated:
Subsidiary Distributions TEP Distributions. The following table shows the TEP distributions for the periods indicated:
TEP Equity Distribution Agreements On October 31, 2014, TEP entered into an equity distribution agreement pursuant to which it may sell from time to time through a group of managers, as its sales agents, common units representing limited partner interests having an aggregate offering price of up to $200 million. On May 13, 2015 the amount was subsequently amended to $100.2 million in order to account for follow-on equity offerings under TEP's S-3 shelf registration statement. On May 17, 2016, TEP entered into a new equity distribution agreement allowing for the sale of common units with an aggregate offering price of up to $657.5 million. Sales of common units, if any, will be made by means of ordinary brokers' transactions, to or through a market maker or directly on or through an electronic communication network, a "dark pool" or any similar market venue, or as otherwise agreed by TEP and one or more of the managers. TEP intends to use the net cash proceeds from any sale of the units for general partnership purposes, which may include, among other things, the exercise of TEP's right to repurchase all or a portion of the 6,518,000 common units issued by TEP to TD in connection with TEP's acquisition of an additional 31.3% of Pony Express in January 2016, repayment or refinancing of debt, funding for acquisitions, capital expenditures and additions to working capital. During the six months ended June 30, 2016, TEP issued and sold 6,081,138 common units with a weighted average sales price of $43.63 per unit under its equity distribution agreements for net cash proceeds of approximately $261.8 million (net of approximately $3.6 million in commissions and professional service expenses). Private Placement On April 28, 2016, TEP issued an aggregate of 2,416,987 common units for net cash proceeds of $90.0 million in a private placement transaction to certain funds managed by Tortoise Capital Advisors, L.L.C. The units were subsequently registered pursuant to TEP's Form S-3/A (File No. 333-210976) filed with the SEC on May 6, 2016, which became effective May 17, 2016. Noncontrolling Interests As of June 30, 2016, noncontrolling interests in our subsidiaries consisted of a 69.65% interest in Tallgrass Equity held by the Exchange Right Holders, as defined in Note 11 – Net Income per Class A Share, the 73.57% limited partner interest in TEP held by TD and the public TEP unitholders, the 2.0% membership interest in Pony Express held by TD, and an 8% membership interest in Water Solutions. During the six months ended June 30, 2016, we recognized contributions from and distributions to noncontrolling interests of $7.3 million and $109.6 million, respectively. Contributions from noncontrolling interests consisted primarily of contributions from TD to Pony Express. Distributions to noncontrolling interests consisted of distributions to TEP unitholders of $64.3 million, Tallgrass Equity distributions to the Exchange Right Holders of $41.9 million, and distributions to Pony Express and Water Solutions noncontrolling interests of $3.3 million. During the six months ended June 30, 2015, we received contributions from and made distributions to noncontrolling interests of $68.7 million and $22.6 million, respectively. Contributions from noncontrolling interest primarily consisted of contributions from TD to Pony Express. Distributions to noncontrolling interests consisted of distributions to TEP unitholders of $13.5 million and distributions from Pony Express to TD. Other Contributions and Distributions During the six months ended June 30, 2015, we distributed $334.1 million of proceeds from the Offering to the Exchange Right Holders as part of the reorganization of entities effective concurrent with the Offering. In addition, we received $7.5 million of TEP general partner and IDR distributions received related to periods prior to the Offering which were distributed to the previous owners of the sole member of TEP GP. |
Net Income per Class A Share Net Income per Class A Share |
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Net Income per Class A Share | Basic net income per Class A share is determined by dividing net income attributable to TEGP by the weighted average number of outstanding Class A shares during the period. Class B shares do not share in the earnings of the Partnership. Accordingly, basic and diluted net income per Class B share has not been presented. Diluted net income per Class A share is determined by dividing net income attributable to TEGP by the weighted average number of outstanding diluted Class A shares during the period. For purposes of calculating diluted net income per Class A share, we considered the impact of possible future exercises of the Exchange Right by the Exchange Right Holders on both net income attributable to TEGP and the diluted weighted average number of Class A shares outstanding. The Exchange Right Holders refers to the group of persons who collectively own all of TEGP's outstanding Class B shares and an equivalent number of Tallgrass Equity units. The Exchange Right Holders are entitled to exercise the right to exchange their Tallgrass Equity units (together with an equivalent number of TEGP Class B shares) for TEGP Class A shares at an exchange ratio of one TEGP Class A share for each Tallgrass Equity unit exchanged, which we refer to as the Exchange Right. The Exchange Right Holders primarily consist of Kelso & Company and its affiliated investment funds, The Energy & Minerals Group and its affiliated investment funds, and Tallgrass KC, LLC, which is an entity owned by certain members of TEGP's and TEP's management. Pursuant to the TEGP partnership agreement and the Tallgrass Equity limited liability company agreement, our capital structure and the capital structure of Tallgrass Equity will generally replicate one another in order to maintain the one-for-one exchange ratio between the Tallgrass Equity units and Class B shares, on the one hand, and our Class A shares, on the other hand. As a result, the potential exchange of any Class B shares does not have a dilutive effect on basic net income per Class A share. There were no potentially dilutive securities outstanding during the three and six months ended June 30, 2015. For the six months ended June 30, 2016 the potential issuance of any TEGP Equity Participation Shares did not have a dilutive effect on basic net income per Class A share. The following table illustrates the calculation of basic and diluted net income per Class A share for the three and six months ended June 30, 2016 and 2015:
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Regulatory Matters |
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Jun. 30, 2016 | |
Regulatory Matters [Abstract] | |
