Document and Entity Information
Document and Entity Information - shares | 6 Months Ended | |
Jun. 30, 2019 | Aug. 01, 2019 | |
Document and Entity Information | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Transition Report | false | |
Document Period End Date | Jun. 30, 2019 | |
Entity File Number | 001-35358 | |
Entity Registrant Name | TC PipeLines, LP | |
Entity Incorporation, State or Country Code | DE | |
Entity Tax Identification Number | 52-2135448 | |
Entity Address, Address Line One | 700 Louisiana Street | |
Entity Address, Address Line Two | SuiteĀ 700 | |
Entity Address, City or Town | Houston | |
Entity Address, State or Province | TX | |
Entity Address, Postal Zip Code | 77002-2761 | |
City Area Code | 877 | |
Local Phone Number | 290-2772 | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Small Business | false | |
Entity Emerging Growth Company | false | |
Entity Shell Company | false | |
Title of 12(b) Security | Common units representing limited partner interests | |
Trading Symbol | TCP | |
Security Exchange Name | NYSE | |
Entity Common Stock, Shares Outstanding | 71,306,396 | |
Entity Central Index Key | 0001075607 | |
Current Fiscal Year End Date | --12-31 | |
Document Fiscal Year Focus | 2019 | |
Document Fiscal Period Focus | Q2 | |
Amendment Flag | false |
CONSOLIDATED STATEMENTS OF INCO
CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Transmission revenues | $ 93 | $ 111 | $ 206 | $ 226 |
Equity earnings (Note 5) | 30 | 36 | 84 | 95 |
Operation and maintenance expenses | (17) | (17) | (33) | (33) |
Property taxes | (6) | (7) | (13) | (14) |
General and administrative | (2) | (1) | (4) | (2) |
Depreciation and amortization | (19) | (24) | (39) | (48) |
Financial charges and other (Note 15) | (21) | (23) | (43) | (46) |
Net income before taxes | 58 | 75 | 158 | 178 |
Income taxes | (1) | (1) | (1) | |
Net Income | 57 | 75 | 157 | 177 |
Net income attributable to non-controlling interests | 2 | 2 | 9 | 8 |
Net income attributable to controlling interests | 55 | 73 | 148 | 169 |
Net income attributable to controlling interest allocation (Note 9) | ||||
General Partner | 1 | 1 | 3 | 3 |
Net income attributable to controlling interests | 55 | 73 | 148 | 169 |
Common Units | ||||
Net income attributable to controlling interest allocation (Note 9) | ||||
Net income attributable to common units | $ 54 | $ 72 | $ 145 | $ 166 |
Net income per common unit (Note 9) - basic and diluted (in dollars per unit) | $ 0.75 | $ 1 | $ 2.03 | $ 2.33 |
Weighted average common units outstanding - basic and diluted (in units) | 71.3 | 71.3 | 71.3 | 71.2 |
Common units outstanding, end of period (in units) | 71.3 | 71.3 | 71.3 | 71.3 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME | ||||
Net income | $ 57 | $ 75 | $ 157 | $ 177 |
Other comprehensive income | ||||
Change in fair value of cash flow hedges (Note 13) | (9) | (1) | (14) | 6 |
Amortization of realized loss on derivative financial instruments | 2 | 2 | ||
Reclassification of net income of gains and losses on cash flow hedges | 1 | 3 | 1 | 3 |
Comprehensive income | 49 | 79 | 144 | 188 |
Comprehensive income attributable to non-controlling interests | 2 | 3 | 9 | 9 |
Comprehensive income attributable to controlling interests | $ 47 | $ 76 | $ 135 | $ 179 |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions | Jun. 30, 2019 | Dec. 31, 2018 |
Current Assets | ||
Cash and cash equivalents | $ 45 | $ 33 |
Accounts receivable and other (Note 14) | 33 | 48 |
Inventories | 9 | 8 |
Other | 3 | 8 |
Total current assets | 90 | 97 |
Equity investments (Note 5) | 1,118 | 1,196 |
Property, plant and equipment (Net of $1,145 accumulated depreciation; 2018 - $1,110) | 1,520 | 1,529 |
Goodwill | 71 | 71 |
Other assets | 6 | |
TOTAL ASSETS | 2,799 | 2,899 |
Current Liabilities | ||
Accounts payable and accrued liabilities | 26 | 36 |
Accounts payable to affiliates (Note 12) | 6 | 6 |
Accrued interest | 11 | 12 |
Current portion of long-term debt (Note 7) | 101 | 36 |
Total current liabilities | 144 | 90 |
Long-term debt, net (Note 7) | 1,892 | 2,072 |
Deferred state income taxes | 9 | 9 |
Other liabilities | 34 | 29 |
Total liabilities | 2,079 | 2,200 |
Partners' Equity | ||
General partner | 14 | 13 |
Accumulated other comprehensive income (loss) (AOCI) | (5) | 8 |
Controlling interests | 618 | 591 |
Non-controlling interests | 102 | 108 |
Total partners' equity | 720 | 699 |
TOTAL LIABILITIES AND PARTNERS' EQUITY | 2,799 | 2,899 |
Common Units | ||
Partners' Equity | ||
Limited partner | 514 | 462 |
Class B Units | ||
Partners' Equity | ||
Limited partner | $ 95 | $ 108 |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions | Jun. 30, 2019 | Dec. 31, 2018 |
CONSOLIDATED BALANCE SHEETS | ||
Accumulated depreciation | $ 1,145 | $ 1,110 |
CONSOLIDATED STATEMENT OF CASH
CONSOLIDATED STATEMENT OF CASH FLOWS - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Cash Generated from Operations | ||||
Net income | $ 57 | $ 75 | $ 157 | $ 177 |
Depreciation and amortization | 19 | 24 | 39 | 48 |
Amortization of debt issue costs reported as interest expense | 1 | 1 | ||
Amortization of realized losses | 2 | |||
Equity earnings from equity investments (Note 5) | (30) | (36) | (84) | (95) |
Distributions received from operating activities of equity investments (Note 5) | 112 | 96 | ||
Change in other long term liabilities | (1) | |||
Equity allowance for funds used during construction (AFUDC equity) | (1) | |||
Change in operating working capital (Note 11) | 4 | (5) | ||
Cash generated from operations | 228 | 223 | ||
Investing Activities | ||||
Investment in Great Lakes (Note 5) | (5) | (4) | ||
Distribution received from return of investment (Note 5) | 52.6 | 55.2 | ||
Capital expenditures | (29) | (9) | ||
Customer advances for construction | 1 | |||
Investing activities | 22 | (8) | ||
Financing Activities | ||||
Distributions paid to common units, including the general partner (Note 10) | (95) | (123) | ||
Distributions paid to Class B units (Note 8) | (13) | (15) | ||
Distributions paid to non-controlling interests | (15) | (3) | ||
Common unit issuance, net | 40 | |||
Long-term debt issued, net of discount (Note 7) | 20 | 130 | ||
Long-term debt repaid (Note 7) | (135) | (225) | ||
Debt issuance costs | (1) | |||
Financing activities | (238) | (197) | ||
Increase in cash and cash equivalents | 12 | 18 | ||
Cash and cash equivalents, beginning of period | 33 | 33 | ||
Cash and cash equivalents, end of period | 45 | 51 | 45 | 51 |
Iroquois | ||||
Cash Generated from Operations | ||||
Equity earnings from equity investments (Note 5) | (7) | (9) | (20) | (27) |
Investing Activities | ||||
Distribution received from return of investment (Note 5) | 5 | 5 | ||
Northern Border | ||||
Cash Generated from Operations | ||||
Equity earnings from equity investments (Note 5) | $ (14) | $ (15) | (35) | $ (32) |
Investing Activities | ||||
Distribution received from return of investment (Note 5) | $ 50 |
CONSOLIDATED STATEMENT OF CHANG
CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS' EQUITY - 6 months ended Jun. 30, 2019 - USD ($) shares in Millions, $ in Millions | Limited PartnersCommon Units | Limited PartnersClass B Units | General Partner | Accumulated Other Comprehensive Income (Loss) | [1] | Non-Controlling Interest | Total |
Partners' Equity at beginning of period at Dec. 31, 2018 | $ 462 | $ 108 | $ 13 | $ 8 | $ 108 | $ 699 | |
Partners' Equity at beginning of period (in units) at Dec. 31, 2018 | 71.3 | 1.9 | |||||
Increase (Decrease) in Partners' Equity | |||||||
Net income | $ 145 | 3 | 9 | 157 | |||
Other comprehensive income (loss) | (13) | (13) | |||||
Distributions (Note 10) | (93) | $ (13) | (2) | (15) | (123) | ||
Partners' Equity at end of period at Jun. 30, 2019 | $ 514 | $ 95 | $ 14 | $ (5) | $ 102 | $ 720 | |
Partners' Equity at end of period (in units) at Jun. 30, 2019 | 71.3 | 1.9 | |||||
[1] | Gain (loss) related to cash flow hedges reported in AOCI and expected to be reclassified to Net income in the next 12 months is estimated to be $2 million. These estimates assume constant interest rates over time; however, the amounts reclassified will vary based on actual value of interest rates at the date of settlement. |
CONSOLIDATED STATEMENT OF CHA_2
CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS' EQUITY (Parenthetical) $ in Millions | 6 Months Ended |
Jun. 30, 2019USD ($) | |
CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS' EQUITY | |
Gain (Loss) related to cash flow hedges in AOCI expected to be reclassified to Net income in the next 12 months | $ 2 |
ORGANIZATION
ORGANIZATION | 6 Months Ended |
Jun. 30, 2019 | |
ORGANIZATION | |
