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 | x | Accelerated filer | ¨ | |||
Non-accelerated filer | ¨ (Do not check if a smaller reporting company) | Smaller reporting company | ¨ | |||
Emerging growth company | ¨ |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
ASSETS | |||||||
Current Assets: | |||||||
Cash and cash equivalents | $ | 2,053 | $ | 2,459 | |||
Accounts receivable, net | 57,274 | 59,536 | |||||
Gas imbalances | 636 | 1,597 | |||||
Inventories | 15,647 | 13,093 | |||||
Derivative assets at fair value | 304 | 10,967 | |||||
Prepayments and other current assets | 6,785 | 7,628 | |||||
Total Current Assets | 82,699 | 95,280 | |||||
Property, plant and equipment, net | 2,085,670 | 2,079,232 | |||||
Goodwill | 343,288 | 343,288 | |||||
Intangible asset, net | 92,764 | 93,522 | |||||
Unconsolidated investments | 935,918 | 475,625 | |||||
Deferred tax asset | 518,790 | 521,454 | |||||
Deferred financing costs, net | 5,039 | 6,042 | |||||
Deferred charges and other assets | 9,242 | 11,037 | |||||
Total Assets | $ | 4,073,410 | $ | 3,625,480 | |||
LIABILITIES AND EQUITY | |||||||
Current Liabilities: | |||||||
Accounts payable | $ | 22,050 | $ | 24,449 | |||
Accounts payable to related parties | 6,067 | 5,824 | |||||
Gas imbalances | 1,473 | 1,239 | |||||
Derivative liabilities at fair value | — | 556 | |||||
Accrued taxes | 21,857 | 16,996 | |||||
Accrued liabilities | 6,796 | 16,755 | |||||
Deferred revenue | 77,067 | 60,757 | |||||
Other current liabilities | 6,001 | 6,446 | |||||
Total Current Liabilities | 141,311 | 133,022 | |||||
Long-term debt, net | 2,108,232 | 1,555,981 | |||||
Other long-term liabilities and deferred credits | 7,125 | 7,063 | |||||
Total Long-term Liabilities | 2,115,357 | 1,563,044 | |||||
Commitments and Contingencies | |||||||
Equity: | |||||||
Class A Shareholders (58,075,000 shares outstanding at March 31, 2017 and December 31, 2016) | 244,610 | 250,967 | |||||
Class B Shareholders (99,154,440 shares outstanding at March 31, 2017 and December 31, 2016) | — | — | |||||
Predecessor Equity | — | 82,295 | |||||
Total Partners' Equity | 244,610 | 333,262 | |||||
Noncontrolling interests | 1,572,132 | 1,596,152 | |||||
Total Equity | 1,816,742 | 1,929,414 | |||||
Total Liabilities and Equity | $ | 4,073,410 | $ | 3,625,480 |
Three Months Ended March 31, | |||||||
2017 | 2016 | ||||||
(in thousands, except per share amounts) | |||||||
Revenues: | |||||||
Crude oil transportation services | $ | 84,331 | $ | 94,572 | |||
Natural gas transportation services | 31,685 | 29,280 | |||||
Sales of natural gas, NGLs, and crude oil | 15,381 | 13,926 | |||||
Processing and other revenues | 13,003 | 9,390 | |||||
Total Revenues | 144,400 | 147,168 | |||||
Operating Costs and Expenses: | |||||||
Cost of sales (exclusive of depreciation and amortization shown below) | 12,370 | 13,568 | |||||
Cost of transportation services (exclusive of depreciation and amortization shown below) | 13,503 | 13,529 | |||||
Operations and maintenance | 12,903 | 12,958 | |||||
Depreciation and amortization | 21,403 | 22,007 | |||||
General and administrative | 14,217 | 14,011 | |||||
Taxes, other than income taxes | 8,226 | 7,650 | |||||
Gain on disposal of assets | (1,448 | ) | — | ||||
Total Operating Costs and Expenses | 81,174 | 83,723 | |||||
Operating Income | 63,226 | 63,445 | |||||
Other Income (Expense): | |||||||
Interest expense, net | (16,017 | ) | (8,677 | ) | |||
Unrealized gain (loss) on derivative instrument | 1,885 | (8,946 | ) | ||||
Equity in earnings of unconsolidated investments | 20,738 | 709 | |||||
Other income, net | 70 | 566 | |||||
Total Other Income (Expense) | 6,676 | (16,348 | ) | ||||
Net income before tax | 69,902 | 47,097 | |||||
Deferred income tax expense | (2,664 | ) | (2,791 | ) | |||
Net income | 67,238 | 44,306 | |||||
Net income attributable to noncontrolling interests | (55,209 | ) | (33,032 | ) | |||
Net income attributable to TEGP | $ | 12,029 | $ | 11,274 | |||
Allocation of income: | |||||||
Net income attributable to TEGP | $ | 12,029 | $ | 11,274 | |||
Predecessor operations interest in net income | — | (3,685 | ) | ||||
Net income attributable to TEGP, excluding predecessor operations interest | 12,029 | 7,589 | |||||
Basic net income per Class A share | $ | 0.21 | $ | 0.16 | |||
Diluted net income per Class A share | $ | 0.21 | $ | 0.16 | |||
Basic average number of Class A shares outstanding | 58,075 | 47,725 | |||||
Diluted average number of Class A shares outstanding | 58,165 | 47,725 |
Three Months Ended March 31, | |||||
2017 | 2016 | ||||
(in thousands) | |||||
Cash Flows from Operating Activities: | |||||
Net income | 67,238 | 44,306 | |||
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||||
Depreciation and amortization | 23,694 | 23,473 | |||
Equity in earnings of unconsolidated investments | (20,738 | ) | (709 | ) | |
Distributions from unconsolidated investments | 20,740 | 634 | |||
Deferred income tax expense | 2,664 | 2,791 | |||
Noncash change in the fair value of derivative financial instruments | (2,454 | ) | 8,990 | ||
Changes in components of working capital: | |||||
Accounts receivable and other | 2,449 | 6,077 | |||
Accounts payable and accrued liabilities | (6,055 | ) | (2,225 | ) | |
Deferred revenue | 16,202 | 7,204 | |||
Other current assets and liabilities | (819 | ) | 10 | ||
Other operating, net | (755 | ) | 1,144 | ||
Net Cash Provided by Operating Activities | 102,166 | 91,695 | |||
Cash Flows from Investing Activities: | |||||
Acquisition of Rockies Express membership interest | (400,000 | ) | — | ||
Acquisition of Terminals and NatGas | (140,000 | ) | — | ||
Capital expenditures | (26,769 | ) | (21,207 | ) | |
Distributions from unconsolidated investments in excess of cumulative earnings | 10,079 | — | |||
Contributions to unconsolidated investments | (6,693 | ) | (63 | ) | |
Acquisition of Pony Express membership interest | — | (49,118 | ) | ||
Other investing, net | 1,341 | 25 | |||
Net Cash Used in Investing Activities | (562,042 | ) | (70,363 | ) | |
Cash Flows from Financing Activities: | |||||
Borrowings under revolving credit facilities, net | 552,000 | 447,000 | |||
Proceeds from public offering of TEP common units, net of offering costs | 99,373 | 12,636 | |||
Partial exercise of call option | (72,381 | ) | — | ||
Distributions to noncontrolling interests | (71,426 | ) | (50,919 | ) | |
Repurchase of TEP common units from TD | (35,335 | ) | — | ||
TEGP distributions to Class A shareholders | (16,116 | ) | (8,256 | ) | |
Acquisition of Pony Express membership interest | — | (425,882 | ) | ||
Other financing, net | 3,355 | 5,654 | |||
Net Cash Provided by (Used in) Financing Activities | 459,470 | (19,767 | ) | ||
Net Change in Cash and Cash Equivalents | (406 | ) | 1,565 | ||
Cash and Cash Equivalents, beginning of period | 2,459 | 2,234 | |||
Cash and Cash Equivalents, end of period | 2,053 | 3,799 |
Predecessor Equity | Partners' Capital | Noncontrolling Interests | Total Equity | ||||||||||||||||
Class A Shares | Class B Shares | ||||||||||||||||||
(in thousands) | |||||||||||||||||||
Balance at January 1, 2017 | $ | 82,295 | $ | 250,967 | $ | — | $ | 1,596,152 | $ | 1,929,414 | |||||||||
Net income | — | 12,029 | — | 55,209 | 67,238 | ||||||||||||||
Issuance of TEP units to public, net of offering costs | — | 10,020 | — | 89,353 | 99,373 | ||||||||||||||
TEGP distributions to Class A shareholders | — | (16,116 | ) | — | — | (16,116 | ) | ||||||||||||
Noncash compensation expense | — | 362 | — | 1,882 | 2,244 | ||||||||||||||
Issuance of common units under TEP LTIP plan | — | (40 | ) | — | (360 | ) | (400 | ) | |||||||||||
Partial exercise of call option | — | (12,052 | ) | — | (72,890 | ) | (84,942 | ) | |||||||||||
Repurchase of TEP common units from TD | — | (3,618 | ) | — | (31,717 | ) | (35,335 | ) | |||||||||||
Acquisition of Terminals and NatGas | (82,295 | ) | (21,314 | ) | — | (36,391 | ) | (140,000 | ) | ||||||||||
Acquisition of additional 24.99% membership interest in Rockies Express | — | 23,522 | — | 40,159 | 63,681 | ||||||||||||||
Contributions from TD | — | 850 | — | 1,451 | 2,301 | ||||||||||||||
Contributions from noncontrolling interest | — | — | — | 710 | 710 | ||||||||||||||
Distributions to noncontrolling interest | — | — | — | (71,426 | ) | (71,426 | ) | ||||||||||||
Balance at March 31, 2017 | $ | — | $ | 244,610 | $ | — | $ | 1,572,132 | $ | 1,816,742 | |||||||||
Predecessor Equity | Partners' Capital | Noncontrolling Interests | Total Equity | ||||||||||||||||
Class A Shares | Class B Shares | ||||||||||||||||||
(in thousands) | |||||||||||||||||||
Balance at January 1, 2016 | $ | 71,564 | $ | 422,310 | $ | — | $ | 1,599,188 | $ | 2,093,062 | |||||||||
Net income | 3,685 | 7,589 | — | 33,032 | 44,306 | ||||||||||||||
Issuance of TEP units to the public, net of offering costs | — | 1,146 | — | 11,490 | 12,636 | ||||||||||||||
TEGP distributions to Class A Shareholders | — | (8,256 | ) | — | — | (8,256 | ) | ||||||||||||
Noncash compensation expense | — | 295 | — | 1,869 | 2,164 | ||||||||||||||
Acquisition of additional 31.3% Pony Express membership interest | — | (255,617 | ) | — | (173,422 | ) | (429,039 | ) | |||||||||||
Contributions from noncontrolling interest | — | — | — | 7,152 | 7,152 | ||||||||||||||
Distributions to noncontrolling interest | — | — | — | (50,919 | ) | (50,919 | ) | ||||||||||||
Distributions to Predecessor Entities, net | (693 | ) | — | — | — | (693 | ) | ||||||||||||
Balance at March 31, 2016 | $ | 74,556 | $ | 167,467 | $ | — | $ | 1,428,390 | $ | 1,670,413 |
• | 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 an approximate 1.14% general partner interest in TEP at March 31, 2017. |
• | 20,000,000 TEP common units, representing an approximate 27.39% limited partner interest in TEP at March 31, 2017. |
• | Crude Oil Transportation & Logistics—the ownership and operation of a FERC-regulated crude oil pipeline system and crude oil storage and terminalling facilities; |
• | 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. |
• | We have formed an implementation team that meets to discuss implementation challenges, technical interpretations, industry-specific treatment of certain revenue contract types, and project status. |
• | We are currently reviewing contracts for each revenue stream identified within each of our business segments. Through this process, we are determining and documenting expected changes in revenue recognition upon adoption of the revised guidance. |
• | We plan to evaluate the potential information technology and internal control changes that will be required for adoption based on the findings from our contract review process. |
• | We plan to provide internal training and awareness related to the revised guidance to the key stakeholders throughout our organization. |
Basis Difference | Amortization Period | ||||
(in thousands) | |||||
Long-term debt | $ | 19,504 | 2 - 25 years | ||
Property, plant and equipment | (406,301 | ) | 35 years | ||
Total basis difference | $ | (386,797 | ) |
December 31, 2016 | |||||||||||||||
TEGP (As previously reported) | Consolidate Terminals | Consolidate NatGas | TEGP (As currently reported) | ||||||||||||
(in thousands) | |||||||||||||||
ASSETS | |||||||||||||||
Current Assets: | |||||||||||||||
Cash and cash equivalents | $ | 2,459 | $ | — | $ | — | $ | 2,459 | |||||||
Accounts receivable, net | 59,469 | 38 | 29 | 59,536 | |||||||||||
Gas imbalances | 1,597 | — | — | 1,597 | |||||||||||
Inventories | 12,805 | 288 | — | 13,093 | |||||||||||
Derivative assets at fair value | 10,967 | — | — | 10,967 | |||||||||||
Prepayments and other current assets | 6,820 | 808 | — | 7,628 | |||||||||||
Total Current Assets | 94,117 | 1,134 | 29 | 95,280 | |||||||||||
Property, plant and equipment, net | 2,012,263 | 66,969 | — | 2,079,232 | |||||||||||
Goodwill | 343,288 | — | — | 343,288 | |||||||||||
Intangible asset, net | 93,522 | — | — | 93,522 | |||||||||||
Unconsolidated investments | 461,915 | 13,710 | — | 475,625 | |||||||||||
Deferred tax asset | 521,454 | — | — | 521,454 | |||||||||||
Deferred financing costs, net | 6,042 | — | — | 6,042 | |||||||||||
Deferred charges and other assets | 9,637 | 1,400 | — | 11,037 | |||||||||||
Total Assets | $ | 3,542,238 | $ | 83,213 | $ | 29 | $ | 3,625,480 | |||||||
LIABILITIES AND EQUITY | |||||||||||||||
Current Liabilities: | |||||||||||||||
Accounts payable | $ | 24,403 | $ | 46 | $ | — | $ | 24,449 | |||||||
Accounts payable to related parties | 5,768 | 56 | — | 5,824 | |||||||||||
Gas imbalances | 1,239 | — | — | 1,239 | |||||||||||
Derivative liabilities at fair value | 556 | — | — | 556 | |||||||||||
Accrued taxes | 16,328 | 668 | — | 16,996 | |||||||||||
Accrued liabilities | 16,578 | 177 | — | 16,755 | |||||||||||
Deferred revenue | 60,757 | — | — | 60,757 | |||||||||||
Other current liabilities | 6,446 | — | — | 6,446 | |||||||||||
Total Current Liabilities | 132,075 | 947 | — | 133,022 | |||||||||||
Long-term debt, net | 1,555,981 | — | — | 1,555,981 | |||||||||||
Other long-term liabilities and deferred credits | 7,063 | — | — | 7,063 | |||||||||||
Total Long-term Liabilities | 1,563,044 | — | — | 1,563,044 | |||||||||||
Equity: | |||||||||||||||
Net Equity | 1,847,119 | 82,266 | 29 | 1,929,414 | |||||||||||
Total Equity | 1,847,119 | 82,266 | 29 | 1,929,414 | |||||||||||
Total Liabilities and Equity | $ | 3,542,238 | $ | 83,213 | $ | 29 | $ | 3,625,480 |
Three Months Ended March 31, 2016 | |||||||||||||||||||
TEGP (As previously reported) | Consolidate Terminals | Consolidate NatGas | Elimination (1) | TEGP (As currently reported) | |||||||||||||||
(in thousands) | |||||||||||||||||||
Revenues: | |||||||||||||||||||
Crude oil transportation services | $ | 94,572 | $ | — | $ | — | $ | — | $ | 94,572 | |||||||||
Natural gas transportation services | 29,280 | — | — | — | 29,280 | ||||||||||||||
Sales of natural gas, NGLs, and crude oil | 13,926 | — | — | — | 13,926 | ||||||||||||||
Processing and other revenues | 7,627 | 2,909 | 1,681 | (2,827 | ) | 9,390 | |||||||||||||