Regulatory Matters | There are currently no proceedings challenging the currently effective rates of Pony Express, Rockies Express or Trailblazer Pipeline Company LLC ("Trailblazer"). On October 30, 2015, Tallgrass Interstate Gas Transmission, LLC ("TIGT") filed a general rate case with the FERC pursuant to Section 4 of the Natural Gas Act ("NGA"), discussed in more detail below. Regulators, as well as shippers, do have rights, under circumstances prescribed by applicable law, to challenge the rates that we charge at our regulated entities. Further, applicable law governing service by Pony Express allows parties having standing to file complaints in regard to existing tariff rates and provisions. If the complaint is not resolved, the FERC may conduct a hearing and order a crude oil pipeline like the Pony Express System to make reparations going back for up to two years prior to the date on which a complaint was filed if a rate is found to be unjust and unreasonable. We can provide no assurance that current rates will remain unchallenged. Any successful challenge could have a material, adverse effect on our future earnings and cash flows. TIGT General Rate Case Filing – FERC Docket RP16-137 On October 30, 2015, TIGT filed a general rate case with the FERC pursuant to Section 4 of the NGA. The rate case proposed a general system-wide increase in the maximum tariff rates for all firm and interruptible services offered by TIGT. In addition, TIGT proposed certain changes to the transportation rate design of its system to replace the current rate zone structure with a single "postage stamp" rate. TIGT also proposed new incremental charges, including (i) a charge for deliveries made to points without certain electronic flow measurement equipment, and (ii) a Cost Recovery Mechanism ("CRM") charge to completely or partially reimburse TIGT for certain costs it incurred to maintain system safety, environmental compliance and reliability. TIGT also proposed to replace its fixed fuel and lost and unaccounted for ("FL&U") charge with a FL&U tracker that would compensate TIGT for its actual FL&U expenses and adjust each year to reflect the previous period's under/over collection and the forecasted FL&U expense for the upcoming period. TIGT also proposed to implement a power cost tracker to recover the actual power costs incurred by TIGT to power its compressors. Finally, TIGT proposed certain revisions to its FERC Gas Tariff addressing a number of other rate and non-rate matters. Under the NGA and the FERC's regulations, TIGT's shippers and other interested parties, including the FERC's Trial Staff, have a right to challenge any aspect of TIGT's rate case filing. Accordingly, numerous TIGT customers have protested aspects of TIGT's NGA Section 4 rate filing. On November 30, 2015, the FERC issued an order accepting and suspending the proposed rates and certain proposed tariff records to be effective upon motion May 1, 2016, subject to refund, certain modifications to TIGT's proposed CRM charge, and the outcome of an evidentiary hearing before a FERC Administrative Law Judge (the "Suspension Order"). In the Suspension Order, the FERC also accepted two tariff records related to force majeure events and reservation charge crediting to be effective December 1, 2015, subject to certain modifications. On December 21, 2015, TIGT made a compliance filing with the FERC to modify TIGT's proposed CRM charge and update the tariff records related to force majeure events and reservation charge crediting as directed by the FERC in the Suspension Order. No comments or protests were filed in response to the compliance filing and FERC accepted the compliance filing on February 1, 2016. On March 22, 2016, a Settlement Judge was appointed in the case to assist the participants in exploring the possibility of settlement. On March 31, 2016, the FERC issued an order denying certain rehearing requests concerning the CRM, granting in part a motion to remove certain pro forma tariff records from the hearing, and also requested comments in order to assess the need for a technical conference. The FERC also retained for resolution through hearing the pro forma tariff records related to TIGT's proposed charge at delivery points lacking electronic flow measurement and removed from hearing the other issues related to the pro forma tariff records. Whether any issues will be resolved through technical conference is pending. The FERC also directed TIGT to provide additional information related to certain pro forma tariff records, which TIGT filed on April 14, 2016. On June 23, 2016, the Commission approved the implementation of TIGT’s filed postage stamp rates, subject to refund, effective on May 1, 2016. TIGT has reached an agreement in principle with customers representing a majority of firm fee revenue on the TIGT System for the year ended December 31, 2015 to settle all rate related issues set for hearing in its existing FERC rate case, including the issues of a cost recovery mechanism and a non-Electronic Flow Measurement charge. On May 5, 2016, the Acting Chief Administrative Law Judge issued an Order suspending the procedural schedule in the case as a result of the agreement in principle. On June 8, 2016, TIGT filed with the Commission its offer of settlement which resolves all issues in the case, with the exception of certain non-rate related tariff issues which remain subject to the Commission’s review and approval. On June 9, 2016, the Presiding Administrative Law Judge issued an Order shortening the period for any comments on the settlement, such that comments were due by June 13, 2016. No adverse comments were filed. The offer of settlement was certified to the Commission by the Administrative Law Judge on July 14, 2016. The Judge found that the settlement is uncontested, presents no issues of first impression, has no Commission policy implications, and appears to be just, reasonable, and in the public interest. The settlement is now subject to the final approval of the FERC. Trailblazer 2016 Annual Fuel Tracker Filing – FERC Docket RP16-814-000 On April 1, 2016, Trailblazer made its annual fuel tracker filing with a proposed effective date of May 1, 2016 in Docket No. RP16-814-000. The FERC accepted this filing on April 18, 2016. Rockies Express Annual FERC Fuel Tracking Filings – Docket No. RP16-702 On March 1, 2016, Rockies Express made its annual fuel tracker filing with a proposed effective date of April 1, 2016 in Docket No. RP16-702. The FERC issued an order accepting the filing on March 25, 2016. Seneca Lateral Facilities Conversion On March 2, 2015 in Docket No. CP15-102-000, Rockies Express filed with FERC an application for (1) authorization to convert certain existing and operating pipeline and compression facilities located in Noble and Monroe Counties, Ohio (Seneca Lateral Facilities described in Docket Nos. CP13-539-000 and CP14-194-000) from Natural Gas Policy Act of 1978 Section 311 authority to Natural Gas Act Section 7 jurisdiction, and (2) issuance of a certificate of public convenience and necessity authorizing Rockies Express to operate and maintain the Seneca Lateral Facilities. On April 7, 2016, the FERC issued a Certificate to Rockies Express granting its requested authorizations. As directed by the FERC, Rockies Express filed revised rates for Natural Gas Act service on the Seneca Lateral and the pipeline announced that Natural Gas Act service would commence on June 1, 2016. Rockies Express Zone 3 Capacity Enhancement Project On March 31, 2015 in Docket No. CP15-137-000, Rockies Express filed with FERC an application for authorization to construct and operate (1) three new mainline compressor stations located in Pickaway and Fayette Counties, Ohio and Decatur County, Indiana; (2) additional compressors at an existing compressor station in Muskingum County, Ohio; and (3) certain ancillary facilities. The proposed facilities will increase the Rockies Express Zone 3 east-to-west mainline capacity by 800,000 Dth/d from receipts at Clarington, Ohio to corresponding deliveries of 520,000 Dth/d and 280,000 Dth/d to Lebanon, Ohio and Moultrie County, Illinois, respectively. Pursuant to the FERC's obligations under the National Environmental Policy Act, FERC staff issued an Environmental Assessment for the project on August 31, 2015. On February 25, 2016, the FERC issued a Certificate of Public Convenience and Necessity authorizing Rockies Express to proceed with the project. On March 14, 2016, Rockies Express commenced construction of the project facilities, which are expected to be placed into service in the fourth quarter of 2016. |
Legal and Environmental Matters |
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Jun. 30, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