ORGANIZATION | NOTE 1 ORGANIZATION ā TC PipeLines, LP and its subsidiaries are collectively referred to herein as the Partnership. The Partnership was formed by TransCanada PipeLines Limited, a wholly owned subsidiary of TC Energy Corporation (TC Energy Corporation together with its subsidiaries collectively referred to herein as TC Energy), to acquire, own and participate in the management of energy infrastructure assets in North America. ā The Partnership owns its pipeline assets through an intermediate general partnership, TC PipeLines Intermediate GP, LLC and three intermediate limited partnerships (ILPs), TC GL Intermediate Limited Partnership, TC PipeLines Intermediate Limited Partnership and TC Tuscarora Intermediate Limited Partnership. |
SIGNIFICANT ACCOUNTING POLICIES
SIGNIFICANT ACCOUNTING POLICIES | 6 Months Ended |
Jun. 30, 2019 | |
SIGNIFICANT ACCOUNTING POLICIES | |
SIGNIFICANT ACCOUNTING POLICIES | NOTE 2 SIGNIFICANT ACCOUNTING POLICIES ā The accompanying consolidated financial statements and related notes have been prepared in accordance with United States generally accepted accounting principles (GAAP) and amounts are stated in U.S. dollars. The results of operations for the three and six months ended June 30, 2019 and 2018 are not necessarily indicative of the results that may be expected for the full fiscal year. ā The accompanying consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto for the year ended December 31, 2018 included in our Annual Report on Form 10-K. That report contains a more comprehensive summary of the Partnershipās significant accounting policies. In the opinion of management, the accompanying consolidated financial statements contain all of the appropriate adjustments, which are normally recurring adjustments unless otherwise noted, and considered necessary to present fairly the financial position of the Partnership, the results of operations and cash flows for the respective periods. Our significant accounting policies are consistent with those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2018, except as described in Note 3, Accounting Pronouncements. ā Basis of Presentation ā The Partnership consolidates its interests in entities over which it is able to exercise control. To the extent there are interests owned by other parties, these interests are included as non-controlling interests. The Partnership uses the equity method of accounting for its investments in entities over which it is able to exercise significant influence. ā Acquisitions by the Partnership from TC Energy are considered common control transactions. If businesses are acquired from TC Energy that will be consolidated by the Partnership, the historical consolidated financial statements are required to be recast, except net income per common unit, to include the acquired entities for all periods presented. ā If the Partnership acquires an asset or an investment from TC Energy, which will be accounted for by the equity method, the financial information is not required to be recast and the transaction is accounted for prospectively from the date of the acquisition. ā U.S. federal and certain state income taxes are the responsibility of the partners and are not reflected in these consolidated financial statements. The tax effect of the Partnership's activities accrues to its partners. The Partnershipās taxable income or loss, which may vary substantially from the net income or loss reported in the consolidated statement of operations, is includable in the U.S. federal income tax returns of each partner. ā In instances where the Partnershipās consolidated entities are subject to state income taxes, the asset-liability method is used to account for taxes. This method requires recognition of deferred tax assets and liabilities for future tax consequences attributable to the differences between the financial statement carrying amount of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are classified as non-current on our consolidated balance sheets. ā Use of Estimates ā The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities, if any, as of the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Although management believes these estimates are reasonable, actual results could differ from these estimates. |
ACCOUNTING PRONOUNCEMENTS
ACCOUNTING PRONOUNCEMENTS | 6 Months Ended |
Jun. 30, 2019 | |
ACCOUNTING PRONOUNCEMENTS | |
ACCOUNTING PRONOUNCEMENTS | NOTE 3 ACCOUNTING PRONOUNCEMENTS ā Changes in Accounting Policies effective January 1, 2019 ā Leases ā In February 2016, the Financial Accounting Standards Board (FASB) issued new guidance on the accounting for leases. The new guidance amends the definition of a lease such that, in order for an arrangement to qualify as a lease, the lessee is required to have both (1) the right to obtain substantially all of the economic benefits from the use of the asset and (2) the right to direct the use of the asset. The new guidance also establishes a right-of-use (ROU) model that requires a lessee to recognize a ROU asset and corresponding lease liability on the balance sheet for all leases with a term longer than twelve months. Leases will be classified as finance or operating, with classification affecting the pattern of expense recognition in the consolidated statements of income. The new guidance does not make extensive changes to previous lessor accounting. ā Under the new guidance, the Partnership determines if an arrangement is a lease at inception. Operating leases are recognized as ROU assets and included in Property, plant and equipment while corresponding liabilities are included in āAccounts payable and otherā, and āOther long-term liabilitiesā on the consolidated balance sheet. ā Operating lease ROU assets and operating lease liabilities are recognized based on the present value of the future minimum lease payments over the lease term at commencement date. As the Partnershipās leases do not provide an implicit rate, the Partnership uses an incremental borrowing rate that approximates its borrowing cost based on the information available at commencement date in determining the present value of future payments. The operating lease ROU asset also includes any lease payments made and initial direct costs incurred and excludes lease incentives. Lease terms may include options to extend or terminate the lease when it is reasonably certain that the Partnership will exercise that option. Operating lease expense is recognized on a straight-line basis over the lease term and included in āOperation and maintenance expensesā in the consolidated statements of income. ā The new guidance was effective January 1, 2019 and was applied using optional transition relief which allowed entities to initially apply the new lease standard at adoption and recognize a cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption. This transition option allowed us to not apply the new guidance, including disclosure requirements, to the comparative periods presented. ā We elected available practical expedients and exemptions upon adoption which allowed us: ā ā not to reassess prior conclusions on existing leases regarding lease identification, lease classification and initial direct costs under the new standard; ā to carry forward the historical lease classification and our accounting treatment for land easements on existing agreements; ā to not recognize ROU assets or lease liabilities for leases that qualify for the short-term lease recognition exemption; ā to not separate lease and non-lease components for all leases for which we are the lessee; and ā to use hindsight in determining the lease term and assessing ROU assets for impairment. ā In the application of the new guidance, assumptions and judgments are used to determine the following: ā ā whether a contract contains a lease and the duration of the lease term including exercising lease renewal options. The lease term for all of the Partnershipās leases includes the non-cancellable period of the lease plus any additional periods covered by either the Partnershipās option to extend (or not to terminate) the lease that the Partnership is reasonably certain to exercise, or an option to extend (or not to terminate) the lease controlled by the lessor; and ā the discount rate for the lease. ā The standard did not impact our previously reported results and did not have a material impact on the Partnership's consolidated balance sheets, consolidated statements of income or consolidated statement of cash flows at the date of adoption. ā The most significant change as a result of the adoption was the recognition of ROU assets and lease liabilities for operating leases which was approximately $0.6 million at January 1, 2019 and $0.5 million at June 30, 2019. For the three and six months ended June 30, 2019, the Partnershipās operating lease cost was not material to the Partnershipās consolidated results. The weighted average remaining term and discount rate of the Partnershipās operating leases was approximately 2.41 years and 3.57 percent, respectively. ā Fair Value Measurement ā In August 2018, the FASB issued new guidance that amends certain disclosure requirements for the fair value measurements as part of its