Total Revenues | 145,405 | 2,909 | 1,681 | (2,827 | ) | 147,168 | |||||||||||||
Operating Costs and Expenses: | |||||||||||||||||||
Cost of sales (exclusive of depreciation and amortization shown below) | 13,568 | — | — | — | 13,568 | ||||||||||||||
Cost of transportation services (exclusive of depreciation and amortization shown below) | 16,156 | 200 | — | (2,827 | ) | 13,529 | |||||||||||||
Operations and maintenance | 12,477 | 481 | — | — | 12,958 | ||||||||||||||
Depreciation and amortization | 21,692 | 315 | — | — | 22,007 | ||||||||||||||
General and administrative | 13,537 | 474 | — | — | 14,011 | ||||||||||||||
Taxes, other than income taxes | 7,506 | 144 | — | — | 7,650 | ||||||||||||||
Total Operating Costs and Expenses | 84,936 | 1,614 | — | (2,827 | ) | 83,723 | |||||||||||||
Operating Income | 60,469 | 1,295 | 1,681 | — | 63,445 | ||||||||||||||
Other Income (Expense): | |||||||||||||||||||
Interest expense, net | (8,677 | ) | — | — | — | (8,677 | ) | ||||||||||||
Unrealized loss on derivative instrument | (8,946 | ) | — | — | — | (8,946 | ) | ||||||||||||
Equity in earnings of unconsolidated investments | — | 709 | — | — | 709 | ||||||||||||||
Other income, net | 566 | — | — | — | 566 | ||||||||||||||
Total Other (Expense) Income | (17,057 | ) | 709 | — | — | (16,348 | ) | ||||||||||||
Net income before tax | 43,412 | 2,004 | 1,681 | — | 47,097 | ||||||||||||||
Deferred income tax expense | (2,791 | ) | — | — | — | (2,791 | ) | ||||||||||||
Net income | 40,621 | 2,004 | 1,681 | — | 44,306 | ||||||||||||||
Net income attributable to noncontrolling interests | (33,032 | ) | — | — | — | (33,032 | ) | ||||||||||||
Net income attributable to TEGP | $ | 7,589 | $ | 2,004 | $ | 1,681 | $ | — | $ | 11,274 |
(1) | Represents the elimination of revenue and cost of transportation services associated with the lease of the Sterling Terminal facilities by Pony Express. |
Three Months Ended March 31, | |||||||
2017 | 2016 | ||||||
(in thousands) | |||||||
Cost of transportation services (1) | $ | 4,507 | $ | 4,429 | |||
Charges to TEGP: (2) | |||||||
Property, plant and equipment, net | $ | 293 | $ | 918 | |||
Operations and maintenance | $ | 6,277 | $ | 6,184 | |||
General and administrative | $ | 9,573 | $ | 9,437 |
(1) | Reflects rent expense for the crude oil storage at the Deeprock Terminal. |
(2) | Charges to TEGP, inclusive of Tallgrass Equity and TEP, include directly charged wages and salaries, other compensation and benefits, and shared services. |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
Receivable from related parties: | |||||||
Rockies Express Pipeline LLC | $ | 1,266 | $ | 590 | |||
Total receivable from related parties | $ | 1,266 | $ | 590 | |||
Accounts payable to related parties: | |||||||
Tallgrass Operations, LLC | $ | 6,047 | $ | 5,811 | |||
Tallgrass Management, LLC | 20 | — | |||||
Deeprock Development, LLC | — | 13 | |||||
Total accounts payable to related parties | $ | 6,067 | $ | 5,824 |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
Affiliate gas imbalance receivables | $ | — | $ | 177 | |||
Affiliate gas imbalance payables | $ | 73 | $ | — |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
Crude oil | $ | 6,903 | $ | 5,462 | |||
Materials and supplies | 6,455 | 6,383 | |||||
Natural gas liquids | 573 | 265 | |||||
Gas in underground storage | 1,716 | 983 | |||||
Total inventory | $ | 15,647 | $ | 13,093 |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
Crude oil pipelines | $ | 1,207,727 | $ | 1,202,125 | |||
Natural gas pipelines | 575,536 | 572,150 | |||||
Processing and treating assets | 262,447 | 256,901 | |||||
General and other | 225,243 | 223,310 | |||||
Construction work in progress | 29,770 | 20,606 | |||||
Accumulated depreciation and amortization | (215,053 | ) | (195,860 | ) | |||
Total property, plant and equipment, net | $ | 2,085,670 | $ | 2,079,232 |
Three Months Ended March 31, 2017 | |||
Revenue | $ | 201,338 | |
Operating income | $ | 107,369 | |
Net income to Members | $ | 66,250 |
Balance Sheet Location | March 31, 2017 | December 31, 2016 | |||||||
(in thousands) | |||||||||
Call option derivative (1) | Current assets | $ | — | $ | 10,676 | ||||
Crude oil derivative contracts (2) | Current assets | $ | 223 | $ | — | ||||
Natural gas derivative contracts (3) | Current assets | $ | 81 | $ | 291 | ||||
Crude oil derivative contracts (2) | Current liabilities | $ | — | $ | 440 | ||||
Natural gas derivative contracts (3) | Current liabilities | $ | — | $ | 116 |
(1) | As discussed below, in conjunction with TEP's acquisition of an additional 31.3% membership interest in Pony Express effective January 1, 2016, TD granted TEP an 18 month call option covering the 6,518,000 common units issued to TD. As of February 1, 2017, no common units remained subject to the call option. |
(2) | As of March 31, 2017 and December 31, 2016, the fair value shown for crude oil derivative contracts represents the sale of 125,000 barrels of crude oil which will settle throughout 2017. |
(3) | As of March 31, 2017, the fair value shown for natural gas derivative contracts was comprised of derivative volumes for long natural gas fixed-price swaps totaling 0.3 Bcf. As of December 31, 2016, the fair value shown for natural gas derivative contracts was comprised of derivative volumes for short and long natural gas fixed-price swaps totaling 0.3 Bcf and 0.4 Bcf, respectively. |
Location of gain (loss) recognized in income on derivatives | Amount of gain (loss) recognized in income on derivatives | ||||||||
Three Months Ended March 31, | |||||||||
2017 | 2016 | ||||||||
(in thousands) | |||||||||
Derivatives not designated as hedging contracts: | |||||||||
Call option derivative | Unrealized gain (loss) on derivative instrument | $ | 1,885 | $ | (8,946 | ) | |||
Natural gas derivative contracts | Sales of natural gas, NGLs, and crude oil | $ | 173 | $ | (44 | ) | |||
Crude oil derivative contracts | Sales of natural gas, NGLs, and crude oil | $ | 663 | $ | — |
Asset Position | |||
(in thousands) | |||
Gross | $ | 304 | |
Netting agreement impact | — | ||
Cash collateral held | — | ||
Net exposure | $ | 304 |
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 March 31, 2017: | |||||||||||||||
Crude oil derivative contracts | $ | 223 | $ | — | $ | 223 | $ | — | |||||||
Natural gas derivative contracts | $ | 81 | $ | — | $ | 81 | $ | — | |||||||
As of December 31, 2016: | |||||||||||||||
Call option derivative | $ | 10,676 | $ | — | $ | 10,676 | $ | — | |||||||
Natural gas derivative contracts | $ | 291 | $ | — | $ | 291 | $ | — | |||||||
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 December 31, 2016: | |||||||||||||||
Crude oil derivative contracts | $ | 440 | $ | — | $ | 440 | $ | — | |||||||
Natural gas derivative contracts | $ | 116 | $ | — | $ | 116 | $ | — |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
Tallgrass Equity revolving credit facility | $ | 148,000 | $ | 148,000 | |||
TEP revolving credit facility | 1,567,000 | 1,015,000 | |||||
TEP 5.50% senior notes due September 15, 2024 | 400,000 | 400,000 | |||||
Less: Deferred financing costs, net (1) | (6,768 | ) | (7,019 | ) | |||
Total long-term debt, net | $ | 2,108,232 | $ | 1,555,981 |
(1) | Deferred financing costs, net as presented above relate solely to the 2024 Notes. Deferred financing costs associated with our revolving credit facility are presented in noncurrent assets on our condensed consolidated balance sheets. |
March 31, 2017 | December 31, 2016 | ||||||
(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 |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
Total capacity under the TEP revolving credit facility | $ | 1,750,000 | $ | 1,750,000 | |||
Less: Outstanding borrowings under the TEP revolving credit facility (1) | (1,567,000 | ) | (1,015,000 | ) | |||
Available capacity under the TEP revolving credit facility | $ | 183,000 | $ | 735,000 |
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) | |||||||||||||||||||
As of March 31, 2017: | |||||||||||||||||||
Revolving credit facilities | $ | — | $ | 1,715,000 | $ | — | $ | 1,715,000 | $ | 1,715,000 | |||||||||
2024 Notes | $ | — | $ | 403,252 | $ | — | $ | 403,252 | $ | 393,232 | |||||||||
As of December 31, 2016: | |||||||||||||||||||
Revolving credit facilities | $ | — | $ | 1,163,000 | $ | — | $ | 1,163,000 | $ | 1,163,000 | |||||||||
2024 Notes | $ | — | $ | 398,000 | $ | — | $ | 398,000 | $ | 392,981 |
Three Months Ended | Date Paid | Distributions to Class A Shareholders | Distributions per Class A Share | ||||||||
(in thousands) | |||||||||||
March 31, 2017 | May 15, 2017 (1) | $ | 16,697 | $ | 0.2875 | ||||||
December 31, 2016 | February 14, 2017 | 16,116 | 0.2775 | ||||||||
September 30, 2016 | November 14, 2016 | 12,528 | 0.2625 | ||||||||
June 30, 2016 | August 12, 2016 | 11,693 | 0.2450 | ||||||||
March 31, 2016 | May 13, 2016 | 10,022 | 0.2100 |
(1) | The distribution announced on April 17, 2017 for the first quarter of 2017 will be paid on May 15, 2017 to Class A shareholders of record at the close of business on April 28, 2017. |
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) | ||||||||||||||||||||||
March 31, 2017 | May 15, 2017 (1) | $ | 60,486 | $ | 29,840 | $ | 1,040 | $ | 91,366 | $ | 0.8350 | |||||||||||
December 31, 2016 | February 14, 2017 | 58,793 | 28,358 | 1,008 | 88,159 | 0.8150 | ||||||||||||||||
September 30, 2016 | November 14, 2016 | 57,332 | 26,987 | 976 | 85,295 | 0.7950 | ||||||||||||||||
June 30, 2016 | August 12, 2016 | 54,442 | 24,262 | 911 | 79,615 | 0.7550 | ||||||||||||||||
March 31, 2016 | May 13, 2016 | 48,238 | 19,816 | 830 | 68,884 | 0.7050 |
(1) | The distribution announced on April 17, 2017 for the first quarter of 2017 will be paid on May 15, 2017 to unitholders of record at the close of business on April 28, 2017. |
Three Months Ended March 31, | |||||||
2017 | 2016 | ||||||
(in thousands, except per share data) | |||||||
Basic Net Income per Class A Share | |||||||
Net income attributable to TEGP, excluding predecessor operations interest | $ | 12,029 | $ | 7,589 | |||
Basic weighted average Class A Shares outstanding | 58,075 | 47,725 | |||||
Basic net income per Class A share | $ | 0.21 | $ | 0.16 | |||
Diluted Net Income per Class A Share | |||||||
Net income attributable to TEGP, excluding predecessor operations interest | $ | 12,029 | $ | 7,589 | |||
Incremental net income attributable to TEGP including the effect of the assumed issuance of Equity Participation Shares | 8 | — | |||||
Net income attributable to TEGP including incremental net income from assumed issuance of Equity Participation Shares | $ | 12,037 | $ | 7,589 | |||
Basic weighted average Class A Shares outstanding | 58,075 | 47,725 | |||||
Equity Participation Shares equivalent shares | 90 | — | |||||
Diluted weighted average Class A Shares outstanding | 58,165 | 47,725 | |||||
Diluted net income per Class A Share | $ | 0.21 | $ | 0.16 |
Three Months Ended March 31, 2017 | Three Months Ended March 31, 2016 | ||||||||||||||||||||||
Revenue: | Total Revenue | Inter- Segment | External Revenue | Total Revenue | Inter- Segment | External Revenue | |||||||||||||||||
(in thousands) | |||||||||||||||||||||||
Crude Oil Transportation & Logistics | $ | 85,092 | $ | — | $ | 85,092 | $ | 94,654 | $ | — | $ | 94,654 | |||||||||||
Natural Gas Transportation & Logistics | 36,428 | (1,445 | ) | 34,983 | 32,668 | (1,355 | ) | 31,313 | |||||||||||||||
Processing & Logistics | 24,325 | — | 24,325 | 21,201 | — | 21,201 | |||||||||||||||||
Corporate and Other | — | — | — | — | — | — | |||||||||||||||||
Total revenue | $ | 145,845 | $ | (1,445 | ) | $ | 144,400 | $ | 148,523 | $ | (1,355 | ) | $ | 147,168 |
Three Months Ended March 31, 2017 | Three Months Ended March 31, 2016 | ||||||||||||||||||||||
Operating Income: | Total Operating Income | Inter- Segment | External Operating Income | Total Operating Income | Inter- Segment | External Operating Income | |||||||||||||||||
(in thousands) | |||||||||||||||||||||||
Crude Oil Transportation & Logistics | $ | 44,715 | $ | 1,344 | $ | 46,059 | $ | 53,961 | $ | 1,345 | $ | 55,306 | |||||||||||
Natural Gas Transportation & Logistics | 18,168 | (1,445 | ) | 16,723 | 12,345 | (1,355 | ) | 10,990 | |||||||||||||||
Processing & Logistics | 4,116 | 101 | 4,217 | 178 | 10 | 188 | |||||||||||||||||
Corporate and Other | (3,773 | ) | — | (3,773 | ) | (3,039 | ) | — | (3,039 | ) | |||||||||||||
Total Operating Income | $ | 63,226 | $ | — | $ | 63,226 | $ | 63,445 | $ | — | $ | 63,445 | |||||||||||
Reconciliation to Net Income: | |||||||||||||||||||||||
Interest expense, net | (16,017 | ) | (8,677 | ) | |||||||||||||||||||
Unrealized gain (loss) on derivative instruments | 1,885 | (8,946 | ) | ||||||||||||||||||||
Equity in earnings of unconsolidated investment | 20,738 | 709 | |||||||||||||||||||||
Other income, net | 70 | 566 | |||||||||||||||||||||
Net income before tax | $ | 69,902 | $ | 47,097 |
Three Months Ended March 31, | |||||||
Capital Expenditures: | 2017 | 2016 | |||||
(in thousands) | |||||||
Crude Oil Transportation & Logistics | $ | 10,436 | $ | 15,973 | |||
Natural Gas Transportation & Logistics | 4,655 | 2,133 | |||||
Processing & Logistics | 11,678 | 3,101 | |||||
Corporate and Other | — | — | |||||
Total capital expenditures | $ | 26,769 | $ | 21,207 |
Assets: | March 31, 2017 | December 31, 2016 | |||||
(in thousands) | |||||||
Crude Oil Transportation & Logistics | $ | 1,492,333 | $ | 1,493,866 | |||
Natural Gas Transportation & Logistics | 1,633,358 | 1,176,147 | |||||
Processing & Logistics | 418,479 | 411,999 | |||||
Corporate and Other | 529,240 | 543,468 | |||||
Total assets | $ | 4,073,410 | $ | 3,625,480 |
• | our ability to pay distributions to our Class A shareholders; |
• | our expected receipt of, and amounts of, distributions from Tallgrass Equity; |
• | TEP's ability to complete and integrate acquisitions from TD or from third parties, including its acquisition of an additional 24.99% membership interest in Rockies Express from TD that was completed on March 31, 2017 and its acquisition of a 100% membership interest in NatGas and Terminals from TD that was completed in January 2017; |