Legal and Environmental Matters | Legal In addition to the matters discussed below, we are a defendant in various lawsuits arising from the day-to-day operations of our business. Although no assurance can be given, we believe, based on our experiences to date, that the ultimate resolution of such routine items will not have a material adverse impact on our business, financial position, results of operations or cash flows. We have evaluated claims in accordance with the accounting guidance for contingencies that we deem both probable and reasonably estimable and, accordingly, had no reserve for legal claims as of June 30, 2016 or December 31, 2015. Rockies Express Mineral Management Service Lawsuit On June 30, 2009, Rockies Express filed claims against Mineral Management Service, a former unit of the U.S. Department of Interior (collectively "Interior") for breach of its contractual obligation to sign transportation service agreements and to pay approximately $192 million for pipeline capacity that it had agreed to take on Rockies Express. The Civilian Board of Contract Appeals ("CBCA") conducted a trial and ruled that Interior was liable for breach of contract, but limited the damages Interior was required to pay. On September 13, 2013, the United States Court of Appeals for the Federal Circuit issued a decision affirming that Interior was liable for its breach of contract, but reversing the CBCA's decision to limit damages. The case was remanded to the CBCA for the purpose of calculating damages at a hearing. On May 20, 2016, Rockies Express and Interior agreed to resolve the claims in this matter in exchange for a $65 million cash payment to Rockies Express. Interior paid the amount due Rockies Express on June 23, 2016. Ultra Resources In early 2016, Ultra Resources, Inc. ("Ultra"), defaulted on its firm transportation service agreement for approximately 0.2 Bcf/d through November 11, 2019. In late March 2016, Rockies Express terminated Ultra's service agreement. On April 14, 2016, Rockies Express filed a lawsuit against Ultra for breach of contract and damages in Harris County, Texas, in which Rockies Express seeks approximately $303 million in damages and other relief. Specifically, Rockies Express has asserted that Ultra owes approximately $303 million for past transportation service charges and for reservation charge fees that Rockies Express would have received over the term of the service agreement had Ultra not defaulted, in addition to other amounts owed under law or equity. On April 29, 2016, Ultra and certain of its debtor affiliates filed for protection under Chapter 11 of the United States Bankruptcy Code in United States Bankruptcy Court for the Southern District of Texas. On May 10, 2016, Ultra filed a notice of bankruptcy in the Harris County state court proceeding, which asserted that pursuant to section 362(a) of the Bankruptcy Code, the filing of Ultra’s Chapter 11 petition operated as a stay of the Harris County state court proceeding. Accordingly, Rockies Express intends to pursue its approximately $303 million claim in Ultra’s Chapter 11 proceeding. Michels Corporation On June 17, 2014, Michels Corporation ("Michels") filed a complaint and request for relief against Rockies Express as a result of work performed by Michels to construct the Seneca Lateral Pipeline in Ohio. Michels seeks unspecified damages from Rockies Express and asserts claims of breach of contract, negligent misrepresentation, unjust enrichment and quantum meruit. Michels has also filed notices of Mechanic's Liens in Monroe and Noble Counties, asserting $24.2 million as the amount due. The case is currently scheduled to go to trial in April 2017. Rockies Express also previously filed Petition for Declaratory Judgment, Injunctive Relief and Damages against Michels in Johnson County, Kansas. That claim was dismissed without prejudice in September 2015. Rockies Express believes Michels' claims are without merit and plans to continue to vigorously contest all of the claims in this matter. Environmental, Health and Safety We are subject to a variety of federal, state and local laws that regulate permitted activities relating to air and water quality, waste disposal, and other environmental matters. We believe that compliance with these laws will not have a material adverse impact on our business, cash flows, financial position or results of operations. However, there can be no assurances that future events, such as changes in existing laws, the promulgation of new laws, or the development of new facts or conditions will not cause us to incur significant costs. We had environmental reserves of $4.4 million and $4.8 million at June 30, 2016 and December 31, 2015, respectively. TMID Casper Plant, EPA Notice of Violation In August 2011, the EPA and the Wyoming Department of Environmental Quality ("WDEQ") conducted an inspection of the Leak Detection and Repair ("LDAR") Program at the Casper Gas Plant in Wyoming. In September 2011, Tallgrass Midstream, LLC ("TMID") received a letter from the EPA alleging violations of the Standards of Performance of Equipment Leaks for Onshore Natural Gas Processing Plant requirements under the Clean Air Act. TMID received a letter from the EPA concerning settlement of this matter in April 2013 and received additional settlement communications from the EPA and Department of Justice beginning in July 2014. Settlement negotiations are continuing, including the expected inclusion of TIGT as a party to any possible settlement as a result of TIGT owning a compressor that is located adjacent to the Casper Gas Plant site. Casper Mystery Bridge Superfund Site The Casper Gas Plant is part of the Mystery Bridge Road/U.S. Highway 20 Superfund Site also known as Casper Mystery Bridge Superfund Site. Remediation work at the Casper Gas Plant has been completed and we have requested that the portion of the site attributable to us be delisted from the National Priorities List. Casper Gas Plant On November 25, 2014, WDEQ issued a Notice of Violation for violations of Part 60 Subpart OOOO related to the Depropanizer project (wv-14388, issued 7/9/13) in Docket No. 5506-14. TMID had discussed the issues in a meeting with WDEQ in Cheyenne on November 17, 2014, and submitted a disclosure on November 20, 2014 detailing the regulatory issues and potential violations. The project triggered a modification of Subpart OOOO for the entire plant. The project equipment as well as plant equipment subjected to Subpart OOOO was not monitored timely, and initial notification was not made timely. Settlement negotiations with WDEQ are currently ongoing. Trailblazer Pipeline Integrity Management Program In 2014 and 2015, Trailblazer conducted smart tool surveys and preliminary analysis on segments of its natural gas pipeline to evaluate the growth rate of corrosion downstream of compressor stations. Trailblazer currently believes that approximately 25 - 35 miles of pipe will likely need to be repaired or replaced in order for the pipeline to operate at its maximum allowable operating pressure of 1,000 pounds per square inch. Such repair or replacement will likely occur over a period of years, depending upon final assessment of corrosion growth rates and the remediation and repair plan implemented by Trailblazer. Trailblazer is currently operating at less than its current maximum allowable operating pressure, public notice of which was first provided in June 2014. The current pressure reduction is not expected to prevent Trailblazer from fulfilling its firm service obligations at existing subscription levels and to date it has not had a material adverse financial impact on TEP. During 2015, Trailblazer completed 32 excavation digs at an aggregate cost of approximately $1.3 million based on preliminary analysis of the smart tool surveys performed in 2014. Segments of the Trailblazer Pipeline that require full replacement are currently expected to cost in the range of approximately $2.2 million to $2.7 million per mile. Repair costs on sections of the pipeline that do not require full replacement