disclosure framework project. This new guidance is effective January 1, 2020, however, early adoption of certain or all requirements is permitted. The Partnership elected to adopt this guidance effective first quarter 2019. The guidance was applied retrospectively and did not have a material effect on the Partnershipās consolidated financial statements. ā Future accounting changes ā Measurement of credit losses on financial instruments ā In June 2016, the FASB issued new guidance that significantly changes how entities measure credit losses for most financial assets and certain other financial instruments that are not measured at fair value through net income (loss). The new guidance amends the impairment model of financial instruments basing it on expected losses rather than incurred losses. These expected credit losses will be recognized as an allowance rather than as a direct write down of the amortized cost basis. The new guidance is effective January 1, 2020 and will be applied using a modified retrospective approach. We have determined which of our assets are within the scope of the new standard and have started to compile historical credit loss information. We are also assessing our current process to determine if any changes are required as a result. We continue to evaluate the impact of the adoption of this guidance and have not yet determined the effect on our consolidated financial statements. ā Consolidation ā In October 2018, the FASB issued new guidance for determining whether fees paid to decision makers and service providers are variable interests for indirect interests held through related parties under common control. This new guidance is effective January 1, 2020, and will be applied on a retrospective basis, however early adoption is permitted. The Partnership has determined that there is no impact to its consolidated financial statements as a result of this new guidance. |
REGULATORY
REGULATORY | 6 Months Ended |
Jun. 30, 2019 | |
REGULATORY | |
REGULATORY | NOTE 4 REGULATORY ā Iroquois, Tuscarora, and Northern Border took the actions listed below to conclude the issues impacting their pipelines as contemplated by the 2017 Tax Act and certain FERC actions that began in March of 2018, namely FERCās Revised Policy Statement on Treatment of Income Taxes (Revised Policy Statement) and a Final Rule that established a schedule by which interstate pipelines must either (i) file a new uncontested rate settlement or (ii) file a one-time report, called FERC Form No. 501-G, that quantified the rate impact of the 2017 Tax Act on FERC-regulated pipelines and the impact of the Revised Policy Statement on pipelines held by an MLP (collectively ā2018 FERC Actionsā). ā Iroquois ā On February 28, 2019, Iroquois filed an uncontested settlement with FERC to address the issues contemplated by the 2017 Tax Act and 2018 FERC Actions via an amendment to its prior 2016 settlement (2019 Iroquois Settlement). Among the terms of the 2019 Iroquois Settlement, Iroquois agreed to reduce its existing maximum system rates by 6.5 percent to be implemented in two phases, (i) effective March 1, 2019, a 3.25 percent rate reduction and (ii) effective April 1, 2020, an additional 3.25 percent rate reduction, which will conclude the total 6.5 percent rate reduction from the 2016 settlement rates. The 2019 Iroquois Settlement, which was approved by FERC on May 2, 2019, preserved the 2016 settlement moratorium on further rate changes until September 1, 2020. Unless superseded by a subsequent rate case or settlement, Iroquois will be required to have new rates in effect on March 1, 2023. ā Tuscarora ā On March 15, 2019, Tuscarora filed an uncontested settlement with FERC to address the issues contemplated by the 2017 Tax Act and 2018 FERC Actions via an amendment to its prior 2016 settlement (2019 Tuscarora Settlement). Among the terms of the 2019 Tuscarora Settlement, Tuscarora agreed to reduce its existing maximum system rates by 1.7 percent effective February 1, 2019 through to July 31, 2019. The existing maximum rates will decrease by an additional 10.8 percent for the period August 1, 2019 through the term of the settlement. Tuscarora is required to have new rates in effect on February 1, 2023. Tuscarora and its customers also agreed on a moratorium on further rate changes until January 31, 2023. The 2019 Tuscarora Settlement, which was approved by FERC on May 2, 2019, will also reflect an elimination of the tax allowance previously recovered in rates along with accumulated deferred income taxes (ADIT) for rate-making purposes. ā Northern Border ā On May 24, 2019, Northern Border's amended settlement agreement filed with the FERC for approval on April 4, 2019, was approved and its 501-G proceeding was terminated. Until superseded by a subsequent rate case or settlement, effective January 1, 2020, the amended settlement agreement extends the two percent rate reduction implemented on February 1, 2019 to July 1, 2024. |
EQUITY INVESTMENTS
EQUITY INVESTMENTS | 6 Months Ended |
Jun. 30, 2019 | |
EQUITY INVESTMENTS | |
EQUITY INVESTMENTS | NOTE 5 EQUITY INVESTMENTS ā The Partnership has equity interests in Northern Border, Great Lakes and Iroquois. The pipeline systems owned by these entities are regulated by FERC. The pipeline systems of Northern Border and Great Lakes are operated by subsidiaries of TC Energy. The Iroquois pipeline system is operated by Iroquois Pipeline Operating Company, a wholly owned subsidiary of Iroquois. The Partnership uses the equity method of accounting for its interests in its equity investees. The Partnershipās equity investments are held through our ILPs that are considered to be variable interest entities (VIEs) (Refer to Note 16). ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā Ownership ā Equity Earnings ā Equity Investments ā ā Interest at ā Three months ended ā Six months ended ā ā ā ā (unaudited) ā June 30, ā June 30, ā June 30, ā June 30, ā December 31, (millions of dollars) 2019 2019 2018 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā Northern Border ā 50 % 14 15 ā 35 32 ā 431 ā 497 Great Lakes ā 46.45 % 9 ā 12 ā 29 ā 36 ā 484 ā 489 Iroquois ā 49.34 % 7 9 ā 20 27 ā 203 ā 210 ā ā ā 30 36 ā 84 95 ā 1,118 ā 1,196 ā Distributions from Equity Investments ā Distributions received from equity investments in the three and six months ended June 30, 2019 were $108 million and $167 million, respectively (June 30, 2018 - $56 million and $101 million, respectively), of which $52.6 million and $55.2 million, respectively (June 30, 2018 - $2.6 million and $5.2 million, respectively), were considered return of capital and included in āInvesting Activitiesā in the Partnershipās consolidated statement of cash flows. The return of capital was related to our investment in Northern Border and Iroquois (see further discussion below). ā Northern Border ā During the three and six months ended June 30, 2019, the Partnership received distributions from Northern Border amounting to $72 million and $100 million, respectively (June 30, 2018 - $17 million and $39 million, respectively) which includes the Partnershipās 50 percent share of the Northern Borderās $100 million distribution on June 26, 2019. The $100 million was 100 percent financed by borrowing on its $200 million revolving credit facility. The $50 million cash the Partnership received did not represent a distribution of operating cash flow during the period and therefore it was reported as a return of investment in the Partnershipās consolidated statement of cash flows. ā The Partnership did not have undistributed earnings from Northern Border for the three and six months ended June 30, 2019 and 2018. ā The summarized financial information provided to us by Northern Border is as follows: ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS ā ā ā ā Cash and cash equivalents 26 10 Other current assets 33 36 Property, plant and equipment, net 1,008 1,037 Other assets 13 13 ā 1,080 1,096 ā ā ā ā ā LIABILITIES AND PARTNERSā EQUITY ā ā ā ā Current liabilities 46 34 Deferred credits and other 37 35 Long-term debt, net (a) 365 264 Partnersā equity ā ā ā ā Partnersā capital 633 764 Accumulated other comprehensive loss (1) (1) ā 1,080 1,096 ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Transmission revenues 67 68 148 140 Operating expenses (20) (19) (40) (38) Depreciation (16) (15) (31) (30) Financial charges and other (4) (4) (8) (7) Net income 27 30 69 65 (a) No current maturities as of June 30, 2019 and December 31, 2018. At June 30, 2019, Northern Border is in compliance with all its financial covenants. ā Great Lakes ā The Partnership made an equity contribution to Great Lakes of $5 million in the first quarter of 2019 (June 30, 2018 - $4 million). This amount represents the Partnershipās 46.45 percent share of an $11 million cash call from Great Lakes to make a scheduled debt repayment. ā The Partnership did not have undistributed earnings from Great