• | the demand for TEP's services, including crude oil transportation, storage and terminalling services, natural gas transportation, storage and processing services and water business services; |
• | large or multiple customer defaults, including defaults resulting from actual or potential insolvencies; |
• | our ability to successfully implement our business plan; |
• | changes in general economic conditions; |
• | competitive conditions in our industry; |
• | the effects of existing and future laws and governmental regulations; |
• | actions taken by third-party operators, processors and transporters; |
• | 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, natural gas liquids, 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, storing and terminalling crude oil, transporting, storing and processing natural gas, and transporting, gathering and disposing of water produced in connection with hydrocarbon exploration and production activities; |
• | environmental liabilities or events that are not covered by an indemnity, insurance or existing reserves; |
• | natural disasters, weather-related delays, casualty losses and other matters beyond our control; |
• | interest rates; |
• | labor relations; |
• | changes in tax status; |
• | 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 as well as all of the TEP 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 May 3, 2017. |
• | 20,000,000 TEP common units, representing an approximate 27.30% limited partner interest in TEP at May 3, 2017. |
• | Crude Oil Transportation & Logistics—the ownership and operation of a FERC-regulated crude oil pipeline system and crude oil storage and terminalling facilities; |
• | 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 March 31, | |||||
2017 | 2016 | ||||
Crude Oil Transportation & Logistics Segment: | |||||
Crude oil transportation average contracted capacity (Bbls/d) (1) | 298,580 | 290,580 | |||
Crude oil transportation average throughput (Bbls/d) | 261,904 | 291,274 | |||
Natural Gas Transportation & Logistics Segment: | |||||
Gas transportation average firm contracted volumes (MMcf/d) (2) | 1,609 | 1,646 | |||
Processing & Logistics Segment: | |||||
Natural gas processing inlet volumes (MMcf/d) | 103 | 98 | |||
Freshwater approximate average volumes (Bbls/d) | 64,754 | 2,802 | |||
Produced water gathering and disposal approximate average volumes (Bbls/d) | 9,760 | 10,726 |
(1) | We are required to make no less than 10% of the contractible capacity of the Pony Express System available for non-contract, or "walk-up", shippers. |
(2) | Volumes transported under firm fee contracts, excluding Rockies Express. |
Three Months Ended March 31, | |||||||
2017 | 2016 | ||||||
(in thousands, except operating data) | |||||||
Revenues: | |||||||
Crude oil transportation services | $ | 84,331 | $ | 94,572 | |||
Natural gas transportation services | 31,685 | 29,280 | |||||
Sales of natural gas, NGLs, and crude oil | 15,381 | 13,926 | |||||
Processing and other revenues | 13,003 | 9,390 | |||||
Total Revenues | 144,400 | 147,168 | |||||
Operating Costs and Expenses: | |||||||
Cost of sales (exclusive of depreciation and amortization shown below) | 12,370 | 13,568 | |||||
Cost of transportation services (exclusive of depreciation and amortization shown below) | 13,503 | 13,529 | |||||
Operations and maintenance | 12,903 | 12,958 | |||||
Depreciation and amortization | 21,403 | 22,007 | |||||
General and administrative | 14,217 | 14,011 | |||||
Taxes, other than income taxes | 8,226 | 7,650 | |||||
Gain on disposal of assets | (1,448 | ) | — | ||||
Total Operating Costs and Expenses | 81,174 | 83,723 | |||||
Operating Income | 63,226 | 63,445 | |||||
Other Income (Expense): | |||||||
Interest expense, net | (16,017 | ) | (8,677 | ) | |||
Unrealized gain (loss) on derivative instrument | 1,885 | (8,946 | ) | ||||
Equity in earnings of unconsolidated investments | 20,738 | 709 | |||||
Other income, net | 70 | 566 | |||||
Total Other Income (Expense) | 6,676 | (16,348 | ) | ||||
Net income before tax | 69,902 | 47,097 | |||||
Deferred income tax expense | (2,664 | ) | (2,791 | ) | |||
Net income | 67,238 | 44,306 | |||||
Net income attributable to noncontrolling interests | (55,209 | ) | (33,032 | ) | |||
Net income attributable to TEGP | $ | 12,029 | $ | 11,274 |
Segment Financial Data - Crude Oil Transportation & Logistics (1) | Three Months Ended March 31, | ||||||
2017 | 2016 | ||||||
(in thousands) | |||||||
Revenues: | |||||||
Crude oil transportation services | $ | 84,331 | $ | 94,572 | |||
Sales of natural gas, NGLs, and crude oil | 663 | — | |||||
Processing and other revenues | 98 | 82 | |||||
Total revenues | 85,092 | 94,654 | |||||
Operating costs and expenses: | |||||||
Cost of transportation services | 11,193 | 11,868 | |||||
Operations and maintenance | 3,750 | 4,312 | |||||
Depreciation and amortization | 13,407 | 12,954 | |||||
General and administrative | 5,529 | 5,508 | |||||
Taxes, other than income taxes | 6,498 | 6,051 | |||||
Total operating costs and expenses | 40,377 | 40,693 | |||||
Operating income | $ | 44,715 | $ | 53,961 |
(1) | Segment results as presented represent total revenue and operating income, including intersegment activity. For reconciliations to the consolidated financial data, see Note 15 – Reportable Segments to the accompanying condensed consolidated financial statements. |
Segment Financial Data - Natural Gas Transportation & Logistics (1) | Three Months Ended March 31, | ||||||
2017 | 2016 | ||||||
(in thousands) | |||||||
Revenues: | |||||||
Natural gas transportation services | $ | 33,130 | $ | 30,635 | |||
Sales of natural gas, NGLs, and crude oil | 1,651 | 348 | |||||
Processing and other revenues | 1,647 | 1,685 | |||||
Total revenues | 36,428 | 32,668 | |||||
Operating costs and expenses: | |||||||
Cost of sales | 1,070 | 1,146 | |||||
Cost of transportation services | 760 | 2,455 | |||||
Operations and maintenance | 6,478 | 5,880 | |||||
Depreciation and amortization | 4,783 | 5,878 | |||||
General and administrative | 3,794 | 3,788 | |||||
Taxes, other than income taxes | 1,375 | 1,176 | |||||
Total operating costs and expenses | 18,260 | 20,323 | |||||
Operating income | $ | 18,168 | $ | 12,345 |
(1) | Segment results as presented represent total revenue and operating income, including intersegment activity. For reconciliations to the consolidated financial data, see Note 15 – Reportable Segments to the accompanying condensed consolidated financial statements. |
Segment Financial Data - Processing & Logistics (1) | Three Months Ended March 31, | ||||||
2017 | 2016 | ||||||
(in thousands) | |||||||
Revenues: | |||||||
Sales of natural gas, NGLs, and crude oil | $ | 13,067 | $ | 13,578 | |||
Processing and other revenues | 11,258 | 7,623 | |||||
Total revenues | 24,325 | 21,201 | |||||
Operating costs and expenses: | |||||||
Cost of sales | 11,401 | 12,432 | |||||
Cost of transportation services | 2,894 | 551 | |||||
Operations and maintenance | 2,675 | 2,766 | |||||
Depreciation and amortization | 3,213 | 3,175 | |||||
General and administrative | 1,121 | 1,676 | |||||
Taxes, other than income taxes | 353 | 423 | |||||
Gain on disposal of assets | (1,448 | ) | — | ||||
Total operating costs and expenses | 20,209 | 21,023 | |||||
Operating income | $ | 4,116 | $ | 178 |
(1) | Segment results as presented represent total revenue and operating income, including intersegment activity. For reconciliations to the consolidated financial data, see Note 15 – Reportable Segments to the accompanying condensed consolidated financial statements. |
• | cash generated from our operations; |
• | borrowing capacity available under TEP's revolving credit facility; and |
• | future issuances of additional partnership units and/or debt securities. |
March 31, 2017 | December 31, 2016 | ||||||
(in thousands) | |||||||
Cash on hand | $ | 2,053 | $ | 2,459 | |||
Total capacity under the TEP revolving credit facility | 1,750,000 | 1,750,000 | |||||
Less: Outstanding borrowings under the TEP revolving credit facility | (1,567,000 | ) | (1,015,000 | ) | |||
Available capacity under the TEP revolving credit facility | 183,000 | 735,000 | |||||
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 | $ | 187,053 | $ | 739,459 |
• | an increase in deferred revenue of $16.3 million primarily from deficiency payments collected by Pony Express; |
• | a decrease in derivative assets at fair value of $10.7 million as TEP exercised the remainder of the call option granted by TD; and |
• | an increase in accrued taxes of $4.9 million due to higher estimated property taxes for 2017 at Pony Express. |
Three Months Ended March 31, | |||||||
2017 | 2016 | ||||||
(in thousands) | |||||||
Net cash provided by (used in): | |||||||
Operating activities | $ | 102,166 | $ | 91,695 | |||
Investing activities | $ | (562,042 | ) | $ | (70,363 | ) | |
Financing activities | $ | 459,470 | $ | (19,767 | ) |
• | cash outflows of $400.0 million for the acquisition of an additional 24.99% membership interest in Rockies Express on March 31, 2017; |
• | cash outflows of $140.0 million for the acquisition of Terminals and NatGas on January 1, 2017; and |
• | capital expenditures of $26.8 million, primarily due to spending on an additional freshwater connection at Water Solutions and remediation digs on the Pony Express System as discussed in Note 14 – Legal and Environmental Matters. |
• | cash outflows of $49.1 million for a portion of the acquisition of an additional 31.3% membership interest in Pony Express on January 1, 2016, the remainder of which is classified as a financing activity as discussed below; and |
• | capital expenditures of $21.2 million, primarily due to post in-service spending on Pony Express System projects. |
• | net borrowings under the TEP revolving credit facility of $552.0 million; and |
• | TEP's issuance of 2,087,647 common units under its Equity Distribution Agreements for net cash proceeds of $99.4 million. |
• | $72.4 million for TEP's exercise of the remainder of the call option granted by TD covering 1,703,094 common units; |
• | distributions to noncontrolling interests of $71.4 million, consisting of distributions to TEP unitholders of $42.5 million, Tallgrass Equity distributions to the Exchange Right Holders of $27.5 million, and distributions to Pony Express and Water Solutions noncontrolling interests of $1.4 million; |
• | $35.3 million for TEP's 736,262 common units repurchased from TD; and |
• | distributions to Class A shareholders of $16.1 million. |
• | cash outflows of $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 $50.9 million, which consisted of distributions to TEP unitholders of $30.2 million, Tallgrass Equity distributions to the Exchange Right Holders of $18.9 million, and distributions to Pony Express and Water Solutions noncontrolling interests of $1.8 million; and |
• | distributions to TEGP Class A shareholders of $8.3 million. |
• | net borrowings under the TEP revolving credit facility of $447.0 million; |
• | the issuance of 337,311 common units under the Equity Distribution Agreement for net cash proceeds of $12.6 million; and |
• | contributions from noncontrolling interests of $7.2 million, which primarily consisted of contributions from TD to Pony Express. |
• | 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 we expect will 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). |
Three Months Ended March 31, | |||||||
2017 | 2016 | ||||||
(in thousands) | |||||||
Maintenance capital expenditures | $ | 63 | $ | 2,168 | |||
Expansion capital expenditures | 22,420 | 8,392 | |||||
Total capital expenditures incurred | $ | 22,483 | $ | 10,560 |
Fair Value | Effect of 10% Price Increase | Effect of 10% Price Decrease | |||||||||
(in thousands) | |||||||||||
Crude oil derivative contracts (1) | $ | 223 | $ | (638 | ) | $ | 638 | ||||
Natural gas derivative contracts (2) | $ | 81 | $ | 93 | $ | (93 | ) |
(1) | Represents the sale of 125,000 barrels of crude oil by our Crude Oil Transportation & Logistics segment which will settle throughout 2017. |
(2) | Represents long natural gas swaps outstanding with a notional volume of approximately 0.3 Bcf covering a portion of the natural gas that is expected to be purchased by our Processing & Logistics segment throughout 2017. |
Exhibit No. | Description | |
10.1 | Purchase and Sale Agreement, dated as of January 1, 2017, by and among Tallgrass Energy Partners, LP, Tallgrass Development, LP and Tallgrass Operations, LLC (incorporated by reference to Exhibit 10.1 to Tallgrass Energy Partner, LP’s Current Report on Form 8-K filed on January 3, 2017). | |
10.2 | Purchase and Sale Agreement, dated March 31, 2017, by and among Tallgrass Energy Partners, LP, Rockies Express Holdings, LLC and Tallgrass Development, LP (incorporated by reference to Exhibit 10.1 to Tallgrass Energy Partners, LP’s Current Report on Form 8-K filed on April 3, 2017). | |
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: | May 3, 2017 | By: | /s/ Gary J. Brauchle | ||||
Name: | Gary J. Brauchle | ||||||
Title: | Executive Vice President and Chief Financial Officer | ||||||
(Duly Authorized Officer and Principal 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 |
3 Months Ended | |
---|---|---|
Mar. 31, 2017 |
May 03, 2017 |
|
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 | Large Accelerated Filer | |
Document Type | 10-Q | |
Document Period End Date | Mar. 31, 2017 | |
Document Fiscal Year Focus | 2017 | |
Document Fiscal Period Focus (Q1,Q2,Q3,FY) | Q1 | |
Trading Symbol | TEGP | |
Amendment Flag | false | |
Capital Unit, Class A | ||
Document Information [Line Items] | ||
Entity Common Stock, Shares Outstanding | 58,075,000 | |
Capital Unit, Class B | ||
Document Information [Line Items] | ||
Entity Common Stock, Shares Outstanding | 99,154,440 |
CONDENSED CONSOLIDATED BALANCE SHEETS CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - shares |