are expected to be less on a per mile basis. Trailblazer is continuing to develop a remediation and repair plan, which involves, among other things, finalizing cost recovery options, establishing project scope and timing and setting an overall project budget. In 2016, Trailblazer intends to replace approximately 8 miles of pipe, install additional ground beds, and continue remediating areas with external control anomalies at an estimated cost of $21.5 million. Trailblazer is currently exploring all possible cost recovery options. It may not ultimately be able to recover any or all of such out of pocket costs unless and until Trailblazer recovers them through a general rate increase or other FERC-approved recovery mechanism, or through negotiated rate agreements with its customers. In connection with TEP's acquisition of the Trailblazer Pipeline, TD agreed to contractually indemnify TEP for any out of pocket costs incurred between April 1, 2014 and April 1, 2017 related to repairing or remediating the Trailblazer Pipeline, to the extent that such actions are necessitated by external corrosion caused by the pipeline's disbonded Hi-Melt CTE coating. The contractual indemnity provided to TEP by TD is currently capped at $20 million and is subject to an annual $1.5 million deductible. |
Reporting Segments |
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Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reporting Segments | Our operations are located in the United States. We are organized into three reporting segments: (1) Crude Oil Transportation & Logistics, (2) Natural Gas Transportation & Logistics, and (3) Processing & Logistics. Crude Oil Transportation & Logistics The Crude Oil Transportation & Logistics segment is engaged in the ownership, and operation of the Pony Express System, which is a FERC-regulated crude oil pipeline serving the Bakken Shale and other nearby oil producing basins. The mainline portion of the Pony Express System was placed in service in October 2014. The Pony Express System also includes a lateral pipeline in Northeast Colorado, which interconnects with the Pony Express System just east of Sterling, Colorado and was placed in service in the second quarter of 2015. Natural Gas Transportation & Logistics The Natural Gas Transportation & Logistics segment is engaged in the ownership and operation of FERC-regulated interstate natural gas pipelines and integrated natural gas storage facilities that provide services to on-system customers (such as third-party LDCs), industrial users and other shippers. The Natural Gas Transportation & Logistics segment includes our 25% membership interest in Rockies Express effective May 6, 2016, as discussed in Note 3 – Acquisitions. Processing & Logistics The Processing & Logistics segment is engaged in the ownership and operation of natural gas processing, treating and fractionation facilities that produce NGLs and residue gas that is sold in local wholesale markets or delivered into pipelines for transportation to additional end markets, as well as water business services provided primarily to the oil and gas exploration and production industry and the transportation of NGLs. Corporate and Other Corporate and Other includes corporate overhead costs that are not directly associated with the operations of our reportable segments, such as interest and fees associated with our revolving credit facility, public company costs, and equity-based compensation expense. These segments are monitored separately by management for performance and are consistent with internal financial reporting. These segments have been identified based on the differing products and services, regulatory environment and the expertise required for their respective operations. The following tables set forth our segment information for the periods indicated:
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Subsequent Events Subsequent Events |
6 Months Ended |
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Jun. 30, 2016 | |
Subsequent Events [Abstract] | |
Subsequent Events | On July 1, 2016, we acquired the remaining 8% noncontrolling equity interest in Water Solutions and additional interests in certain of Water Solutions' subsidiaries from Regency Investments I, LLC and BSEG Water Group LLC for total cash consideration of $6.0 million, which will be accounted for as an acquisition of noncontrolling interest. Subsequent to the closing of the transaction, our aggregate membership interest in Water Solutions is 100%. |
Summary of Significant Accounting Policies (Policies) |
6 Months Ended |
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Jun. 30, 2016 | |
Accounting Policies [Abstract] | |
Basis of Presentation | Basis of Presentation These condensed consolidated financial statements and related notes for the three and six months ended June 30, 2016 and 2015 were prepared in accordance with the accounting principles contained in the Financial Accounting Standards Board's Accounting Standards Codification, the single source of generally accepted accounting principles in the United States of America ("GAAP") for interim financial information. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. The year-end balance sheet data was derived from audited financial statements but does not include all disclosures required by GAAP for annual periods. The condensed consolidated financial statements for the three and six months ended June 30, 2016 and 2015 include all normal, recurring adjustments and disclosures that we believe are necessary for a fair statement of the results for the interim periods. In this report, the Financial Accounting Standards Board is referred to as the FASB and the FASB Accounting Standards Codification is referred to as the Codification or ASC. Certain prior period amounts have been reclassified to conform to the current presentation. Our financial results for the three and six months ended June 30, 2016 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2016. The accompanying condensed consolidated interim financial statements should be read in conjunction with our audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2015 ("2015 Form 10-K") filed with the United States Securities and Exchange Commission (the "SEC") on February 17, 2016. The condensed consolidated financial statements of TEGP for the three and six months ended June 30, 2015 include historical cost basis accounts of the assets of TEGP and were prepared in contemplation of TEGP's initial public offering of Class A shares completed on May 12, 2015 and the acquisition of an approximately 30.35% interest in Tallgrass Equity as described in Note 1 – Description of Business, which was accounted for as a transaction between entities under common control in accordance with ASC 805. Significant intra-entity items have been eliminated in the presentation. Both TEGP and TEGP Predecessor are considered entities under common control and, as such, the transfer between the entities of the assets and liabilities has been recorded by TEGP at historical cost. TEGP, as used herein, refers to the consolidated financial results and operations for TEGP Predecessor prior to the completion of the Offering and to TEGP thereafter. |