Lakes for the three and six months ended June 30, 2019 and 2018. ā The summarized financial information provided to us by Great Lakes is as follows: ā ā ā ā ā ā (unaudited) ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS ā ā ā ā Current assets 56 75 Property, plant and equipment, net 687 689 ā 743 764 ā ā ā ā ā LIABILITIES AND PARTNERSā EQUITY ā ā ā ā Current liabilities 26 26 Net long-term debt, including current maturities (a) 229 240 Other long term liabilities ā 4 ā 4 Partners' equity 484 494 ā 743 764 ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Transmission revenues 51 53 123 134 Operating expenses (19) (15) (35) (32) Depreciation (8) ā (8) (16) (16) Financial charges and other (5) (5) (9) (9) Net income 19 25 63 77 (a) Includes current maturities of $21 million as of June 30, 2019 and as of December 31, 2018. At June 30, 2019, Great Lakes is in compliance with all its financial covenants. ā Iroquois ā During the three and six months ended June 30, 2019, the Partnership received distributions from Iroquois amounting to $14 million and $28 million, respectively (June 30, 2018 - $14 million and $28 million, respectively), which includes the Partnershipās 49.34 percent share of the Iroquois unrestricted cash distribution amounting to approximately $2.6 million and $5.2 million, respectively (June 30, 2018 - $2.6 million and $5.2 million, respectively). The unrestricted cash did not represent a distribution of Iroquoisā cash from operations during the period and therefore it was reported as a return of investment in the Partnershipās consolidated statement of cash flows. Iroquois declared its second quarter 2019 distribution of $28 million on July 24, 2019, of which the Partnership received its 49.34 percent share or $14 million on August 1, 2019. The distribution includes our 49.34 percent share of the Iroquois unrestricted cash distribution amounting to approximately $2.6 million. The Partnership did not have undistributed earnings from Iroquois for the three and six months ended June 30, 2019 and 2018. ā The summarized financial information provided to us by Iroquois is as follows: ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS Cash and cash equivalents 73 80 Other current assets 25 32 Property, plant and equipment, net 573 581 Other assets 14 8 ā 685 701 ā ā ā ā ā LIABILITIES AND PARTNERSā EQUITY ā ā Current liabilities 15 19 Long-term debt, net (a) 319 325 Other non-current liabilities 21 14 Partners' equity 330 343 ā 685 701 ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Transmission revenues 40 ā 44 ā 92 ā 105 Operating expenses (13) ā (14) ā (28) ā (28) Depreciation (8) ā (7) ā (15) ā (15) Financial charges and other (4) ā (4) ā (7) ā (7) Net income 15 ā 19 ā 42 ā 55 (a) Includes current maturities of $4 million as of June 30, 2019 (December 31, 2018 - $146 million). At June 30, 2019, Iroquois is in compliance with all its financial covenants . |
REVENUES
REVENUES | 6 Months Ended |
Jun. 30, 2019 | |
REVENUES | |
REVENUES | NOTE 6 REVENUES ā Disaggregation of Revenues ā For the three and six months ended June 30, 2019 and 2018, effectively all of the Partnershipās revenues were from capacity arrangements and transportation contracts with customers as discussed in more detail below. ā Capacity Arrangements and Transportation Contracts ā The Partnershipās performance obligations in its contracts with customers consist primarily of capacity arrangements and natural gas transportation contracts. ā The Partnershipās revenues are generated from contractual arrangements for committed capacity and from transportation of natural gas which are treated as a bundled performance obligation. Revenues earned from firm contracted capacity arrangements are recognized ratably over the term of the contract regardless of the amount of natural gas that is transported. Transportation revenues for interruptible or volumetric-based services are recognized when the service is performed. The Partnership has elected to utilize the practical expedient of recognizing revenue as invoiced. ā The Partnership's pipeline systems are subject to FERC regulations and, as a result, a portion of revenues collected may be subject to refund if invoiced during an interim period when a rate proceeding is ongoing. Allowances for these potential refunds are recognized using management's best estimate based on the facts and circumstances of the proceeding. Any allowances that are recognized during the proceeding process are refunded or retained, as applicable, at the time a regulatory decision becomes final. As of June 30, 2019, the Partnership does not have any outstanding refund obligations related to any rate proceedings. Revenues are invoiced and paid on a monthly basis. The Partnershipās pipeline systems do not take ownership of the natural gas that is transported for customers. Revenues from contracts with customers are recognized net of any taxes collected from customers, which are subsequently remitted to governmental authorities. ā Contract Balances ā All of the Partnershipās contract balances pertain to receivables from contracts with customers amounting to $31 million at June 30, 2019 (December 31, 2018 - $44 million) and are recorded as Trade accounts receivable and reported as āAccounts receivable and otherā in the Partnershipās consolidated balance sheet (Refer to Note 14). ā Additionally, our accounts receivable represent the Partnershipās unconditional right to consideration for services completed which includes billed and unbilled accounts. ā Future revenue from remaining performance obligations ā When the right to invoice practical expedient is applied, the guidance does not require disclosure of information related to future revenue from remaining performance obligations, therefore, no additional disclosure is required. ā Additionally, in the application of the right to invoice practical expedient, the Partnershipās revenues from regulated capacity arrangements are recognized based on rates specified in the contract. Therefore, the amount invoiced, which includes the capacity contracted and variable volume of natural gas transported, corresponds directly to the value the customer received. These revenues are recognized on a monthly basis once the Partnershipās performance obligation to provide capacity has been satisfied. ā |
DEBT AND CREDIT FACILITIES
DEBT AND CREDIT FACILITIES | 6 Months Ended |
Jun. 30, 2019 | |
DEBT AND CREDIT FACILITIES | |
DEBT AND CREDIT FACILITIES | NOTE 7 DEBT AND CREDIT FACILITIES ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā Weighted Average ā Weighted Average ā ā ā ā Interest Rate for the ā ā ā Interest Rate for the (unaudited) ā ā ā Six Months Ended ā December 31, ā Year Ended (millions of dollars) ā June 30, 2019 ā June 30, 2019 ā 2018 ā December 31, 2018 TC PipeLines, LP ā ā ā ā ā ā ā ā ā ā ā ā Senior Credit Facility due 2021 ā 3.61 % ā ā 40 ā 3.14 % ā 2013 Term Loan Facility due 2022 450 3.73 % ā ā 500 ā 3.23 % ā 4.65% Unsecured Senior Notes due 2021 350 4.65 % (a) ā 350 ā 4.65 % (a) 4.375% Unsecured Senior Notes due 2025 ā 350 ā 4.375 % (a) ā 350 ā 4.375 % (a) 3.90 % Unsecured Senior Notes due 2027 ā 500 ā 3.90 % (a) ā 500 ā 3.90 % (a) GTN ā ā ā ā ā ā ā ā ā ā ā ā 5.29% Unsecured Senior Notes due 2020 100 5.29 % (a) ā 100 ā 5.29 % (a) 5.69% Unsecured Senior Notes due 2035 150 5.69 % (a) ā 150 ā 5.69 % (a) Unsecured Term Loan Facility due 2019 ā ā ā ā ā ā ā 35 ā 2.93 % ā PNGTS ā ā ā ā ā ā ā ā ā ā ā ā Revolving Credit Facility due 2023 ā 29 ā 3.74 % ā ā 19 ā 3.55 % ā Tuscarora ā ā ā ā ā ā ā ā ā ā ā ā Unsecured Term Loan due 2020 ā 24 ā 3.62 % ā ā 24 ā 3.10 % ā North Baja ā ā ā ā ā ā ā ā ā ā ā ā Unsecured Term Loan due 2021 ā 50 ā 3.56 % ā ā 50 ā 3.54 % ā ā 2,003 ā ā ā 2,118 ā ā ā ā Less: unamortized debt issuance costs and debt discount ā 10 ā ā ā ā ā 10 ā ā ā ā Less: current portion 101 ā ā ā ā 36 ā ā ā ā ā 1,892 ā ā ā 2,072 ā ā ā ā (a) Fixed interest rate ā TC PipeLines, LP ā The Partnershipās Senior Credit Facility consists of a $500 million senior revolving credit facility with a banking syndicate, maturing November 10, 2021. In March 2019, the Partnership repaid all amounts outstanding under its Senior Credit Facility and there was no outstanding balance at June 30, 2019 (December 31, 2018 - $40 million). ā The LIBOR-based interest rate applicable to the Senior Credit Facility was 3.77 percent at December 31, 2018. ā On June 26, 2019, the Partnership repaid $50 million of the principal balance under its 2013 Term Loan Facility using proceeds from Northern Border's special distribution (see Note 5). Additionally, in conjunction with this repayment, the Partnership also terminated an equivalent amount in interest rate swaps that were used to hedge this facility at a rate of 2.81 percent. As of June 30, 2019, the variable interest rate exposure related to the 2013 Term Loan Facility was hedged using interest rate swaps at an average rate of 3.26 percent (December 