Mar. 31, 2017 |
Dec. 31, 2016 |
---|---|---|
Common Class A | ||
Limited Partners' Capital Account, Units Issued | 58,075,000 | 58,075,000 |
Shares Outstanding | 58,075,000 | 58,075,000 |
Common Class B | ||
Limited Partners' Capital Account, Units Issued | 99,154,440 | 99,154,440 |
Shares Outstanding | 99,154,440 | 99,154,440 |
CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (UNAUDITED) - USD ($) $ in Thousands |
Total |
Pony Express Pipeline |
Noncontrolling Interest |
Noncontrolling Interest
Tallgrass Energy Partners
|
Noncontrolling Interest
Terminals and NatGas
|
Noncontrolling Interest
Rockies Express Pipeline LLC
|
Noncontrolling Interest
Pony Express Pipeline
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest |
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Tallgrass Energy Partners
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Terminals and NatGas
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Rockies Express Pipeline LLC
|
Total Partner Equity Including Portion Attributable to Noncontrolling Interest
Pony Express Pipeline
|
Common Class A |
Common Class A
Tallgrass Energy Partners
|
Common Class A
Terminals and NatGas
|
Common Class A
Rockies Express Pipeline LLC
|
Common Class A
Pony Express Pipeline
|
Common Class B |
Common Class B
Tallgrass Energy Partners
|
Common Class B
Terminals and NatGas
|
Common Class B
Rockies Express Pipeline LLC
|
Common Class B
Pony Express Pipeline
|
Predecessor Equity |
Predecessor Equity
Tallgrass Energy Partners
|
Predecessor Equity
Terminals and NatGas
|
Predecessor Equity
Rockies Express Pipeline LLC
|
Predecessor Equity
Pony Express Pipeline
|
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | $ 1,599,188 | $ 2,093,062 | $ 422,310 | $ 0 | $ 71,564 | ||||||||||||||||||||||
Increase (Decrease) in Partners' Capital [Roll Forward] | |||||||||||||||||||||||||||
Net income | $ 44,306 | 33,032 | 44,306 | 7,589 | 0 | 3,685 | |||||||||||||||||||||
Issuance of TEP units to public, net of offering costs | $ 11,490 | $ 12,636 | $ 1,146 | $ 0 | $ 0 | ||||||||||||||||||||||
TEGP distributions to Class A shareholders | 8,256 | 0 | 8,256 | (8,256) | 0 | 0 | |||||||||||||||||||||
Noncash compensation expense | 1,869 | 2,164 | 295 | 0 | 0 | ||||||||||||||||||||||
Payments for Repurchase of Common Stock | 0 | ||||||||||||||||||||||||||
Acquisitions | $ (173,422) | $ (429,039) | $ (255,617) | $ 0 | $ 0 | ||||||||||||||||||||||
Contributions from noncontrolling interest | 7,152 | 7,152 | 0 | 0 | 0 | ||||||||||||||||||||||
Distributions to noncontrolling interest | 50,919 | $ 425,882 | 50,919 | 50,919 | 0 | 0 | 0 | ||||||||||||||||||||
Distributions to Predecessor Entities, net | 0 | (693) | 0 | 0 | (693) | ||||||||||||||||||||||
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | 1,428,390 | 1,670,413 | 167,467 | 0 | 74,556 | ||||||||||||||||||||||
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | 1,929,414 | 1,596,152 | 1,929,414 | 250,967 | 0 | 82,295 | |||||||||||||||||||||
Net income | 67,238 | 55,209 | 67,238 | 12,029 | 0 | 0 | |||||||||||||||||||||
Issuance of TEP units to public, net of offering costs | 99,400 | 89,353 | 99,373 | 10,020 | 0 | 0 | |||||||||||||||||||||
TEGP distributions to Class A shareholders | 16,116 | 0 | 16,116 | (16,116) | 0 | 0 | |||||||||||||||||||||
Noncash compensation expense | 1,882 | 2,244 | 362 | 0 | 0 | ||||||||||||||||||||||
Issuance of common units under TEP LTIP plan | $ 360 | $ (400) | $ (40) | $ 0 | $ 0 | ||||||||||||||||||||||
Partial exercise of call option | (72,890) | (84,942) | (12,052) | 0 | 0 | ||||||||||||||||||||||
Payments for Repurchase of Common Stock | (35,335) | 31,717 | 35,335 | 3,618 | 0 | 0 | |||||||||||||||||||||
Acquisitions | $ (36,391) | $ 40,159 | $ (140,000) | $ 63,681 | $ (21,314) | $ 23,522 | $ 0 | $ 0 | $ (82,295) | $ 0 | |||||||||||||||||
Contributions from TD | 1,451 | 2,301 | 850 | 0 | 0 | ||||||||||||||||||||||
Contributions from noncontrolling interest | 700 | 710 | 0 | 0 | 0 | ||||||||||||||||||||||
Distributions to noncontrolling interest | 71,426 | $ 0 | (71,400) | 71,426 | 0 | 0 | 0 | ||||||||||||||||||||
Partners' Capital, Including Portion Attributable to Noncontrolling Interest | $ 1,816,742 | $ 1,572,132 | $ 1,816,742 | $ 244,610 | $ 0 | $ 0 |
Description of Business |
3 Months Ended | ||||||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2017 | |||||||||||||||||||||
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. "We," "us," "our" and similar terms refer to TEGP together with its consolidated subsidiaries. TEGP's sole cash-generating asset as of March 31, 2017 is an approximate 36.94% controlling membership 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, that were historically owned by entities controlled by Tallgrass Equity, including Tallgrass Development, LP ("TD"):
TEP is a publicly traded, growth-oriented limited partnership formed to own, operate, acquire and develop midstream energy assets in North America. TEP's operations are 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:
Crude Oil Transportation & Logistics. 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 FERC-regulated crude oil pipeline commencing in Guernsey, Wyoming and terminating in Cushing, Oklahoma, which includes a lateral in Northeast Colorado commencing in Weld County, Colorado, and interconnecting with the pipeline just east of Sterling, Colorado (the "Pony Express System"). TEP also provides crude oil storage and terminalling services through TEP's 100% membership interest in Tallgrass Terminals, LLC ("Terminals") acquired effective January 1, 2017, which owns and operates crude oil terminals near Sterling, Colorado (the "Sterling Terminal") and in Weld County, Colorado (the "Buckingham Terminal"). Terminals also owns a 20% membership interest in Deeprock Development, LLC ("Deeprock Development"), which owns a crude oil terminal in Cushing, Oklahoma (the "Cushing Terminal"). Natural Gas Transportation & Logistics. TEP provides natural gas transportation and storage services for customers in the Rocky Mountain, Midwest and Appalachian regions of the United States through: (1) its 49.99% membership interest in Rockies Express Pipeline LLC ("Rockies Express"), which owns the Rockies Express Pipeline, a FERC-regulated natural gas pipeline system extending from Opal, Wyoming and Meeker, Colorado to Clarington, Ohio (the "Rockies Express Pipeline"), which includes the additional 24.99% membership interest acquired from TD effective March 31, 2017 as discussed in Note 4 – Acquisitions, and TEP's 100% membership interest in Tallgrass NatGas Operator, LLC ("NatGas") acquired effective January 1, 2017, which operates the Rockies Express Pipeline, (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"). Processing & Logistics. 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 and Wyoming. TEP performs water business services, including freshwater transportation and produced water gathering and disposal, in Colorado and Texas through BNN Water Solutions, LLC ("Water Solutions"). The term "Terminals Predecessor" refers to Terminals and the term "NatGas Predecessor" refers to NatGas prior to their acquisition by TEP on January 1, 2017. Terminals Predecessor and NatGas Predecessor are collectively referred to as the Predecessor Entities, as further discussed in Note 2 – Summary of Significant Accounting Policies. Financial results for all prior periods have been recast to reflect the operations of the Predecessor Entities. Predecessor Equity as presented in the condensed consolidated financial statements represents the capital account activity of Terminals Predecessor and NatGas Predecessor prior to January 1, 2017. For additional information regarding these acquisitions, see Note 4 – Acquisitions. |
Summary of Significant Accounting Policies |
3 Months Ended | ||||||||||||||||
---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
Mar. 31, 2017 | |||||||||||||||||
Accounting Policies [Abstract] | |||||||||||||||||
Summary of Significant Accounting Policies | Basis of Presentation These condensed consolidated financial statements and related notes for the three months ended March 31, 2017 and 2016 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 months ended March 31, 2017 and 2016 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 months ended March 31, 2017 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2017. 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, 2016 ("2016 Form 10-K") filed with the United States Securities and Exchange Commission (the "SEC") on February 15, 2017. The condensed consolidated financial statements include the accounts of TEGP and its subsidiaries and controlled affiliates. Significant intra-entity items have been eliminated in the presentation. Net income or loss from consolidated subsidiaries that are not wholly-owned by TEGP is attributed to TEGP and noncontrolling interests in accordance with the respective ownership interests. As further discussed in Note 4 – Acquisitions, TEP closed the acquisition of Terminals and NatGas on January 1, 2017. As the acquisitions of Terminals and NatGas are considered transactions between entities under common control, and a change in reporting entity, the financial information presented has been recast to include Terminals and NatGas for all periods presented. Net equity distributions of the Predecessor Entities included in the condensed consolidated financial statements represent transfers of cash as a result of TD's centralized cash management system prior to January 1, 2017 for Terminals and NatGas, under which cash balances were swept daily and recorded as loans from the subsidiaries of TD. These loans were then periodically recorded as equity distributions. The accompanying condensed consolidated financial statements of TEGP include historical cost-basis accounts of the assets and liabilities of the Predecessor Entities for the periods prior to January 1, 2017, the date TEP acquired Terminals and NatGas from TD, and include charges from TD for direct costs and allocations of indirect corporate overhead. Management believes that the allocation methods are reasonable, and that the allocations are representative of costs that would have been incurred on a stand-alone basis. TEGP, TEP, and the Predecessor Entities are all considered "entities under common control" as defined under GAAP and, as such, the transfers between the entities of the assets and liabilities have been recorded by TEGP at historical cost. 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. TEP is also considered to be a VIE under the applicable authoritative guidance. Based on a qualitative analysis, we have determined that TEP GP is the primary beneficiary of TEP and we continue to consolidate TEP accordingly. 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 Pronouncement Recently Adopted 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 adopted the guidance in ASU 2016-09 effective January 1, 2017 and made a policy election to account for forfeitures when they occur. The adoption of ASU 2016-09 did not have a material impact on our consolidated financial statements. Accounting Pronouncements Not Yet Adopted 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 2015 and 2016, the FASB has issued a series of subsequent updates to the revenue recognition guidance in Topic 606, including ASU No. 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date, 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, ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients, and ASU No. 2016-20, Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers. The amendments in ASU 2014-09, ASU 2016-08, ASU 2016-10, ASU 2016-12, and ASU 2016-20 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 our pending adoption of the revised guidance. The status of our implementation is as follows:
Through the contract review process currently underway, management has identified several areas of potential impact, including the accounting for non-cash consideration, particularly in our Crude Oil Transportation & Logistics and Processing & Logistics segments, and the timing of revenue recognition with respect to deficiency payments received in our Crude Oil Transportation & Logistics segment. We will continue to conduct our contract review process throughout 2017 and, as a result, additional areas of impact may be identified. We are in the process of quantifying the impact of adoption but cannot reasonably estimate such amount at this time. We expect to adopt the new standard on January 1, 2018 using the modified retrospective approach. This approach allows us to apply the new standard to (i) all new contracts entered into after January 1, 2018 and (ii) all existing contracts for which all (or substantially all) of the revenue has not been recognized under legacy revenue guidance as of January 1, 2018 through a cumulative adjustment to equity. Consolidated revenues presented in our comparative financial statements for periods prior to January 1, 2018 would not be revised. 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. 2017-01, "Business Combinations (Topic 805): Clarifying the Definition of a Business" In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business. ASU 2017-01 clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses by providing a screen to determine when an integrated set of assets and activities is not a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business. This screen reduces the number of transactions that need to be further evaluated. The ASU also narrows the definition of the term "output" so that the term is consistent with how outputs are described under the revenue recognition guidance in Topic 606. The amendments in ASU 2017-01 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2017. Early adoption is permitted in certain circumstances. We are currently evaluating the impact of ASU 2017-01, but do not anticipate a material impact on our consolidated financial statements. ASU No. 2017-04, "Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment" In January 2017, the FASB issued ASU No. 2017-04, which simplifies the subsequent measurement of goodwill by eliminating "Step 2" from the goodwill impairment test, which involved calculating the implied fair value of goodwill by determining the fair value at the impairment testing date of a reporting unit's assets and liabilities. Instead, under the simplified test approach, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The amendments in ASU 2017-04 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. We are currently evaluating the impact of ASU 2017-04. |