Consolidation | Net income or loss from consolidated subsidiaries that are not wholly-owned by TEGP is attributed to TEGP and noncontrolling interests. This is done in accordance with substantive profit sharing arrangements, which generally follow the allocation of cash distributions and may not follow the respective ownership percentages held by TEGP. Concurrent with TEP's acquisition of an initial 33.3% membership interest in Pony Express effective September 1, 2014, TEP, Tallgrass Development, LP ("TD"), and Pony Express entered into the Second Amended and Restated Limited Liability Agreement of Tallgrass Pony Express Pipeline, LLC ("the Second Amended Pony Express LLC Agreement"), which provided TEP a minimum quarterly preference payment of $16.65 million (prorated to approximately $5.4 million for the quarter ended September 30, 2014) through the quarter ended September 30, 2015. Effective March 1, 2015 with TEP's acquisition of an additional 33.3% membership interest in Pony Express, the Second Amended Pony Express LLC Agreement was further amended (as amended, "the Pony Express LLC Agreement") to increase the minimum quarterly preference payment to $36.65 million (prorated to approximately $23.5 million for the quarter ended March 31, 2015) and extend the term of the preference period through the quarter ended December 31, 2015. The Pony Express LLC Agreement provides that the net income or loss of Pony Express be allocated, to the extent possible, consistent with the allocation of Pony Express cash distributions. Under the terms of the Pony Express LLC Agreement, Pony Express distributions and net income for periods beginning after December 31, 2015 are attributed to TEP and its noncontrolling interests in accordance with the respective ownership interests. A variable interest entity ("VIE") is a legal entity that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity owners who do not have the obligation to absorb expected losses or the right to receive the expected residual returns of the entity. Companies are required to consolidate a VIE if they are its primary beneficiary, which is the enterprise that has a variable interest that could be significant to the VIE and the power to direct the activities that most significantly impact the entity's economic performance. We have presented separately in our condensed consolidated balance sheets, to the extent material, the liabilities of our consolidated VIEs for which creditors do not have recourse to our general credit. Our consolidated VIEs do not have material assets that can only be used to settle specific obligations of the consolidated VIEs. Tallgrass Equity is considered to be a VIE under the applicable authoritative guidance. Based on a qualitative analysis in accordance with the applicable authoritative guidance, we have determined that we are the primary beneficiary as we have the right to receive benefits of Tallgrass Equity that could potentially be significant to Tallgrass Equity. Also, as discussed further under "New Accounting Pronouncements" below, under the new authoritative guidance effective January 1, 2016, TEP is considered to be a VIE. Based on a qualitative analysis, we have determined that TEP GP is the primary beneficiary of TEP and we continue to consolidate TEP accordingly. Pony Express was considered to be a VIE under the applicable authoritative guidance prior to our acquisition of an additional 31.3% membership interest effective January 1, 2016. Effective January 1, 2016, Pony Express is no longer considered to be a VIE. We continue to consolidate our membership interest in Pony Express. |
Use of Estimates | Use of Estimates Certain amounts included in or affecting these condensed consolidated financial statements and related disclosures must be estimated, requiring management to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time the financial statements are prepared. These estimates and assumptions affect the amounts reported for assets, liabilities, revenues, and expenses during the reporting period, and the disclosure of contingent assets and liabilities at the date of the financial statements. Management evaluates these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods it considers reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from these estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. |
Accounting Pronouncements Issued But Not Yet Effective | New Accounting Pronouncements Revenue Recognition In May 2014, the FASB issued Accounting Standards Update ("ASU") No. 2014-09, Revenue from Contracts with Customers (Topic 606). ASU 2014-09 provides a comprehensive and converged set of principles-based revenue recognition guidelines which supersede the existing industry and transaction-specific standards. The core principle of the new guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. To achieve this core principle, entities must apply a five step process to (1) identify the contract with a customer; (2) identify the performance obligations in the contract; (3) determine the transaction price; (4) allocate the transaction price to the performance obligations in the contract; and (5) recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 also mandates disclosure of sufficient information to enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The disclosure requirements include qualitative and quantitative information about contracts with customers, significant judgments and changes in judgments, and assets recognized from the costs to obtain or fulfill a contract. Throughout the first half of 2016, the FASB has issued a series of subsequent updates to the revenue recognition guidance in Topic 606, including ASU No. 2016-08, Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net), ASU No. 2016-10, Revenue from Contracts with Customers (Topic 606): Identifying Performance Obligations and Licensing, and ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients. The amendments in ASU 2014-09, ASU 2016-08, ASU 2016-10, and ASU 2016-12 are effective for public entities for annual reporting periods beginning after December 15, 2017, and for interim periods within that reporting period. Early application is permitted for annual reporting periods beginning after December 15, 2016. We are currently evaluating the impact of these updates. ASU No. 2015-11, "Inventory (Topic 330): Simplifying the Measurement of Inventory" In July 2015, the FASB issued ASU No. 2015-11, Inventory (Topic 330), Simplifying the Measurement of Inventory. ASU 2015-11 establishes a "lower of cost and net realizable value" model for the measurement of most inventory balances. Net realizable value is the estimated selling prices in the ordinary course of business, less reasonably predictable costs of completion, disposal, and transportation. The amendments in ASU 2015-11 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2016. Early adoption is permitted. We are currently evaluating the impact of ASU 2015-11. ASU No. 2015-17, "Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes" In November 2015, the FASB issued ASU No. 2015-17, Income Taxes (Topic 740): Balance Sheet Classification of Deferred Taxes. ASU 2015-17 simplifies the presentation of deferred income taxes. The amendments in this update require that deferred tax liabilities and assets be classified as noncurrent in a classified statement of financial position. The amendments in ASU 2015-17 are effective for financial statements issued for annual periods beginning after December 15, 2016, and interim periods within those annual periods. Earlier application is permitted for all entities as of the beginning of an interim or annual reporting period. The adoption of ASU 2015-17 did not have a material impact on our financial position and results of operations. ASU No. 2016-02, "Leases (Topic 842)" In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842). ASU 2016-02 provides a comprehensive update to the lease accounting topic in the Codification intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The amendments in ASU 2016-02 include a revised definition of a lease as well as certain scope exceptions. The changes primarily impact lessee accounting, while lessor accounting is largely unchanged from previous GAAP. The amendments in ASU 2016-02 are effective for public entities for annual reporting periods beginning after December 15, 2018, and for interim periods within that reporting period. Early application is permitted. We are currently evaluating the impact of ASU 2016-02. ASU No. 2016-09, "Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting" In March 2016, the FASB issued ASU No. 