31, 2018 ā3.26 percent). Prior to hedging activities, the LIBOR-based interest rate on the 2013 Term Loan Facility was 3.69 percent at June 30, 2019 (December 31, 2018 - 3.60 percent). ā The Senior Credit Facility and the 2013 Term Loan Facility require the Partnership to maintain a certain leverage ratio (debt to adjusted cash flow [net income plus cash distributions received, extraordinary losses, interest expense, expense for taxes paid or accrued, and depreciation and amortization expense less equity earnings and extraordinary gains]) of no greater than 5.00 to 1.00 for each fiscal quarter, except for the fiscal quarter and the two following fiscal quarters in which one or more acquisitions have been executed, in which case the leverage ratio is to be no greater than 5.50 to 1.00. The leverage ratio was 2.78 to 1.00 as of June 30, 2019. ā GTN ā GTNās Unsecured Senior Notes contain a covenant that limits total debt to no greater than 70 percent of GTNās total capitalization. GTNās total debt to total capitalization ratio at June 30, 2019 was ā During the three months ended June 30, 2019, GTN's Unsecured Term Loan Facility matured and was fully repaid using the Partnership's funds from operations. The LIBOR-based interest rate applicable to GTNās Unsecured Term Loan Facility was 3.30 percent at December 31, 2018. ā PNGTS ā PNGTSā Revolving Credit Facility requires PNGTS to maintain a leverage ratio not greater than 5.00 to 1.00. The leverage ratio was 0.5 to 1.00 as of June 30, 2019. ā The LIBOR-based interest rate applicable to PNGTSā Revolving Credit Facility was 3.69 percent at June 30, 2019 (December 31, 2018 - 3.60 percent). ā Tuscarora ā Tuscaroraās Unsecured Term Loan contains a covenant that requires Tuscarora to maintain a debt service coverage ratio (cash available from operations divided by a sum of interest expense and principal payments) of greater than or equal to 3.00 to 1.00. As of June 30, 2019, the ratio was 9.44 to 1.00. ā The LIBOR-based interest rate applicable to Tuscaroraās Unsecured Term Loan Facility was 3.57 percent at June 30, 2019 (December 31, 2018 - 3.47 percent). ā North Baja ā North Bajaās Term Loan Facility contains a covenant that limits total debt to no greater than 70 percent of North Bajaās total capitalization. North Bajaās total debt to total capitalization ratio at June 30, 2019 was 39.06 percent. ā The LIBOR-based interest rate applicable to North Bajaās Term Loan Facility was 3.52 percent at June 30, 2019 (December 31, 2018 - 3.54 percent). ā Partnership (TC PipeLines, LP and its subsidiaries) ā At June 30, 2019, the Partnership was in compliance with its financial covenants, in addition to the other covenants which include restrictions on entering into mergers, consolidations and sales of assets, granting liens, material amendments to the Fourth Amended and Restated Agreement of Limited Partnership (Partnership Agreement), incurring additional debt and distributions to unitholders. ā The principal repayments required of the Partnership on its debt are as follows: ā ā ā ā (unaudited) ā ā (millions of dollars) Principal Payments 2019 1 2020 123 2021 400 2022 450 2023 ā 29 Thereafter 1,000 ā 2,003 ā |
PARTNERS' EQUITY
PARTNERS' EQUITY | 6 Months Ended |
Jun. 30, 2019 | |
PARTNERS' EQUITY | |
PARTNERS' EQUITY | NOTE 8 PARTNERSā EQUITY ā ATM equity issuance program (ATM program) ā During the six months ended June 30, 2019, no common units were issued under this program. ā Class B units issued to TC Energy ā The Class B units entitle TC Energy to an annual distribution based on 30 percent of GTNās annual distributions as follows: (i) 100 percent of distributions above $20 million for the year ending December 31, 2019; (ii) 43.75 percent of distributions above $20 million for the year ending December 31, 2020; and (iii) 25 percent of distributions above $20 million thereafter (Class B Distribution). Additionally, the Class B Distribution will be further reduced by 35 percent, which is equivalent to the percentage by which distributions payable to the common units were reduced in 2018 (Class B Reduction). The Class B Reduction was implemented during the first quarter of 2018 following the Partnershipās common unit distribution reduction of 35 percent. The Class B Reduction will continue to apply to any particular calendar year until distributions payable in respect of common units for such calendar year equal or exceed $3.94 per common unit. ā For the year ended December 31, 2019, the Class B unitsā equity account will be increased by the Class B Distribution, less the Class B Reduction, until such amount is declared for distribution and paid in the first quarter of 2020. During the six months ended June 30, 2019, the Class B threshold was not exceeded. ā For the year ended December 31, 2018, the Class B distribution was $13 million and was declared and paid in the first quarter of 2019. |
NET INCOME PER COMMON UNIT
NET INCOME PER COMMON UNIT | 6 Months Ended |
Jun. 30, 2019 | |
NET INCOME PER COMMON UNIT | |
NET INCOME PER COMMON UNIT | NOTE 9 NET INCOME PER COMMON UNIT ā Net income per common unit is computed by dividing net income attributable to controlling interests, after deduction of amounts attributable to the General Partner and Class B units, by the weighted average number of common units outstanding. ā The amount allocable to the General Partner equals an amount based upon the General Partnerās two percent general partner interest, plus an amount equal to incentive distributions. Incentive distributions are paid to the General Partner if quarterly cash distributions on the common units exceed levels specified in the Partnership Agreement . ā The amount allocable to the Class B units in 2019 equals 30 percent of GTNās distributable cash flow during the year ended December 31, 2019 less $20 million and is further reduced by the estimated Class B Reduction for 2019 (December 31, 2018-$20 million less Class B Reduction). During the three and six months ended June 30, 2019 and 2018, no amounts were allocated to the Class B units as the annual threshold was not exceeded. ā Net income per common unit was determined as follows: ā ā ā ā ā ā ā ā ā ā ā ā ā ā (unaudited) ā Three months ended June 30, ā Six months ended June 30, (millions of dollars, except per common unit amounts) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā ā ā ā ā Net income attributable to controlling interests ā 55 ā ā 73 ā 148 ā ā 169 Net income attributable to the General Partner ā ā (1) ā ā (1) ā ā (3) ā ā (3) Net income attributable to common units ā ā 54 ā ā 72 ā ā 145 ā ā 166 Weighted average common units outstanding (millions) ā 71.3 ā ā 71.3 ā 71.3 ā ā 71.2 Net income per common unit ā basic and diluted ā $ 0.75 ā $ 1.00 ā $ 2.03 ā $ 2.33 ā |
CASH DISTRIBUTIONS PAID TO COMM
CASH DISTRIBUTIONS PAID TO COMMON UNITS | 6 Months Ended |
Jun. 30, 2019 | |
CASH DISTRIBUTIONS PAID TO COMMON UNITS | |
CASH DISTRIBUTIONS PAID TO COMMON UNITS | NOTE 10 CASH DISTRIBUTIONS PAID TO COMMON UNITS ā 2019 ā During the three and six months ended June 30, 2019, the Partnership distributed $0.65 and $1.30 per common unit, respectively, for a total of $47 million and $95 million, respectively. ā The total distribution paid above includes our General Partnerās share during the three and six months ended June 30, 2019 for its two percent general partner interest, which was $1 million and $2 million, respectively. The General Partner did not receive any distributions in respect of its IDRs during the three and six months ended June 30, 2019. ā 2018 ā During the three and six months ended June 30, 2018, the Partnership distributed $0.65 and $1.65 per common unit, respectively, for a total of $47 million and $123 million, respectively. ā The total distribution paid above includes our General Partnerās share during the three and six months ended June 30, 2018 for its two percent general partner interest, which was $1 million and $3 million, respectively. The distributions paid to our General Partner in respect of IDRs during the three and six months ended June 30, 2018 were nil and $3 million, respectively. |
CHANGE IN OPERATING WORKING CAP
CHANGE IN OPERATING WORKING CAPITAL | 6 Months Ended |
Jun. 30, 2019 | |
CHANGE IN OPERATING WORKING CAPITAL | |
CHANGE IN OPERATING WORKING CAPITAL | NOTE 11 CHANGE IN OPERATING WORKING CAPITAL ā ā ā ā ā ā (unaudited) ā Six months ended June 30, (millions of dollars) 2019 2018 ā ā ā ā ā Change in accounts receivable and other 15 2 Change in inventories ā (1) ā ā Change in other current assets ā 3 ā (1) Change in accounts payable and accrued liabilities (12) ā (6) Change in accrued interest (1) ā Change in operating working capital 4 (5) ā |
RELATED PARTY TRANSACTIONS
RELATED PARTY TRANSACTIONS | 6 Months Ended |
Jun. 30, 2019 | |
RELATED PARTY TRANSACTIONS | |