Variable Interest Entity Variable Interest Entity |
3 Months Ended |
---|---|
Mar. 31, 2017 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Variable Interest Entity | 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 our controlling interest in Tallgrass Equity and have no contractual commitments or obligations to provide additional financial support to Tallgrass Equity. Other than TEGP's deferred tax asset of approximately $518.8 million and $521.5 million at March 31, 2017 and December 31, 2016, respectively, the assets and liabilities included in our condensed consolidated balance sheets at March 31, 2017 and December 31, 2016 represent the consolidated assets and liabilities of Tallgrass Equity, including the assets and liabilities of TEP. |
Acquisitions |
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Business Combinations [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Acquisitions | TEP Acquisition of an Additional 24.99% Membership Interest in Rockies Express On March 31, 2017, TEP, TD, and Rockies Express Holdings, LLC, entered into a definitive Purchase and Sale Agreement, pursuant to which TEP acquired an additional 24.99% membership interest in Rockies Express from TD in exchange for cash consideration of $400 million. Together with the 25% membership interest in Rockies Express that TEP acquired from a unit of Sempra U.S. Gas and Power on May 6, 2016, this transaction increases TEP’s aggregate membership interest in Rockies Express to 49.99%. The transfer of the Rockies Express membership interest between TD and TEP is considered a transaction between entities under common control, but does not represent a change in reporting entity. TEP's investment in Rockies Express is recorded under the equity method of accounting and is reported as "Unconsolidated investments" on our condensed consolidated balance sheets. As a result of the common control nature of the transaction, the 24.99% membership interest in Rockies Express was transferred to TEP at TD's historical carrying amount, including the remaining unamortized basis difference driven by the difference between the fair value of the investment and the book value of the underlying assets and liabilities on November 13, 2012, the date of acquisition by TD. For additional information, see Note 8 – Investments in Unconsolidated Affiliates. As of March 31, 2017, the negative basis difference carried over from TD was approximately $386.8 million. 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 associated with the recently acquired 24.99% membership interest in Rockies Express at March 31, 2017 was allocated as follows:
TEP Acquisition of Tallgrass Terminals, LLC and Tallgrass NatGas Operator, LLC Effective January 1, 2017, TEP acquired 100% of the issued and outstanding membership interests in Terminals and 100% of the issued and outstanding membership interests in NatGas from TD for total cash consideration of $140 million. These acquisitions are considered transactions between entities under common control, and a change in reporting entity. Terminals owns several fully operational assets providing storage capacity and additional injection points for the Pony Express System, including the Sterling Terminal near Sterling, Colorado, the Buckingham Terminal in northeast Colorado, and a 20% interest in the Deeprock Development Terminal in Cushing, Oklahoma. The 20% interest in Deeprock Development is recorded under the equity method of accounting and reported as "Unconsolidated investments" on our condensed consolidated balance sheets. Terminals also owns acreage in Cushing, Oklahoma and Guernsey, Wyoming, which is under development to provide additional storage capacity, and other potential opportunities. NatGas is the operator of the Rockies Express Pipeline and receives a fee from Rockies Express as compensation for its services. Historical Financial Information The results of our acquisitions of Terminals and NatGas are included in the condensed consolidated balance sheets as of March 31, 2017 and December 31, 2016. The following table presents our previously reported December 31, 2016 condensed consolidated balance sheet, adjusted for the acquisitions of Terminals and NatGas:
The results of our acquisitions of Terminals and NatGas are included in the condensed consolidated statements of income for the three months ended March 31, 2017 and 2016. The following tables present the previously reported condensed consolidated statements of income for the three months ended March 31, 2016, adjusted for the acquisitions of Terminals and NatGas:
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Related Party Transactions |
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Related Party Transactions [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Related Party Transactions | As a result of our relationship with TD and its affiliates, we have entered into a number of related party transactions. The following disclosure includes those related party disclosures which are not otherwise disclosed in these notes to our condensed consolidated financial statements. We have no employees. In connection with the closing of the TEP initial public offering on May 17, 2013, TEP and its general partner entered into an Omnibus Agreement with TD and certain of its affiliates, including Tallgrass Operations, LLC (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 our initial public offering on May 12, 2015 (the "TEGP IPO"), TEGP entered into an Omnibus Agreement (the "TEGP Omnibus Agreement") with TEGP Management, LLC, Tallgrass Equity and Tallgrass Energy Holdings, LLC (which is 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 first quarter of 2017. This amount will be periodically reviewed and adjusted as necessary to continue to reflect reasonable allocation of costs to TEGP. Totals of transactions with affiliated companies, excluding transactions disclosed elsewhere in these notes, 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:
Gas imbalances with affiliated shippers are as follows:
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Inventory |
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory | The components of inventory at March 31, 2017 and December 31, 2016 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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Investments in Unconsolidated Affiliates (Notes) |
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Equity Method Investments and Joint Ventures [Abstract] | |||||||||||||||||||||||||||||
Equity Method Investments and Joint Ventures Disclosure | Rockies Express Our investment in Rockies Express is recorded under the equity method of accounting and is reported as "Unconsolidated investments" on our condensed consolidated balance sheets. During the three months ended March 31, 2017, we recognized equity in earnings associated with our previously acquired 25% membership interest in Rockies Express of $20.0 million, inclusive of the amortization of the negative basis difference, and received distributions from and made contributions to Rockies Express of $30.1 million and $6.7 million, respectively. As discussed in Note 4 – Acquisitions, we acquired an additional 24.99% membership interest in Rockies Express from TD on March 31, 2017. Summarized financial information for Rockies Express is as follows:
Deeprock Development See Note 4 – Acquisitions for additional information regarding our recently acquired 20% membership interest in Deeprock Development. |
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 months ended March 31, 2017 and 2016:
Call Option Derivative As part of TEP's acquisition of an additional 31.3% membership interest in Pony Express effective January 1, 2016, TD granted TEP an 18 month call option at an exercise price of $42.50 per TEP common unit covering the 6,518,000 TEP common units issued to TD as a portion of the consideration. In July 2016 and October 2016, TEP partially exercised the call option covering 3,563,146 and 1,251,760 common units, respectively, for cash payments of $151.4 million and $53.2 million, respectively. On February 1, 2017, TEP exercised the remainder of the call option covering an additional 1,703,094 common units for a cash payment of $72.4 million. These common units were deemed canceled upon the exercise of the call option and as of the applicable exercise date were no longer issued and outstanding. 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 was TD. 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. The maximum potential exposure to credit losses on our crude oil and natural gas derivative contracts at March 31, 2017 was:
As of March 31, 2017 and December 31, 2016, 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 our commodity derivative contracts nor did we have any margin deposits with counterparties associated with our commodity derivative contracts. 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 commodity 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. The call option granted by TD was 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 was classified within Level 2 of the fair value hierarchy as the value was based on significant observable inputs. 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 following table summarizes the fair value measurements of our derivative contracts as of March 31, 2017 and December 31, 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 | Long-term debt consisted of the following at March 31, 2017 and December 31, 2016:
TEP Senior Unsecured Notes On September 1, 2016, TEP and Tallgrass Energy Finance Corp. (the "Co-Issuer" and together with TEP, the "Issuers"), the Guarantors named therein and U.S. Bank, National Association, as trustee, entered into an Indenture dated September 1, 2016 (the "Indenture"), pursuant to which the Issuers issued $400 million in aggregate principal amount of 5.50% senior notes due 2024 (the "2024 Notes"). The Indenture contains covenants that, among other things, limit TEP's ability and the ability of its restricted subsidiaries to: (i) incur, assume or guarantee additional indebtedness or issue preferred units; (ii) create liens to secure indebtedness; (iii) pay distributions on equity interests, repurchase equity securities or redeem subordinated securities; (iv) make investments; (v) restrict distributions, loans or other asset transfers from TEP's restricted subsidiaries; (vi) consolidate with or merge with or into, or sell substantially all of TEP's properties to, another person; (vii) sell or otherwise dispose of assets, including equity interests in subsidiaries; and (viii) enter into transactions with affiliates. As of March 31, 2017, TEP was in compliance with the covenants required under the 2024 Notes. Tallgrass Equity Revolving Credit Facility The following table sets forth the available borrowing capacity under the Tallgrass Equity revolving credit facility as of March 31, 2017 and December 31, 2016:
In connection with the TEGP IPO, 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 March 31, 2017, 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 March 31, 2017, the weighted average interest rate on outstanding borrowings under the Tallgrass Equity revolving credit facility was 3.48%. During the three months ended March 31, 2017, Tallgrass Equity's weighted average effective interest rate, including the interest on outstanding borrowings, commitment fees, and amortization of deferred financing costs, was 3.61%. TEP Revolving Credit Facility The following table sets forth the available borrowing capacity under the TEP revolving credit facility as of March 31, 2017 and December 31, 2016:
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 its 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 March 31, 2017, TEP was 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 March 31, 2017, the weighted average interest rate on outstanding borrowings under the TEP revolving credit facility was 2.95%. During the three months ended March 31, 2017, 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 3.12%. 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 March 31, 2017 and December 31, 2016, but for which fair value is disclosed:
The long-term debt borrowed under the revolving credit facilities is carried at amortized cost. As of March 31, 2017 and December 31, 2016, the fair value of borrowings under the revolving credit facilities approximates the carrying amount of the borrowings using a discounted cash flow analysis. The 2024 Notes are carried at amortized cost, net of deferred financing costs. The estimated fair value of the 2024 Notes is based upon quoted market prices adjusted for illiquid markets. We are not aware of any factors that would significantly affect the estimated fair value subsequent to March 31, 2017. |
Partnership Equity and Distributions |
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Equity [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Partnership Equity and Distributions | TEGP Partnership Agreement and Distributions to Holders of Class A Shares The following table details the distributions for the periods indicated:
Subsidiary Distributions TEP Distributions. The following table shows the distributions for the periods indicated:
Repurchase of TEP Common Units Owned by TD Following an offer received from TD with respect to TEP common units owned by TD not subject to the call option, TEP repurchased 736,262 TEP common units from TD at an aggregate price of approximately $35.3 million, or $47.99 per common unit, on February 1, 2017, which was approved by the conflicts committee of the board of directors of TEP's general partner. These common units were deemed canceled upon our purchase and as of such transaction date were no longer issued and outstanding. TEP Equity Distribution Agreements As of March 31, 2017, TEP had active equity distribution agreements pursuant to which it may sell from time to time through a group of managers, as its sales agents, TEP common units representing limited partner interests having an aggregate offering price of up to $100.2 million and $657.5 million. Net cash proceeds from any sale of the TEP common units may be used for general partnership purposes, which includes, among other things, TEP's exercise of the call option with respect to the 6,518,000 common units issued 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 three months ended March 31, 2017, TEP issued and sold 2,087,647 common units with a weighted average sales price of $48.23 per unit under its equity distribution agreements for net cash proceeds of approximately $99.4 million (net of approximately $1.3 million in commissions and professional service expenses). During the period from April 1, 2017 to May 3, 2017, TEP issued and sold an additional 253,414 common units with a weighted average sales price of $53.65 per unit under its equity distribution agreements for net cash proceeds of approximately $13.5 million (net of approximately $0.1 million in commissions and professional service expenses). TEP used the net cash proceeds for general partnership purposes as described above. Noncontrolling Interests As of March 31, 2017, noncontrolling interests in our subsidiaries consisted of a 63.06% interest in Tallgrass Equity held by the Exchange Right Holders, as defined in Note 12 – Net Income per Class A Share, the 72.29% limited partner interest in TEP held by TD and the public TEP unitholders and the 2.0% membership interest in Pony Express held by TD. During the three months ended March 31, 2017, we recognized contributions from and distributions to noncontrolling interests of $0.7 million and $71.4 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 $42.5 million, Tallgrass Equity distributions to the Exchange Right Holders of $27.5 million, and distributions to Pony Express noncontrolling interests of $1.4 million. During the three months ended March 31, 2016, we received contributions from and made distributions to noncontrolling interests of $7.2 million and $50.9 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 $30.2 million, Tallgrass Equity distributions to Exchange Right Holders of $18.9 million and distributions to Pony Express noncontrolling interests in the aggregate of $1.8 million. Other Contributions and Distributions During the three months ended March 31, 2017, TEP received contributions from TD of $2.3 million, primarily to indemnify TEP for costs associated with Trailblazer's Pipeline Integrity Management Program, as discussed in Note 14 – Legal and Environmental Matters. |
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 exchange of any Class B shares for Class A shares does not have a dilutive effect on basic net income per Class A share. However, for the three months ended March 31, 2017 and 2016, the potential issuance of TEGP Equity Participation Shares would have had a dilutive effect on basic net income per Class A share. All net income or loss from Terminals and NatGas prior to TEP's acquisition on January 1, 2017 is allocated to predecessor operations in the condensed consolidated statements of income. Historical earnings of transferred businesses for periods prior to the date of those common control transactions are solely those of the general partner, and therefore we have appropriately excluded any allocation to the TEP limited partner units when determining net income available to TEP common unitholders. Accordingly, no net income or loss from Terminals and NatGas is allocated to our Class A shareholders. We present the financial results of any transferred business prior to the transaction date in the line item "Predecessor operations interest in net income" in the table below. The following table illustrates the calculation of basic and diluted net income per Class A share for the three months ended March 31, 2017 and 2016:
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Regulatory Matters |
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Regulatory Matters [Abstract] | |
Regulatory Matters | There are no regulatory proceedings challenging the transportation rates of Pony Express, Rockies Express, Tallgrass Interstate Gas Transmission, LLC ("TIGT") or Trailblazer Pipeline Company LLC ("Trailblazer"). We have certain regulatory filings currently pending with the FERC, including the following: Rockies Express Rockies Express Zone 3 Capacity Enhancement Project – FERC Docket No. CP15-137-000 On March 31, 2015 in Docket No. CP15-137-000, Rockies Express filed with the 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 facilities increased the Rockies Express Zone 3 east-to-west mainline capacity by 0.8 Bcf/d. 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. The project was placed in-service for the 0.8 Bcf/d on January 6, 2017. 2016 Annual and Interim FERC Fuel Tracking Filings - FERC Docket Nos. RP16-702 and RP17-240 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. On December 1, 2016, Rockies Express made an interim fuel tracker filing with a proposed effective date of January 1, 2017 in Docket No. RP17-240. The FERC issued an order accepting the filing on December 29, 2016. Electric Power Charge Clarification - FERC Docket No. RP17-285 On December 21, 2016, in Docket No. RP17-285, Rockies Express proposed certain revisions to the General Terms and Conditions of its tariff to clarify that the electric power costs associated with the operation of gas coolers installed in association with the Zone 3 Capacity Enhancement Project, at both electric and gas powered stations, will be included in the Power Cost Tracker. Several shippers submitted comments on the proposal. The FERC issued an order on January 19, 2017 accepting the proposed revisions permitting the recovery of electric power costs from the operation of both gas and electric powered compressor stations, subject to certain clarifications. 2017 Annual FERC Fuel Tracking Filing - FERC Docket No. RP17-401-000 On February 13, 2017, in Docket No. RP17-401-000, Rockies Express made its annual fuel and power cost tracker filing with a proposed effective date of April 1, 2017. The FERC issued an order accepting the filing, including certain requested waivers, on March 21, 2017. TIGT General Rate Case Filing - FERC Docket No. RP16-137-000, et seq. On October 30, 2015, TIGT filed a general rate case with the FERC pursuant to Section 4 of the National Gas Act ("NGA"). The rate case proposed, among other things, a general system-wide increase in the maximum tariff rates for all firm and interruptible services offered by TIGT, certain changes to the transportation rate design of its system, a fixed fuel and lost and unaccounted for ("FL&U") and power cost tracker, and certain pro forma tariff records reflecting revisions to TIGT's Tariff. On June 8, 2016, TIGT filed an Offer of Settlement (the "TIGT Rate Case Settlement") with the FERC, which resolved all issues the FERC had set for hearing. Following certification by the Administrative Law Judge and approval by the FERC, TIGT filed revised tariff records to implement the TIGT Rate Case Settlement, which the FERC subsequently approved on December 23, 2016. Per the terms of the TIGT Rate Case Settlement, TIGT is required to file a new general rate case on May 1, 2019 (provided that such rate case is not pre-empted by a pre-filing settlement). On February 3, 2017, the FERC accepted TIGT’s pro forma tariff records, subject to conditions, and directed TIGT to file the actual tariff records within 30 days. TIGT subsequently submitted a compliance filing to implement the actual tariff records and restate its tariff to be effective April 1, 2017 and also filed to cancel its existing tariff (which was ultimately superseded by the new tariff). On March 16, 2017, the FERC accepted both filings. 2017 Annual Fuel Tracker Filing - FERC Docket No. RP17-428-000 On February 27, 2017, TIGT made its annual fuel tracker filing with a proposed effective date of April 1, 2017 in Docket No. RP17-428-000. The filing incorporated the FL&U tracker and power cost tracker mechanisms agreed to in the TIGT Rate Case Settlement. The FERC accepted the filing on March 21, 2017. Trailblazer 2017 Annual Fuel Tracker Filing - FERC Docket No. RP17-549-000 On March 22, 2017, Trailblazer made its annual fuel tracker filing with a proposed effective date of May 1, 2017 in Docket No. RP15-549. This filing incorporates the revised fuel tracker and power cost tracker mechanisms agreed to in the Stipulation and Agreement, which resolved all outstanding issues related to Trailblazer fuel recoveries. The FERC accepted the filing on April 19, 2017. |
Legal and Environmental Matters |
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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, have recorded no reserve for legal claims as of March 31, 2017 or December 31, 2016. Rockies Express 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, seeking approximately $303 million in damages and other relief. 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, which operated as a stay of the Harris County state court proceeding. On January 12, 2017, Rockies Express and Ultra entered into an agreement to settle Rockies Express' approximately $303 million claim against Ultra's bankruptcy estate. In accordance with the settlement agreement, Ultra has agreed to make a cash payment to Rockies Express of $150 million no later than July 12, 2017, and Ultra has entered into a new, seven-year firm transportation agreement with Rockies Express commencing December 1, 2019, for west-to-east service of 0.2 Bcf/d at a rate of approximately $0.37, or approximately $26.8 million annually. The settlement was part of Ultra's Chapter 11 reorganization plan, which was confirmed by the U.S. Bankruptcy Court on March 14, 2017. On April 12, 2017, Ultra announced that it successfully completed its restructuring in the U.S. Bankruptcy Court and emerged from Chapter 11 bankruptcy. Michels Corporation On June 17, 2014, Michels Corporation ("Michels") filed a complaint and request for relief against Rockies Express in the Court of Common Pleas, Monroe County, Ohio, as a result of work performed by Michels to construct the Seneca Lateral Pipeline in Ohio. Michels sought unspecified damages from Rockies Express and asserted claims of breach of contract, negligent misrepresentation, unjust enrichment and quantum meruit. Michels also filed notices of Mechanic's Liens in Monroe and Noble Counties, asserting $24.2 million as the amount due. On February 2, 2017, Rockies Express and Michels agreed to resolve Michels' claims for a $10 million cash payment by Rockies Express. The cash payment was inclusive of approximately $5.9 million that Rockies Express had been withholding from Michels. Subsequently, Rockies Express and Michels entered into a definitive agreement with respect to the settlement and Rockies Express made the $10 million cash payment to Michels on February 16, 2017. 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 $3.8 million and $4.0 million at March 31, 2017 and December 31, 2016, 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 Trailblazer is currently operating at less than its current maximum allowable operating pressure ("MAOP"), public notice of which was first provided in June 2014. As a result of smart tool surveys in 2014, Trailblazer has identified approximately 25 - 35 miles of pipe that will likely need to be repaired or replaced in order for the pipeline to operate at its MAOP of 1,000 pounds per square inch across all segments of the Trailblazer Pipeline. Such repair or replacement will likely occur over a period of years, depending upon the remediation and repair plan implemented by Trailblazer. Segments of the Trailblazer Pipeline that require full replacement could cost as much as $2.7 million per mile and repair costs on sections of the pipeline that do not require full replacement are expected to be less on a per mile basis. 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 us. With respect to the approximately 25 - 35 miles of pipe that has been identified, Trailblazer completed 32 excavation digs in 2015 at an aggregate cost of approximately $1.3 million. During 2016, Trailblazer completed additional excavation digs and replaced approximately 8 miles of pipe at an aggregate cost of approximately $19.0 million. In 2017, Trailblazer intends to complete final remediation and cleanup of the pipe replacement at an estimated cost of $2.5 million. Trailblazer is currently exploring all possible cost recovery options to recover such out of pocket costs, including recovery through a general rate increase, negotiated rate agreements with its customers, or other FERC-approved recovery mechanisms. In connection with our acquisition of the Trailblazer Pipeline, TD agreed to contractually indemnify TEP for certain out of pocket costs related to repairing or remediating the Trailblazer Pipeline, to the extent that such actions were necessitated by external corrosion caused by the pipeline's disbonded Hi-Melt CTE coating. The contractual indemnity provided by TD was capped at $20 million and was subject to a $1.5 million deductible. TEP has received $20 million from TD pursuant to the contractual indemnity, as of March 31, 2017. Pony Express Pipeline Integrity In connection with certain crack tool runs on the Pony Express System completed in 2015 and 2016, Pony Express completed approximately $9.8 million of remediation for anomalies identified on the Pony Express System associated with portions of the pipeline converted from natural gas to crude oil service, and expects to complete additional remediation in 2017 on the Pony Express System of approximately $9 million. Terminals System Failures In January 2017, approximately 10,000 bbls of crude oil were released at the Sterling Terminal as the result of a defective roof drain system on a storage tank. The release was restricted to the containment area designed for such purpose and approximately 9,000 bbls were recovered. We currently expect that the total cost to remediate the release will be less than $600,000. |