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. ASU 2016-09 simplifies several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. Among other changes, ASU 2016-09 allows an entity to make an entity-wide accounting policy election to either estimate the number of awards expected to vest (consistent with current GAAP) or account for forfeitures when they occur. The amendments in ASU 2016-09 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2016. Early adoption is permitted. We are currently evaluating the impact of ASU 2016-09. ASU No. 2015-16, "Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments" In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments. ASU 2015-16 simplifies the accounting for measurement-period adjustments for provisional amounts recognized in a business combination by eliminating the requirement for an acquirer to retrospectively account for measurement-period adjustments. Under the updated guidance, the acquirer must recognize adjustments in the reporting period in which the adjustment amounts are determined and the effect on earnings as a result of the change to the provisional amounts must be calculated as if the accounting had been completed at the acquisition date. The amendments in ASU 2015-16 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2015. The adoption of ASU 2015-16 did not have a material impact on our financial position and results of operations. ASU No. 2015-02, "Consolidation (Topic 810): Amendments to the Consolidation Analysis" In February 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810) - Amendments to the Consolidation Analysis. ASU 2015-02 will change the analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities. ASU 2015-02 will modify the evaluation of whether limited partnerships and other similar legal entities are considered VIEs or voting interest entities, eliminate the presumption that a general partner should consolidate a limited partnership, and change certain aspects of the consolidation analysis for reporting entities that are involved with VIEs, particularly for those with fee arrangements and related party relationships. The amendments in ASU 2015-02 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2015. The adoption of ASU 2015-02 did not have a material impact on our financial position and results of operations. ASU No. 2014-12, "Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period" In June 2014, the FASB issued ASU No. 2014-12, Compensation - Stock Compensation (Topic 718), Accounting for Share-Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 provides explicit guidance on accounting for share-based payments requiring a specific performance target to be achieved in order for employees to become eligible to vest in the awards when that performance target may be achieved after the requisite service period for the award. The ASU requires that such performance targets be treated as a performance condition, and should not be reflected in the estimate of the grant-date fair value of the award. Instead, compensation cost should be recognized in the period in which it becomes probable that the performance target will be achieved. ASU 2014-12 is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. The adoption of ASU 2014-12 did not have a material impact on our financial position and results of operations. |
Acquisitions Equity Method Investments (Policies) |
6 Months Ended |
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Jun. 30, 2016 | |
Accounting Policies [Abstract] | |
Equity Method Investments, Policy | Our investment in Rockies Express is recorded under the equity method of accounting and reported as "Unconsolidated investment" on our condensed consolidated balance sheet. As of May 6, 2016, the difference between the fair value of our investment in Rockies Express of $436.0 million and the book value of the underlying net assets of approximately $840.7 million results in a negative basis difference of approximately $404.7 million. The basis difference has been allocated to property, plant and equipment and long-term debt based on their respective fair values at the date of acquisition. The amount of the basis difference allocated to property, plant and equipment is accreted over 35 years, which equates to the 2.86% composite depreciation rate utilized by Rockies Express to depreciate the underlying property, plant and equipment. The amount allocated to long-term debt is amortized over the remaining life of the various debt facilities. |
Acquisitions Business Acquisition Pro Forma Information (Tables) |
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Business Combinations [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Equity Method Investments | Summarized financial information for Rockies Express is as follows:
The basis difference at June 30, 2016 was allocated as follows:
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Business Acquisition, Pro Forma Information | TEGP's unaudited pro forma revenue and net income attributable to partners for the three and six months ended June 30, 2015 is presented below as if the acquisition of Western had been completed on January 1, 2015:
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Related Party Transactions (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Related Party Transactions [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Transactions with Affiliated Companies | Totals of transactions with affiliated companies are as follows:
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Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Consolidated Balance Sheets | Details of balances with affiliates included in "Accounts receivable, net" and "Accounts payable to related parties" in the condensed consolidated balance sheets are as follows:
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Schedule of Balances of Gas Imbalance with Affiliated Shippers | Balances of gas imbalances with affiliated shippers are as follows:
|
Inventory (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Components of Inventory | The components of inventory at June 30, 2016 and December 31, 2015 consisted of the following:
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Property, Plant and Equipment (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Jun. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Components of Property Plant and Equipment | A summary of net property, plant and equipment by classification is as follows:
|
Risk Management (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Fair Value of Derivative Contracts | The following table summarizes the fair values of our derivative contracts included in the condensed consolidated balance sheets:
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Derivative Contracts Included in Consolidated Statements of Income | The following table summarizes the impact of derivative contracts for the three and six months ended June 30, 2016 and 2015:
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Derivative Instruments Maximum Potential Exposure to Credit Loss [Table Text Block] | The maximum potential exposure to credit losses on our crude oil derivative contract at June 30, 2016 was:
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Schedule of Energy Commodity Derivative Contracts Based on Fair Value Hierarchy Established by Codification | The following table summarizes the fair value measurements of our derivative contracts as of June 30, 2016 based on the fair value hierarchy established by the Codification:
|