RELATED PARTY TRANSACTIONS | NOTE 12 RELATED PARTY TRANSACTIONS ā The Partnership does not have any employees. The management and operating functions are provided by the General Partner. The General Partner does not receive a management fee in connection with its management of the Partnership. The Partnership reimburses the General Partner for all costs of services provided, including the costs of employee, officer and director compensation and benefits, and all other expenses necessary or appropriate to conduct the business of, and allocable to, the Partnership. Such costs include (i) overhead costs (such as office space and equipment) and (ii) out-of-pocket expenses related to the provision of such services. The Partnership Agreement provides that the General Partner will determine the costs that are allocable to the Partnership in any reasonable manner determined by the General Partner in its sole discretion. For both the three and six months ended June 30, 2019 and 2018, total costs charged to the Partnership by the General Partner were $1 million and $2 million, respectively. ā As operator of our pipelines, except Iroquois and a certain portion of the PNGTS facilities, TC Energyās subsidiaries provide capital and operating services to our pipeline systems. TC Energyās subsidiaries incur costs on behalf of our pipeline systems, including, but not limited to, employee salary and benefit costs, and property and liability insurance costs. Iroquois does not receive any capital and operating services from TC Energy (Refer to Note 5). ā Capital and operating costs charged to our pipeline systems, except for Iroquois, for the three and six months ended June 30, 2019 and 2018 by TC Energyās subsidiaries and amounts payable to TC Energyās subsidiaries at June 30, 2019 and December 31, 2018 are summarized in the following tables: ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Capital and operating costs charged by TC Energyās subsidiaries to: ā ā ā ā ā ā ā ā Great Lakes (a) ā 12 ā 16 ā 23 ā 24 Northern Border (a) 10 9 19 18 GTN 11 8 21 16 Bison ā 1 1 3 North Baja 2 1 3 2 Tuscarora 1 1 2 2 PNGTS (a) ā 1 ā 2 ā 3 ā 4 Impact on the Partnershipās net income: ā ā ā ā ā ā ā ā Great Lakes 5 7 10 11 Northern Border 5 4 9 8 GTN 8 7 16 14 Bison ā 1 1 3 North Baja 1 1 2 2 Tuscarora ā 1 ā 1 ā 2 ā 2 PNGTS ā 1 ā 1 ā 2 ā 2 ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā Net amounts payable to TC Energyās subsidiaries are as follows: ā ā ā ā Great Lakes (a) 5 3 Northern Border (a) 4 3 GTN 4 4 Bison ā ā ā 1 North Baja 1 ā Tuscarora ā 1 PNGTS (a) ā 1 ā 1 (a) Represents 100 percent of the costs. ā Great Lakes ā Great Lakes earns significant transportation revenues from TC Energy and its affiliates, some of which are provided at discounted rates and some at maximum recourse rates. For the three and six months ended June 30, 2019, Great Lakes earned 73 percent of its transportation revenues from TC Energy and its affiliates (June 30, 2018 - 72 percent and 70 percent, respectively). ā At June 30, 2019, $13 million was included in Great Lakesā receivables with regard to the transportation contracts with TC Energy and its affiliates (December 31, 2018 - $18 million). ā During the second quarter of 2018, Great Lakes reached an agreement on the terms of new long-term transportation capacity contracts with its affiliate, ANR Pipeline Company. The contracts are for a term of 15 years from November 2021 to October 31, 2036 with a total contract value of approximately $1.3 billion. The contracts contain reduction options (i) at any time on or before April 1, 2019 for any reason and (ii) any time before April 2021, if TC Energy is not able to secure the required regulatory approval related to anticipated expansion projects. During the first quarter of 2019, Great Lakes reached an agreement to amend volume reduction āfor any reasonā option by extending the period āon or beforeā April 1, 2019 to āon or beforeā April 1, 2020. All the other terms remained the same. ā PNGTS ā PNGTS earns transportation revenues from TC Energy and its affiliates. For the three and six months ended June 30, 2019, PNGTS earned approximately nil of its transportation revenues from TC Energy and its affiliates (June 30, 2018 - $1 million). ā At June 30, 2019, nil was included in PNGTS' outstanding receivables with regard to the transportation contracts with TC Energy and its affiliates (December 31, 2018 ā nil). ā In connection with the Portland XPress expansion project, PNGTS has entered into an arrangement with its affiliates regarding the construction of certain facilities on their systems that will be required to fulfill future contracts on the PNGTS system. In the event the anticipated developments do not proceed, PNGTS will be required to reimburse its affiliates for any costs incurred related to the development of these facilities. At June 30, 2019, the total costs incurred by these affiliates was approximately $99 million. |
FAIR VALUE MEASUREMENTS
FAIR VALUE MEASUREMENTS | 6 Months Ended |
Jun. 30, 2019 | |
FAIR VALUE MEASUREMENTS | |
FAIR VALUE MEASUREMENTS | NOTE 13 FAIR VALUE MEASUREMENTS ā (a) Fair Value Hierarchy ā Under Accounting Standards Codification (ASC) 820, Fair Value Measurements and Disclosures ā ā Level 1 inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that we have the ability to access at the measurement date. ā Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. ā Level 3 inputs are unobservable inputs for the asset or liability. ā 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, managementās best estimate is used. ā (b) Fair Value of Financial Instruments ā The carrying value of ācash and cash equivalentsā, āaccounts receivable and otherā, āaccounts payable and accrued liabilitiesā, āaccounts payable to affiliatesā and āaccrued interestā approximate their fair values because of the short maturity or duration of these instruments, or because the instruments bear a variable rate of interest or a rate that approximates current rates. The fair value of the Partnershipās debt is estimated by discounting the future cash flows of each instrument at estimated current borrowing rates. The fair value of interest rate derivatives is calculated using the income approach, which uses period-end market rates and applies a discounted cash flow valuation model. ā The Partnership has classified the fair value of natural gas imbalances as a Level 2 of the fair value hierarchy for fair value disclosure purposes, as the valuation approach includes quoted prices in the market index and observable volumes for the imbalance. ā Long-term debt is recorded at amortized cost and classified as Level 2 of the fair value hierarchy for fair value disclosure purposes. Interest rate derivative assets and liabilities are classified as Level 2 for all periods presented where the fair value is determined by using valuation techniques that refer to observable market data or estimated market prices. The estimated fair value of the Partnershipās debt as at June 30, 2019 and December 31, 2018 was $2,064 million and $2,101 million, respectively. ā Market risk is the risk that changes in market interest rates may result in fluctuations in the fair values or cash flows of financial instruments. The Partnershipās floating rate debt is subject to LIBOR benchmark interest rate risk. The Partnership uses derivatives to manage its exposure to interest rate risk. We regularly assess the impact of interest rate fluctuations on future cash flows and evaluate hedging opportunities to mitigate our interest rate risk. ā The Partnershipās interest rate swaps mature on October 2, 2022 and are structured such that the cash flows of the derivative instruments match those of the variable rate of interest on the 2013 Term Loan Facility. The fixed weighted average interest rate on these instruments is 3.26 percent. On June 26, 2019, in conjunction with the Partnershipās $50 million repayment on its 2013 Term Loan Facility, the Partnership also terminated an equivalent amount in interest rate swaps that were used to hedge this facility at an unwind rate of 2.81% (See also Note 7). ā At June 30, 2019, the fair value of the interest rate swaps accounted for as cash flow hedges was a liability ā The change in fair value of interest rate derivative instruments recognized in other comprehensive income was a loss of $9 million and $14 million for the three and six months ended June 30, 2019, respectively (June 30, 2018 - loss of $1 million and gain of $6 million, respectively). During the three and six months ended June 30, 2019, a gain of $1 million was reclassified from other comprehensive income to net income (June 30, 2018 - gain of $3 million). For the three and six months ended June 30, 2019, the net realized gain related to the interest rate swaps was nil and $1 million, respectively, and was included in āfinancial charges and otherā (June 30, 2018 - gain of $1 million and $2 million, respectively) (Refer to Note 15). ā The Partnership has no master netting agreements; however, it has derivative contracts containing provisions with rights of offset. The Partnership has elected to present the fair value of derivative instruments with the right to offset on a gross basis in the consolidated balance sheet. Had the Partnership elected to present these instruments on a net basis, there would be no effect on the consolidated balance sheet as of June 30, 2019 and December 31, 2018. |