Reporting Segments |
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Segment Reporting [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Reporting Segments | Our operations are located in the United States. We are organized into three reportable 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, Denver-Julesburg and Powder River Basins, 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. The Crude Oil Transportation & Logistics segment also includes our 100% membership interest in Terminals acquired effective January 1, 2017. 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 an integrated natural gas storage facility 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 100% membership interest in NatGas acquired effective January 1, 2017 and our 49.99% membership interest in Rockies Express, including the additional 24.99% membership interest acquired effective March 31, 2017. 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 facilities and the 2024 Notes, 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 |
3 Months Ended |
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Mar. 31, 2017 | |
Subsequent Events [Abstract] | |
Subsequent Events | [PLACEHOLDER] |
Summary of Significant Accounting Policies (Policies) |
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Mar. 31, 2017 | |||||||||||||||||
Accounting Policies [Abstract] | |||||||||||||||||
Basis of Presentation | Basis of Presentation These condensed consolidated financial statements and related notes for the three months ended March 31, 2017 and 2016 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 months ended March 31, 2017 and 2016 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 months ended March 31, 2017 are not necessarily indicative of the results that may be expected for the full year ending December 31, 2017. 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, 2016 ("2016 Form 10-K") filed with the United States Securities and Exchange Commission (the "SEC") on February 15, 2017. |
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Consolidation | The condensed consolidated financial statements include the accounts of TEGP and its subsidiaries and controlled affiliates. Significant intra-entity items have been eliminated in the presentation. Net income or loss from consolidated subsidiaries that are not wholly-owned by TEGP is attributed to TEGP and noncontrolling interests in accordance with the respective ownership interests. As further discussed in Note 4 – Acquisitions, TEP closed the acquisition of Terminals and NatGas on January 1, 2017. As the acquisitions of Terminals and NatGas are considered transactions between entities under common control, and a change in reporting entity, the financial information presented has been recast to include Terminals and NatGas for all periods presented. Net equity distributions of the Predecessor Entities included in the condensed consolidated financial statements represent transfers of cash as a result of TD's centralized cash management system prior to January 1, 2017 for Terminals and NatGas, under which cash balances were swept daily and recorded as loans from the subsidiaries of TD. These loans were then periodically recorded as equity distributions. The accompanying condensed consolidated financial statements of TEGP include historical cost-basis accounts of the assets and liabilities of the Predecessor Entities for the periods prior to January 1, 2017, the date TEP acquired Terminals and NatGas from TD, and include charges from TD for direct costs and allocations of indirect corporate overhead. Management believes that the allocation methods are reasonable, and that the allocations are representative of costs that would have been incurred on a stand-alone basis. TEGP, TEP, and the Predecessor Entities are all considered "entities under common control" as defined under GAAP and, as such, the transfers between the entities of the assets and liabilities have been recorded by TEGP at historical cost. 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. TEP is also considered to be a VIE under the applicable authoritative guidance. Based on a qualitative analysis, we have determined that TEP GP is the primary beneficiary of TEP and we continue to consolidate TEP accordingly. |
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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. |
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Accounting Pronouncements | Accounting Pronouncement Recently Adopted 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 adopted the guidance in ASU 2016-09 effective January 1, 2017 and made a policy election to account for forfeitures when they occur. The adoption of ASU 2016-09 did not have a material impact on our consolidated financial statements. Accounting Pronouncements Not Yet Adopted 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 2015 and 2016, the FASB has issued a series of subsequent updates to the revenue recognition guidance in Topic 606, including ASU No. 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date, 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, ASU No. 2016-12, Revenue from Contracts with Customers (Topic 606): Narrow-Scope Improvements and Practical Expedients, and ASU No. 2016-20, Technical Corrections and Improvements to Topic 606, Revenue from Contracts with Customers. The amendments in ASU 2014-09, ASU 2016-08, ASU 2016-10, ASU 2016-12, and ASU 2016-20 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 our pending adoption of the revised guidance. The status of our implementation is as follows:
Through the contract review process currently underway, management has identified several areas of potential impact, including the accounting for non-cash consideration, particularly in our Crude Oil Transportation & Logistics and Processing & Logistics segments, and the timing of revenue recognition with respect to deficiency payments received in our Crude Oil Transportation & Logistics segment. We will continue to conduct our contract review process throughout 2017 and, as a result, additional areas of impact may be identified. We are in the process of quantifying the impact of adoption but cannot reasonably estimate such amount at this time. We expect to adopt the new standard on January 1, 2018 using the modified retrospective approach. This approach allows us to apply the new standard to (i) all new contracts entered into after January 1, 2018 and (ii) all existing contracts for which all (or substantially all) of the revenue has not been recognized under legacy revenue guidance as of January 1, 2018 through a cumulative adjustment to equity. Consolidated revenues presented in our comparative financial statements for periods prior to January 1, 2018 would not be revised. 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. 2017-01, "Business Combinations (Topic 805): Clarifying the Definition of a Business" In January 2017, the FASB issued ASU No. 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business. ASU 2017-01 clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses by providing a screen to determine when an integrated set of assets and activities is not a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business. This screen reduces the number of transactions that need to be further evaluated. The ASU also narrows the definition of the term "output" so that the term is consistent with how outputs are described under the revenue recognition guidance in Topic 606. The amendments in ASU 2017-01 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2017. Early adoption is permitted in certain circumstances. We are currently evaluating the impact of ASU 2017-01, but do not anticipate a material impact on our consolidated financial statements. ASU No. 2017-04, "Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment" In January 2017, the FASB issued ASU No. 2017-04, which simplifies the subsequent measurement of goodwill by eliminating "Step 2" from the goodwill impairment test, which involved calculating the implied fair value of goodwill by determining the fair value at the impairment testing date of a reporting unit's assets and liabilities. Instead, under the simplified test approach, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit's fair value; however, the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The amendments in ASU 2017-04 are effective for public entities for annual periods and interim periods within those annual periods beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. We are currently evaluating the impact of ASU 2017-04. |
Acquisitions Equity Method Investments (Policies) |
3 Months Ended |
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Mar. 31, 2017 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Equity Method Investments, Policy | TEP's investment in Rockies Express is recorded under the equity method of accounting and is reported as "Unconsolidated investments" on our condensed consolidated balance sheets. As a result of the common control nature of the transaction, the 24.99% membership interest in Rockies Express was transferred to TEP at TD's historical carrying amount, including the remaining unamortized basis difference driven by the difference between the fair value of the investment and the book value of the underlying assets and liabilities on November 13, 2012, the date of acquisition by TD. For additional information, see Note 8 – Investments in Unconsolidated Affiliates. As of March 31, 2017, the negative basis difference carried over from TD was approximately $386.8 million. 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 Equity Method Investments (Tables) |
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Equity Method Investments and Joint Ventures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Equity Method Investments | The basis difference associated with the recently acquired 24.99% membership interest in Rockies Express at March 31, 2017 was allocated as follows:
Summarized financial information for Rockies Express is as follows:
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Impact of Adjustments Related to Transaction Among Entities Under Common Control, Balance Sheet [Table Text Block] | The results of our acquisitions of Terminals and NatGas are included in the condensed consolidated balance sheets as of March 31, 2017 and December 31, 2016. The following table presents our previously reported December 31, 2016 condensed consolidated balance sheet, adjusted for the acquisitions of Terminals and NatGas:
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Impact of Adjustments Related to Transaction Among Entities Under Common Control, Income Statement [Table Text Block] | The results of our acquisitions of Terminals and NatGas are included in the condensed consolidated statements of income for the three months ended March 31, 2017 and 2016. The following tables present the previously reported condensed consolidated statements of income for the three months ended March 31, 2016, adjusted for the acquisitions of Terminals and NatGas:
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Related Party Transactions (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Related Party Transactions [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Transactions with Affiliated Companies | Totals of transactions with affiliated companies, excluding transactions disclosed elsewhere in these notes, 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 | Gas imbalances with affiliated shippers are as follows:
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Inventory (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Inventory Disclosure [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Components of Inventory | The components of inventory at March 31, 2017 and December 31, 2016 consisted of the following:
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Property, Plant and Equipment (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Property, Plant and Equipment [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Components of Property Plant and Equipment | A summary of net property, plant and equipment by classification is as follows:
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Investments in Unconsolidated Affiliates (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Equity Method Investments and Joint Ventures [Abstract] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Equity Method Investments | The basis difference associated with the recently acquired 24.99% membership interest in Rockies Express at March 31, 2017 was allocated as follows:
Summarized financial information for Rockies Express is as follows:
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Risk Management (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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 months ended March 31, 2017 and 2016:
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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 and natural gas derivative contracts at March 31, 2017 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 March 31, 2017 and December 31, 2016 based on the fair value hierarchy established by the Codification:
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Long-term Debt (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Line of Credit Facility [Line Items] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Schedule of Debt | Long-term debt consisted of the following at March 31, 2017 and December 31, 2016:
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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 March 31, 2017 and December 31, 2016, 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 March 31, 2017 and December 31, 2016:
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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 March 31, 2017 and December 31, 2016:
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Partnership Equity and Distributions Partnership and Equity and Distributions (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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 distributions for the periods indicated:
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Net Income per Class A Share Net Income per Class A Share (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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 months ended March 31, 2017 and 2016:
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Reporting Segments (Tables) |
3 Months Ended | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Mar. 31, 2017 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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 |
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Variable Interest Entity VIE Assets and Liabilities (Details) - USD ($) $ in Thousands |
Mar. 31, 2017 |
Dec. 31, 2016 |
---|---|---|
Organization, Consolidation and Presentation of Financial Statements [Abstract] | ||
Deferred tax asset | $ 518,790 | $ 521,454 |
Acquisitions Equity Method Investments (Details) - Rockies Express Pipeline LLC $ in Thousands |
3 Months Ended |
---|---|
Mar. 31, 2017
USD ($)
| |
Schedule of Equity Method Investments [Line Items] | |
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity | $ (386,797) |
Basis Difference, Amortization Period | 35 years |
Long-term Debt | |
Schedule of Equity Method Investments [Line Items] | |
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity | $ 19,504 |
Property, Plant and Equipment | |
Schedule of Equity Method Investments [Line Items] | |
Equity Method Investment, Difference Between Carrying Amount and Underlying Equity | $ (406,301) |
Basis Difference, Amortization Period | 35 years |
Minimum | Long-term Debt | |
Schedule of Equity Method Investments [Line Items] | |
Basis Difference, Amortization Period | 2 years |
Maximum | Long-term Debt | |
Schedule of Equity Method Investments [Line Items] | |
Basis Difference, Amortization Period | 25 years |
Related Party Transactions - Schedule of Transactions with Affiliated Companies (Detail) - USD ($) $ in Thousands |
3 Months Ended | |
---|---|---|
Mar. 31, 2017 |
Mar. 31, 2016 |
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Related Party Transaction [Line Items] | ||
Cost of transportation services (1) | $ 4,507 | $ 4,429 |
Operation and maintenance | ||
Related Party Transaction [Line Items] | ||
Expenses related to transactions with affiliated companies | 6,277 | 6,184 |
General and administrative expense | ||
Related Party Transaction [Line Items] | ||
Expenses related to transactions with affiliated companies | 9,573 | 9,437 |
Property, Plant and Equipment | ||
Related Party Transaction [Line Items] | ||
Property, plant and equipment, net | $ 293 | $ 918 |
Related Party Transactions - Schedule of Balances with Affiliates Included in Accounts Receivables and Accounts Payable in Consolidated Balance Sheets (Detail) - USD ($) $ in Thousands |
Mar. 31, 2017 |
Dec. 31, 2016 |
---|---|---|
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | $ 1,266 | $ 590 |
Accounts payable to related parties | 6,067 | 5,824 |
Rockies Express Pipeline LLC | ||
Related Party Transaction [Line Items] | ||
Accounts Receivable, Related Parties, Current | 1,266 | 590 |
Tallgrass Operations, LLC | ||
Related Party Transaction [Line Items] | ||
Accounts payable to related parties | 6,047 | 5,811 |
Tallgrass Management, LLC | ||
Related Party Transaction [Line Items] | ||
Accounts payable to related parties | 20 | 0 |
Deeprock Development, LLC | ||
Related Party Transaction [Line Items] | ||
Accounts payable to related parties | $ 0 | $ 13 |
Related Party Transactions - Schedule of Balances of Gas Imbalance with Affiliated Shippers (Detail) - Affiliated Shippers - USD ($) $ in Thousands |
Mar. 31, 2017 |
Dec. 31, 2016 |
---|---|---|
Related Party Transaction [Line Items] | ||
Affiliate gas imbalance receivables | $ 0 | $ 177 |
Affiliate gas imbalance payables | $ 73 | $ 0 |
Related Party Transactions - Additional Information (Detail) |
3 Months Ended |
---|---|
Mar. 31, 2017
USD ($)
| |
Public Company Expense | Tallgrass Development LP | |
Related Party Transaction [Line Items] | |
Public company cost reimbursement | $ 500,000 |
Inventory Inventory (Details) - USD ($) $ in Thousands |
Mar. 31, 2017 |
Dec. 31, 2016 |
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Inventory Disclosure [Abstract] | ||
Crude oil | $ 6,903 | $ 5,462 |
Materials and supplies | 6,455 | 6,383 |
Natural gas liquids | 573 | 265 |
Gas in underground storage | 1,716 | 983 |
Inventory, Net | $ 15,647 | $ 13,093 |
Property Plant and Equipment - Components of Property Plant and Equipment (Detail) - USD ($) $ in Thousands |
Mar. 31, 2017 |
Dec. 31, 2016 |
---|---|---|
Property, Plant and Equipment [Line Items] | ||
Accumulated depreciation and amortization | $ (215,053) | $ (195,860) |
Property, plant and equipment | 2,085,670 | 2,079,232 |
Crude oil pipelines | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 1,207,727 | 1,202,125 |
Natural gas pipelines | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 575,536 | 572,150 |
Processing and treating assets | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 262,447 | 256,901 |
General and other | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | 225,243 | 223,310 |
Construction work in progress | ||
Property, Plant and Equipment [Line Items] | ||
Property , plant and equipment | $ 29,770 | $ 20,606 |
Investments in Unconsolidated Affiliates Equity Method Investments (Details) - Rockies Express Pipeline LLC $ in Thousands |
3 Months Ended |
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Mar. 31, 2017
USD ($)
| |
Schedule of Equity Method Investments [Line Items] | |
Equity Method Investment, Summarized Financial Information, Revenue | $ 201,338 |
Equity Method Investment Summarized Financial Information Operating Income | 107,369 |
Equity Method Investment, Summarized Financial Information, Net Income (Loss) | $ 66,250 |
Risk Management - Derivative Contracts Included in Consolidated Statement of Income (Detail) - Derivatives not designated as hedging contracts [Member] - USD ($) $ in Thousands |
3 Months Ended | |
---|---|---|
Mar. 31, 2017 |
Mar. 31, 2016 |
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Equity Option | ||
Derivative Instruments, Gain (Loss) [Line Items] | ||
Amount of gain (loss) recognized in income on derivatives | $ 1,885 | $ (8,946) |
Energy commodity derivative contracts | ||
Derivative Instruments, Gain (Loss) [Line Items] | ||
Amount of gain (loss) recognized in income on derivatives | 173 | (44) |
Energy Related Derivative | ||
Derivative Instruments, Gain (Loss) [Line Items] | ||
Amount of gain (loss) recognized in income on derivatives | $ 663 | $ 0 |
Risk Management Risk Management - Derivative Instruments Maximum Potential Exposure to Credit Loss (Details) - Energy commodity derivative contracts $ in Thousands |
Mar. 31, 2017
USD ($)
|
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Concentration Risk [Line Items] | |
Gross | $ 304 |
Netting agreement impact | 0 |
Cash collateral held | 0 |
Net exposure | $ 304 |
Risk Management Risk Management - Additional Information (Details) - USD ($) $ / shares in Units, $ in Thousands |
3 Months Ended | |||||
---|---|---|---|---|---|---|
Feb. 01, 2017 |
Oct. 31, 2016 |
Jul. 21, 2016 |
Jan. 01, 2016 |
Mar. 31, 2017 |
Mar. 31, 2016 |
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Derivative [Line Items] | ||||||
Partners' Capital Account, Units, Treasury Units Purchased | 736,262 | |||||
Partial exercise of call option | $ 35,300 | $ 35,335 | $ 0 | |||
Pony Express Pipeline | ||||||
Derivative [Line Items] | ||||||
Business Acquisition, Percentage of Voting Interests Acquired | 31.30% | |||||
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares | 6,518,000 | |||||
Equity Option | ||||||
Derivative [Line Items] | ||||||
Partners' Capital Account, Units, Treasury Units Purchased | 1,703,094 | 1,251,760 | 3,563,146 | |||
Partial exercise of call option | $ 72,400 | $ 53,200 | $ 151,400 | $ 72,381 | $ 0 | |
Equity Option | Pony Express Pipeline | ||||||
Derivative [Line Items] | ||||||
Derivative, Term of Contract | 18 months | |||||
Option Indexed to Issuer's Equity, Strike Price | $ 42.50 | |||||
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares | 6,518,000 |
Long-term Debt Schedule of Debt (Details) - USD ($) $ in Thousands |
Mar. 31, 2017 |
Dec. 31, 2016 |
---|---|---|
Debt Instrument [Line Items] | ||
Total long-term debt, net | $ 2,108,232 | $ 1,555,981 |
Revolving Credit Facility | ||
Debt Instrument [Line Items] | ||
Total long-term debt, net | 1,715,000 | 1,163,000 |
Tallgrass Equity, LLC | Revolving Credit Facility | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Gross | 148,000 | 148,000 |
Total long-term debt, net | 148,000 | 148,000 |
Tallgrass Energy Partners | ||
Debt Instrument [Line Items] | ||
Less: Deferred financing costs, net (1) | (6,768) | (7,019) |
Tallgrass Energy Partners | Senior Notes | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Gross | 400,000 | 400,000 |
Tallgrass Energy Partners | Revolving Credit Facility | ||
Debt Instrument [Line Items] | ||
Long-term Debt, Gross | 1,567,000 | 1,015,000 |
Total long-term debt, net | $ 1,567,000 | $ 1,015,000 |
Partnership Equity and Distributions Partnership and Equity Distributions - TEGP Summary of Distributions (Details) - Tallgrass Energy GP, LP - USD ($) $ / shares in Units, $ in Thousands |
3 Months Ended | ||||
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Mar. 31, 2017 |
Dec. 31, 2016 |
Sep. 30, 2016 |
Jun. 30, 2016 |
Mar. 31, 2016 |
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Distribution Made to Limited Partner [Line Items] | |||||
Partners' Capital Account, Distributions | $ 16,697 | $ 16,116 | $ 12,528 | $ 11,693 | $ 10,022 |
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ 0 | $ 0 | $ 0 | $ 0 | $ 0.210 |
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 | ||||
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Mar. 31, 2017 |
Dec. 31, 2016 |
Sep. 30, 2016 |
Jun. 30, 2016 |
Mar. 31, 2016 |
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Distribution Made to Limited Partner [Line Items] | |||||
Limited Partner Common Units | $ 60,486 | $ 58,793 | $ 57,332 | $ 54,442 | $ 48,238 |
Incentive Distribution Rights | 29,840 | 28,358 | 26,987 | 24,262 | 19,816 |
General Partner Units | $ 1,040 | $ 1,008 | $ 976 | $ 911 | $ 830 |
Distribution Made to Limited Partner, Distributions Paid, Per Unit | $ 0.8350 | $ 0.8150 | $ 0.7950 | $ 0.7550 | $ 0.7050 |
Net Income per Class A Share Net Income per Class A Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands |
3 Months Ended | |
---|---|---|
Mar. 31, 2017 |
Mar. 31, 2016 |
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Earnings Per Share [Abstract] | ||
Net income attributable to TEGP, excluding predecessor operations interest | $ 12,029 | $ 7,589 |
Basic average number of Class A shares outstanding | 58,075 | 47,725 |
Basic net income per Class A share | $ 0.21 | $ 0.16 |
Incremental net income attributable to TEGP including the effect of the assumed issuance of Equity Participation Shares | $ 8 | $ 0 |
Net income attributable to TEGP including incremental net income from assumed issuance of Equity Participation Shares | $ 12,037 | $ 7,589 |
Equity Participation Shares equivalent shares | 90 | 0 |
Diluted weighted average Class A Shares outstanding | 58,165 | 47,725 |
Diluted net income per Class A Share | $ 0.21 | $ 0.16 |
Regulatory Matters Regulatory Matters (Details) MMBTU / d in Thousands |
Jan. 06, 2017
MMBTU / d
|
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Regulated Operations [Abstract] | |
Capacity Enhancement | 0 |
Reporting Segments Reporting Segments - Summary of TEP's Segment Information for Payments to Acquire Plant, Property and Equipment (Details) - USD ($) $ in Thousands |
3 Months Ended | |
---|---|---|
Mar. 31, 2017 |
Mar. 31, 2016 |
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Segment Reporting Information [Line Items] | ||
Capital expenditures | $ 26,769 | $ 21,207 |
TEGP | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 26,769 | 21,207 |
TEGP | Crude Oil Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 10,436 | 15,973 |
TEGP | Natural Gas Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 4,655 | 2,133 |
TEGP | Processing & Logistics | ||
Segment Reporting Information [Line Items] | ||
Capital expenditures | 11,678 | 3,101 |
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 |
Mar. 31, 2017 |
Dec. 31, 2016 |
---|---|---|
Segment Reporting Information [Line Items] | ||
Segment assets | $ 4,073,410 | $ 3,625,480 |
TEGP | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 4,073,410 | 3,625,480 |
TEGP | Crude Oil Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 1,492,333 | 1,493,866 |
TEGP | Natural Gas Transportation & Logistics | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 1,633,358 | 1,176,147 |
TEGP | Processing & Logistics | ||
Segment Reporting Information [Line Items] | ||
Segment assets | 418,479 | 411,999 |
TEGP | Corporate and Other | ||
Segment Reporting Information [Line Items] | ||
Segment assets | $ 529,240 | $ 543,468 |