Long-term Debt (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Jun. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Line of Credit Facility [Line Items] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Carrying Amount and Fair value of Long-term Debt | The following table sets forth the carrying amount and fair value of our long-term debt, which is not measured at fair value in the condensed consolidated balance sheets as of June 30, 2016 and December 31, 2015, but for which fair value is disclosed:
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Tallgrass Equity, LLC | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Line of Credit Facility [Line Items] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Line of Credit Facilities | The following table sets forth the available borrowing capacity under the Tallgrass Equity revolving credit facility as of June 30, 2016 and December 31, 2015:
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Tallgrass Energy Partners | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Line of Credit Facility [Line Items] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Line of Credit Facilities | The following table sets forth the available borrowing capacity under the TEP revolving credit facility as of June 30, 2016 and December 31, 2015:
|
Partnership Equity and Distributions Partnership and Equity and Distributions (Tables) |
6 Months Ended | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2016 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Tallgrass Energy GP, LP | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summary of Distributions | The following table details the distributions for the periods indicated:
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Tallgrass Energy Partners | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summary of Distributions | TEP Distributions. The following table shows the TEP distributions for the periods indicated:
|
Net Income per Class A Share Net Income per Class A Share (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Earnings Per Share [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summary of Net Income per Class A Share | The following table illustrates the calculation of basic and diluted net income per Class A share for the three and six months ended June 30, 2016 and 2015:
|
Reporting Segments (Tables) |
6 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Jun. 30, 2016 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Summary of TEGP's Segment Information of Revenue | The following tables set forth our segment information for the periods indicated:
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Summary of TEGP's Segment Information of Earnings |
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Summary of TEGP's Segment Capital Expenditures |
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Summary of TEGP's Segment Information of Assets |
|
Description of Business - Additional Information (Detail) |
6 Months Ended |
---|---|
Jun. 30, 2016
shares
| |
Tallgrass Equity, LLC | |
Organization [Line Items] | |
Variable Interest Entity, Ownership Percentage | (30.35%) |
Tallgrass MLP GP, LLC | |
Organization [Line Items] | |
Limited Liability Company (LLC) or General Partner, Ownership Interest | 100.00% |
Tallgrass Energy Partners | |
Organization [Line Items] | |
Limited Liability Company (LLC) or General Partner, Ownership Interest | 1.09% |
General partner units issued | 834,391 |
Purchase of Stock, Number of Shares Purchased in Transaction | 20,000,000 |
Ownership Percentage Of Aggregate Partnership Equity, Including General Partner Units | 26.14% |
Summary of Significant Accounting Policies Accounting Policies (Details) - USD ($) $ in Thousands |
1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | 13 Months Ended | |||
---|---|---|---|---|---|---|---|---|
Sep. 01, 2014 |
Sep. 30, 2014 |
Mar. 31, 2015 |
Jun. 30, 2016 |
Dec. 31, 2015 |
Sep. 30, 2015 |
Jan. 01, 2016 |
Mar. 01, 2015 |
|
Pony Express Pipeline | ||||||||
Business Acquisition [Line Items] | ||||||||
Minimum Quarterly Distribution Required by Partnership Agreement | $ 36,650 | $ 16,650 | ||||||
Prorated Minimum Quarterly Distribution Required by Partnership Agreement | $ 5,400 | $ 23,500 | ||||||
Business Acquisition, Percentage of Voting Interests Acquired | 31.30% | 33.30% | ||||||
Tallgrass Equity, LLC | ||||||||
Business Acquisition [Line Items] | ||||||||
Variable Interest Entity, Ownership Percentage | (30.35%) | |||||||
Pony Express Pipeline | ||||||||
Business Acquisition [Line Items] | ||||||||
Variable Interest Entity, Ownership Percentage | (33.30%) |
Variable Interest Entity VIE Assets and Liabilities (Details) - USD ($) $ in Thousands |
6 Months Ended | ||||
---|---|---|---|---|---|
Sep. 01, 2014 |
Jun. 30, 2016 |
Jan. 01, 2016 |
Dec. 31, 2015 |
Mar. 01, 2015 |
|
Variable Interest Entity [Line Items] | |||||
Deferred Tax Assets, Net, Noncurrent | $ 442,846 | $ 452,430 | |||
Tallgrass Equity, LLC | |||||
Variable Interest Entity [Line Items] | |||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 30.35% | ||||
Pony Express Pipeline | |||||
Variable Interest Entity [Line Items] | |||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 33.30% | ||||
Pony Express Pipeline | |||||
Variable Interest Entity [Line Items] | |||||
Business Acquisition, Percentage of Voting Interests Acquired | 31.30% | 33.30% |
Related Party Transactions - Schedule of Transactions with Affiliated Companies (Detail) - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2016 |
Jun. 30, 2015 |
Jun. 30, 2016 |
Jun. 30, 2015 |
|
Related Party Transaction [Line Items] | ||||
Cost of transportation services | $ 7,295 | $ 6,233 | $ 14,551 | $ 10,591 |
Operation and maintenance | ||||
Related Party Transaction [Line Items] | ||||
Expenses related to transactions with affiliated companies | 6,323 | 5,825 | 12,461 | 11,248 |
General and administrative expense | ||||
Related Party Transaction [Line Items] | ||||
Expenses related to transactions with affiliated companies | 10,452 | 9,565 | 19,643 | 18,821 |
Property, Plant and Equipment | ||||
Related Party Transaction [Line Items] | ||||
Property, plant and equipment, net | $ 622 | $ 1,594 | $ 1,521 | $ 2,901 |
Related Party Transactions - Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Consolidated Balance Sheets (Detail) - USD ($) $ in Thousands |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | $ 0 | $ 15 |
Accounts Payable, Related Parties, Current | 7,086 | 7,755 |
Tallgrass Operations, LLC | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | 7,028 | 7,731 |
Rockies Express Pipeline LLC | ||
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | 0 | 15 |
Accounts Payable, Related Parties, Current | 58 | 7 |
Deeprock Development, LLC | ||
Related Party Transaction [Line Items] | ||
Accounts Payable, Related Parties, Current | $ 0 | $ 17 |
Related Party Transactions - Schedule of Balances of Gas Imbalance with Affiliated Shippers (Detail) - Affiliated Shippers - USD ($) $ in Thousands |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Related Party Transaction [Line Items] | ||
Affiliate gas balance receivables | $ 23 | $ 92 |
Affiliate gas balance payables | $ 167 | $ 227 |
Related Party Transactions - Additional Information (Detail) - USD ($) |
3 Months Ended | 6 Months Ended |
---|---|---|
Jun. 30, 2016 |
Jun. 30, 2015 |
|
Related Party Transaction [Line Items] | ||
Interest Income, Related Party | $ 400,000 | |
Public Company Expense | Tallgrass Development LP | ||
Related Party Transaction [Line Items] | ||
Public company cost reimbursement | $ 500,000 |
Inventory Inventory (Details) - USD ($) $ in Thousands |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Inventory Disclosure [Abstract] | ||
Crude oil | $ 5,752 | $ 2,661 |
Materials and supplies | 6,429 | 8,581 |
Natural gas liquids | 351 | 395 |
Gas in underground storage | 2,222 | 2,156 |
Inventory, Net | $ 14,754 | $ 13,793 |
Property Plant and Equipment - Components of Property Plant and Equipment (Detail) - USD ($) $ in Thousands |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Property, Plant and Equipment [Line Items] | ||