ACCOUNTS RECEIVABLE AND OTHER
ACCOUNTS RECEIVABLE AND OTHER | 6 Months Ended |
Jun. 30, 2019 | |
ACCOUNTS RECEIVABLE AND OTHER | |
ACCOUNTS RECEIVABLE AND OTHER | NOTE 14 ACCOUNTS RECEIVABLE AND OTHER ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā Trade accounts receivable, net of allowance of nil 31 44 Imbalance receivable from affiliates ā 1 ā 2 Other 1 2 ā 33 48 ā |
FINANCIAL CHARGES AND OTHER
FINANCIAL CHARGES AND OTHER | 6 Months Ended |
Jun. 30, 2019 | |
FINANCIAL CHARGES AND OTHER | |
FINANCIAL CHARGES AND OTHER | NOTE 15 FINANCIAL CHARGES AND OTHER ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Interest expense (a) ā 22 ā 24 45 48 PNGTS' amortization of loss on derivative instruments ā ā ā 2 ā ā ā 2 Net realized gain related to the interest rate swaps ā ā (1) (1) (2) Other income ā (1) ā (2) ā (1) ā (2) ā 21 ā 23 43 ā 46 (a) Includes amortization of debt issuance costs and discount costs. |
VARIABLE INTEREST ENTITIES
VARIABLE INTEREST ENTITIES | 6 Months Ended |
Jun. 30, 2019 | |
VARIABLE INTEREST ENTITIES | |
VARIABLE INTEREST ENTITIES | NOTE 16 VARIABLE INTEREST ENTITIES ā In the normal course of business, the Partnership must re-evaluate its legal entities under the current consolidation guidance to determine if those that are considered to be VIEs are appropriately consolidated or if they should be accounted for differently under GAAP. A VIE is a legal entity that does not have sufficient equity at risk to finance its activities without additional subordinated financial support or is structured such that equity investors lack the ability to make significant decisions relating to the entityās operations through voting rights or do not substantively participate in the gains or losses of the entity. A VIE is appropriately consolidated if the Partnership is considered to be the primary beneficiary. The VIEās primary beneficiary is the entity that has both (1) the power to direct the activities of the VIE that most significantly impact the VIEs economic performance and (2) the obligation to absorb losses or the right to receive benefits from the VIE that could potentially be significant to the VIE. ā As a result of its analysis, the Partnership continues to consolidate all legal entities in which it has a variable interest and for which it is considered to be the primary beneficiary. VIEs where the Partnership is not the primary beneficiary, but has a variable interest in the entity, are accounted for as equity investments. ā Consolidated VIEs ā The Partnershipās consolidated VIEs consist of the intermediate partnerships and mainly the Partnershipās ILPs that hold interests in the Partnershipās pipeline systems. After considering the purpose and design of the ILPs and the risks that they were designed to create and pass through to the Partnership, the Partnership has concluded that it is the primary beneficiary of these ILPs because of the significant amount of variability it absorbs from the ILPsā economic performance. ā The assets and liabilities held through these VIEs that are not available to creditors of the Partnership and whose investors have no recourse to the credit of the Partnership are held through GTN, Tuscarora, Northern Border, Great Lakes, PNGTS, Iroquois and North Baja due to their third party debt. The following table presents the total assets and liabilities of these entities that are included in the Partnershipās consolidated balance sheets: ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS (LIABILITIES) (a) ā ā ā ā Cash and cash equivalents ā 14 ā 16 Accounts receivable and other ā 29 ā 39 Inventories ā 9 ā 8 Other current assets ā 3 ā 6 Equity investments ā 1,118 ā 1,196 Property, plant and equipment, net ā 1,240 ā 1,240 Other assets ā 1 ā 1 Accounts payable and accrued liabilities ā (22) ā (33) Accounts payable to affiliates, net ā (87) ā (40) Accrued interest ā (2) ā (2) Current portion of long-term debt ā (101) ā (36) Long-term debt ā (251) ā (341) Other liabilities ā (28) ā (27) Deferred state income tax ā (9) ā (9) (a) Bison, an asset held through our consolidated VIEs, is excluded at June 30, 2019 and at December 31, 2018 as the assets of this entity can be used for purposes other than the settlement of the VIEās obligations. |
SUBSEQUENT EVENTS
SUBSEQUENT EVENTS | 6 Months Ended |
Jun. 30, 2019 | |
SUBSEQUENT EVENTS | |
SUBSEQUENT EVENTS | NOTE 17 SUBSEQUENT EVENTS ā Management of the Partnership has reviewed subsequent events through August 1, 2019, the date the consolidated financial statements were issued, and concluded there were no events or transactions during this period that would require recognition or disclosure in the consolidated financial statements other than what is disclosed here and/or those already disclosed in the preceding notes. ā On July 23, 2019, the board of directors of the General Partner declared the Partnershipās second quarter 2019 cash distribution in the amount of $0.65 per common unit payable on August 14, 2019 to unitholders of record as of August 2, 2019. The declared distribution totaled $47 million and is payable in the following manner: $46 million to common unitholders (including $4 million to the General Partner as a holder of 5,797,106 common units and $7 million to another subsidiary of TC Energy as holder of 11,287,725 common units) and $1 million to the General Partner for its two percent general partner interest. The General Partner did not receive any distributions in respect of its IDRs for the second quarter of 2019. ā Northern Border declared its June 2019 distribution of $15 million on July 8, 2019, of which the Partnership received its 50 percent share or $7 million on July 31, 2019. ā Great Lakes declared its second quarter 2019 distribution of $20 million on July 16, 2019, of which the Partnership received its 46.45 percent share or $9 million on August 1, 2019. ā Iroquois declared its second quarter 2019 distribution of $28 million on July 24, 2019, of which the Partnership received its 49.34 percent share or $14 million on August 1, 2019. The $14 million includes our proportionate share of Iroquoisā unrestricted cash amounting to $2.6 million (Refer to Note 5). ā PNGTS declared its second quarter 2019 distribution of $7 million on July 12, 2019, of which $3 million was paid to its non-controlling interest owner on August 1, 2019. ā |
SIGNIFICANT ACCOUNTING POLICI_2
SIGNIFICANT ACCOUNTING POLICIES (Policies) | 6 Months Ended |
Jun. 30, 2019 | |
SIGNIFICANT ACCOUNTING POLICIES | |
Basis of Presentation - Consolidation and equity method of accounting | Basis of Presentation ā The Partnership consolidates its interests in entities over which it is able to exercise control. To the extent there are interests owned by other parties, these interests are included as non-controlling interests. The Partnership uses the equity method of accounting for its investments in entities over which it is able to exercise significant influence. |
Basis of Presentation - Transactions between entities under common control | Acquisitions by the Partnership from TC Energy are considered common control transactions. If businesses are acquired from TC Energy that will be consolidated by the Partnership, the historical consolidated financial statements are required to be recast, except net income per common unit, to include the acquired entities for all periods presented. ā If the Partnership acquires an asset or an investment from TC Energy, which will be accounted for by the equity method, the financial information is not required to be recast and the transaction is accounted for prospectively from the date of the acquisition. ā U.S. federal and certain state income taxes are the responsibility of the partners and are not reflected in these consolidated financial statements. The tax effect of the Partnership's activities accrues to its partners. The Partnershipās taxable income or loss, which may vary substantially from the net income or loss reported in the consolidated statement of operations, is includable in the U.S. federal income tax returns of each partner. ā In instances where the Partnershipās consolidated entities are subject to state income taxes, the asset-liability method is used to account for taxes. This method requires recognition of deferred tax assets and liabilities for future tax consequences attributable to the differences between the financial statement carrying amount of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are classified as non-current on our consolidated balance sheets. |