Accumulated depreciation and amortization | $ (171,590) | $ (133,427) |
Property, plant and equipment | 2,007,067 | 2,025,018 |
Crude oil pipelines | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 1,180,989 | 1,172,684 |
Natural gas pipelines | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 552,107 | 550,710 |
Processing and treating assets | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 255,767 | 254,073 |
Water business assets | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 80,736 | 81,098 |
General and other | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 81,876 | 69,181 |
Construction work in progress | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | $ 27,182 | $ 30,699 |
Risk Management - Schedule of Fair Value of Derivative Contracts (Detail) - USD ($) $ in Thousands |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Energy Related Derivative | ||
Derivatives, Fair Value [Line Items] | ||
Derivative asset at fair value | $ 148 | |
Equity Option | ||
Derivatives, Fair Value [Line Items] | ||
Derivative asset at fair value | 55,967 | |
Energy commodity derivative contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivative liability at fair value | 351 | |
Other Current Assets | Energy Related Derivative | ||
Derivatives, Fair Value [Line Items] | ||
Derivative asset at fair value | 148 | $ 0 |
Other Noncurrent Assets | Equity Option | ||
Derivatives, Fair Value [Line Items] | ||
Derivative asset at fair value | 55,967 | 0 |
Other Current Liabilities | Energy commodity derivative contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivative liability at fair value | $ 351 | $ 0 |
Risk Management - Derivative Contracts Included in Consolidated Statement of Income (Detail) - Derivatives not designated as hedging contracts [Member] - USD ($) $ in Thousands |
3 Months Ended | 6 Months Ended | ||
---|---|---|---|---|
Jun. 30, 2016 |
Jun. 30, 2015 |
Jun. 30, 2016 |
Jun. 30, 2015 |
|
Equity Option | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Amount of gain (loss) recognized in income on derivatives | $ 18,953 | $ 0 | $ 10,007 | $ 0 |
Energy commodity derivative contracts | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Amount of gain (loss) recognized in income on derivatives | (307) | (131) | (351) | (41) |
Energy Related Derivative | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Amount of gain (loss) recognized in income on derivatives | $ 148 | $ 0 | $ 148 | $ 0 |
Risk Management Derivative Instruments Maximum Potential Exposure to Credit Loss (Details) - Energy Related Derivative $ in Thousands |
Jun. 30, 2016
USD ($)
|
---|---|
Concentration Risk [Line Items] | |
Gross | $ 148 |
Netting agreement impact | 0 |
Cash collateral held | 0 |
Net Exposure | $ 148 |
Long-term Debt - Carrying Amount and Fair Value of Long-term Debt (Detail) - USD ($) $ in Thousands |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Debt Instrument [Line Items] | ||
Long-term Debt, Fair Value | $ 1,426,000 | $ 901,000 |
Long-term Debt | 1,426,000 | 901,000 |
Quoted prices in active markets for identical assets (Level 1) | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Fair Value | 0 | 0 |
Significant other observable inputs (Level 2) | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Fair Value | 1,426,000 | 901,000 |
Significant unobservable inputs (Level 3) | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Fair Value | $ 0 | $ 0 |
Partnership Equity and Distributions Partnership and Equity Distributions - TEGP Summary of Distributions (Details) - Tallgrass Energy GP, LP (TEGP) [Member] - USD ($) $ / shares in Units, $ in Thousands |
3 Months Ended | ||||
---|---|---|---|---|---|
Jun. 30, 2016 |
Mar. 31, 2016 |
Dec. 31, 2015 |
Sep. 30, 2015 |
Jun. 30, 2015 |
|
Distribution Made to Limited Partner [Line Items] | |||||
Partners' Capital Account, Distributions | $ 11,693 | $ 10,022 | $ 8,256 | $ 6,872 | $ 3,484 |
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ 0 | $ 0.210 | $ 0.173 | $ 0.144 | $ 0.073 |
Partnership Equity and Distributions Partnership Equity and Distributions - TEP Summary of Distributions (Details) - Tallgrass Energy Partners - USD ($) $ / shares in Units, $ in Thousands |
3 Months Ended | |||||
---|---|---|---|---|---|---|
Jun. 30, 2016 |
Mar. 31, 2016 |
Dec. 31, 2015 |
Sep. 30, 2015 |
Jun. 30, 2015 |
Mar. 31, 2015 |
|
Distribution Made to Limited Partner [Line Items] | ||||||
Limited Partners' Capital Account, Distribution Amount | $ 54,442 | $ 48,238 | $ 42,984 | $ 36,347 | $ 35,135 | $ 31,322 |
Incentive Distribution, Distribution | 24,262 | 19,816 | 15,332 | 11,567 | 10,418 | 6,934 |
General Partner Distributions | 911 | 830 | 724 | 660 | 627 | 530 |
Partners' Capital Account, Distributions | $ 79,615 | $ 68,884 | $ 59,040 | $ 48,574 | $ 46,180 | $ 38,786 |
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ 0.7550 | $ 0.7050 | $ 0.6400 | $ 0.6000 | $ 0.5800 | $ 0.5200 |
Regulatory Matters Regulatory Matters (Details) MMBTU / d in Thousands |
6 Months Ended |
---|---|
Jun. 30, 2016
MMBTU / d
| |
Public Utilities, General Disclosures [Line Items] | |
Capacity Enhancement | 800 |
Clarington, Ohio to Lebanon, Ohio [Member] | |
Public Utilities, General Disclosures [Line Items] | |
Capacity Enhancement | 520 |
Clarington, Ohio to Moultrie County, Illinois [Member] | |
Public Utilities, General Disclosures [Line Items] | |
Capacity Enhancement | 280 |
Reporting Segments Reporting Segments - Summary of TEP's Segment Information for Payments to Acquire Plant, Property and Equipment (Details) - USD ($) $ in Thousands |
6 Months Ended | |
---|---|---|
Jun. 30, 2016 |
Jun. 30, 2015 |
|
Segment Reporting Information [Line Items] | ||
Capital expenditures | $ 28,491 | $ 49,544 |
TEGP | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 28,491 | 49,544 |
TEGP | Crude Oil Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 19,160 | 32,501 |
TEGP | Natural Gas Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 4,115 | 7,061 |
TEGP | Processing & Logistics | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 5,216 | 9,982 |
TEGP | Corporate and Other | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | $ 0 | $ 0 |
Reporting Segments - Summary of TEGP's Segment Information of Assets (Detail) - USD ($) $ in Thousands |
Jun. 30, 2016 |
Dec. 31, 2015 |
---|---|---|
Segment Reporting Information [Line Items] | ||
Segment assets | $ 3,484,907 | $ 3,016,660 |
TEGP | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 3,484,907 | 3,016,660 |
TEGP | Crude Oil Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 1,425,917 | 1,439,418 |
TEGP | Natural Gas Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 1,142,222 | 706,576 |
TEGP | Processing & Logistics | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 408,055 | 409,795 |
TEGP | Corporate and Other | ||
Segment Reporting Information [Line Items] | ||
Segment assets | $ 508,713 | $ 460,871 |
Reporting Segments - Additional Information (Detail) - Segment |
6 Months Ended | |
---|---|---|
Jun. 30, 2016 |
May 06, 2016 |
|
Segment Reporting Information [Line Items] | ||
Number of reportable segments | 3 | |
Rockies Express Holdings, LLC | Sempra U.S. Gas and Power [Member] | ||
Segment Reporting Information [Line Items] | ||
Business Acquisition, Percentage of Voting Interests Acquired | 25.00% |
Subsequent Events (Details) - USD ($) $ in Thousands |
6 Months Ended | ||
---|---|---|---|
Jul. 01, 2016 |
Jun. 30, 2016 |
Jun. 30, 2015 |
|
Subsequent Event [Line Items] | |||
Payments to Noncontrolling Interests | $ 109,551 | $ 46,082 | |
Subsequent Event [Member] | Water Solutions | |||
Subsequent Event [Line Items] | |||
Business Acquisition, Percentage of Voting Interests Acquired | 8.00% | ||
Payments to Noncontrolling Interests | $ 6,000 | ||
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest | 100.00% |
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