Use of Estimates | Use of Estimates ā The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities, if any, as of the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Although management believes these estimates are reasonable, actual results could differ from these estimates. |
EQUITY INVESTMENTS (Tables)
EQUITY INVESTMENTS (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
EQUITY INVESTMENTS | |
Schedule of equity investments and summarized financial information for equity investees | ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā Ownership ā Equity Earnings ā Equity Investments ā ā Interest at ā Three months ended ā Six months ended ā ā ā ā (unaudited) ā June 30, ā June 30, ā June 30, ā June 30, ā December 31, (millions of dollars) 2019 2019 2018 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā Northern Border ā 50 % 14 15 ā 35 32 ā 431 ā 497 Great Lakes ā 46.45 % 9 ā 12 ā 29 ā 36 ā 484 ā 489 Iroquois ā 49.34 % 7 9 ā 20 27 ā 203 ā 210 ā ā ā 30 36 ā 84 95 ā 1,118 ā 1,196 ā |
Northern Border | |
EQUITY INVESTMENTS | |
Schedule of equity investments and summarized financial information for equity investees | ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS ā ā ā ā Cash and cash equivalents 26 10 Other current assets 33 36 Property, plant and equipment, net 1,008 1,037 Other assets 13 13 ā 1,080 1,096 ā ā ā ā ā LIABILITIES AND PARTNERSā EQUITY ā ā ā ā Current liabilities 46 34 Deferred credits and other 37 35 Long-term debt, net (a) 365 264 Partnersā equity ā ā ā ā Partnersā capital 633 764 Accumulated other comprehensive loss (1) (1) ā 1,080 1,096 ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Transmission revenues 67 68 148 140 Operating expenses (20) (19) (40) (38) Depreciation (16) (15) (31) (30) Financial charges and other (4) (4) (8) (7) Net income 27 30 69 65 (a) No current maturities as of June 30, 2019 and December 31, 2018. At June 30, 2019, Northern Border is in compliance with all its financial covenants. |
Great Lakes | |
EQUITY INVESTMENTS | |
Schedule of equity investments and summarized financial information for equity investees | ā ā ā ā ā ā (unaudited) ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS ā ā ā ā Current assets 56 75 Property, plant and equipment, net 687 689 ā 743 764 ā ā ā ā ā LIABILITIES AND PARTNERSā EQUITY ā ā ā ā Current liabilities 26 26 Net long-term debt, including current maturities (a) 229 240 Other long term liabilities ā 4 ā 4 Partners' equity 484 494 ā 743 764 ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Transmission revenues 51 53 123 134 Operating expenses (19) (15) (35) (32) Depreciation (8) ā (8) (16) (16) Financial charges and other (5) (5) (9) (9) Net income 19 25 63 77 (a) Includes current maturities of $21 million as of June 30, 2019 and as of December 31, 2018. At June 30, 2019, Great Lakes is in compliance with all its financial covenants. |
Iroquois | |
EQUITY INVESTMENTS | |
Schedule of equity investments and summarized financial information for equity investees | ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS Cash and cash equivalents 73 80 Other current assets 25 32 Property, plant and equipment, net 573 581 Other assets 14 8 ā 685 701 ā ā ā ā ā LIABILITIES AND PARTNERSā EQUITY ā ā Current liabilities 15 19 Long-term debt, net (a) 319 325 Other non-current liabilities 21 14 Partners' equity 330 343 ā 685 701 ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Transmission revenues 40 ā 44 ā 92 ā 105 Operating expenses (13) ā (14) ā (28) ā (28) Depreciation (8) ā (7) ā (15) ā (15) Financial charges and other (4) ā (4) ā (7) ā (7) Net income 15 ā 19 ā 42 ā 55 (a) Includes current maturities of $4 million as of June 30, 2019 (December 31, 2018 - $146 million). At June 30, 2019, Iroquois is in compliance with all its financial covenants . |
DEBT AND CREDIT FACILITIES (Tab
DEBT AND CREDIT FACILITIES (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
DEBT AND CREDIT FACILITIES | |
Schedule of debt and credit facilities | ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā ā Weighted Average ā Weighted Average ā ā ā ā Interest Rate for the ā ā ā Interest Rate for the (unaudited) ā ā ā Six Months Ended ā December 31, ā Year Ended (millions of dollars) ā June 30, 2019 ā June 30, 2019 ā 2018 ā December 31, 2018 TC PipeLines, LP ā ā ā ā ā ā ā ā ā ā ā ā Senior Credit Facility due 2021 ā 3.61 % ā ā 40 ā 3.14 % ā 2013 Term Loan Facility due 2022 450 3.73 % ā ā 500 ā 3.23 % ā 4.65% Unsecured Senior Notes due 2021 350 4.65 % (a) ā 350 ā 4.65 % (a) 4.375% Unsecured Senior Notes due 2025 ā 350 ā 4.375 % (a) ā 350 ā 4.375 % (a) 3.90 % Unsecured Senior Notes due 2027 ā 500 ā 3.90 % (a) ā 500 ā 3.90 % (a) GTN ā ā ā ā ā ā ā ā ā ā ā ā 5.29% Unsecured Senior Notes due 2020 100 5.29 % (a) ā 100 ā 5.29 % (a) 5.69% Unsecured Senior Notes due 2035 150 5.69 % (a) ā 150 ā 5.69 % (a) Unsecured Term Loan Facility due 2019 ā ā ā ā ā ā ā 35 ā 2.93 % ā PNGTS ā ā ā ā ā ā ā ā ā ā ā ā Revolving Credit Facility due 2023 ā 29 ā 3.74 % ā ā 19 ā 3.55 % ā Tuscarora ā ā ā ā ā ā ā ā ā ā ā ā Unsecured Term Loan due 2020 ā 24 ā 3.62 % ā ā 24 ā 3.10 % ā North Baja ā ā ā ā ā ā ā ā ā ā ā ā Unsecured Term Loan due 2021 ā 50 ā 3.56 % ā ā 50 ā 3.54 % ā ā 2,003 ā ā ā 2,118 ā ā ā ā Less: unamortized debt issuance costs and debt discount ā 10 ā ā ā ā ā 10 ā ā ā ā Less: current portion 101 ā ā ā ā 36 ā ā ā ā ā 1,892 ā ā ā 2,072 ā ā ā ā (a) Fixed interest rate |
Schedule of principal repayments required on debt | ā ā ā ā (unaudited) ā ā (millions of dollars) Principal Payments 2019 1 2020 123 2021 400 2022 450 2023 ā 29 Thereafter 1,000 ā 2,003 ā |
NET INCOME PER COMMON UNIT (Tab
NET INCOME PER COMMON UNIT (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
NET INCOME PER COMMON UNIT | |
Schedule of net income per common unit | ā ā ā ā ā ā ā ā ā ā ā ā ā ā (unaudited) ā Three months ended June 30, ā Six months ended June 30, (millions of dollars, except per common unit amounts) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā ā ā ā ā Net income attributable to controlling interests ā 55 ā ā 73 ā 148 ā ā 169 Net income attributable to the General Partner ā ā (1) ā ā (1) ā ā (3) ā ā (3) Net income attributable to common units ā ā 54 ā ā 72 ā ā 145 ā ā 166 Weighted average common units outstanding (millions) ā 71.3 ā ā 71.3 ā 71.3 ā ā 71.2 Net income per common unit ā basic and diluted ā $ 0.75 ā $ 1.00 ā $ 2.03 ā $ 2.33 ā |
CHANGE IN OPERATING WORKING C_2
CHANGE IN OPERATING WORKING CAPITAL (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
CHANGE IN OPERATING WORKING CAPITAL | |
Schedule of change in operating working capital | ā ā ā ā ā ā (unaudited) ā Six months ended June 30, (millions of dollars) 2019 2018 ā ā ā ā ā Change in accounts receivable and other 15 2 Change in inventories ā (1) ā ā Change in other current assets ā 3 ā (1) Change in accounts payable and accrued liabilities (12) ā (6) Change in accrued interest (1) ā Change in operating working capital 4 (5) ā |
RELATED PARTY TRANSACTIONS (Tab
RELATED PARTY TRANSACTIONS (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
RELATED PARTY TRANSACTIONS | |
Summary of capital and operating costs charged to pipeline systems by related party | ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Capital and operating costs charged by TC Energyās subsidiaries to: ā ā ā ā ā ā ā ā Great Lakes (a) ā 12 ā 16 ā 23 ā 24 Northern Border (a) 10 9 19 18 GTN 11 8 21 16 Bison ā 1 1 3 North Baja 2 1 3 2 Tuscarora 1 1 2 2 PNGTS (a) ā 1 ā 2 ā 3 ā 4 Impact on the Partnershipās net income: ā ā ā ā ā ā ā ā Great Lakes 5 7 10 11 Northern Border 5 4 9 8 GTN 8 7 16 14 Bison ā 1 1 3 North Baja 1 1 2 2 Tuscarora ā 1 ā 1 ā 2 ā 2 PNGTS ā 1 ā 1 ā 2 ā 2 (a) Represents 100 percent of the costs. |
Summary of amount payable to related party for costs charged | ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā Net amounts payable to TC Energyās subsidiaries are as follows: ā ā ā ā Great Lakes (a) 5 3 Northern Border (a) 4 3 GTN 4 4 Bison ā ā ā 1 North Baja 1 ā Tuscarora ā 1 PNGTS (a) ā 1 ā 1 (a) Represents 100 percent of the costs. |
ACCOUNTS RECEIVABLE AND OTHER (
ACCOUNTS RECEIVABLE AND OTHER (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
ACCOUNTS RECEIVABLE AND OTHER | |
Schedule of accounts receivable and other | ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā Trade accounts receivable, net of allowance of nil 31 44 Imbalance receivable from affiliates ā 1 ā 2 Other 1 2 ā 33 48 ā |
FINANCIAL CHARGES AND OTHER (Ta
FINANCIAL CHARGES AND OTHER (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
FINANCIAL CHARGES AND OTHER | |
Schedule of components of financial charges and other | ā ā ā ā ā ā ā ā ā ā ā ā Three months ended ā Six months ended (unaudited) ā June 30, ā June 30, (millions of dollars) 2019 2018 2019 2018 ā ā ā ā ā ā ā ā ā Interest expense (a) ā 22 ā 24 45 48 PNGTS' amortization of loss on derivative instruments ā ā ā 2 ā ā ā 2 Net realized gain related to the interest rate swaps ā ā (1) (1) (2) Other income ā (1) ā (2) ā (1) ā (2) ā 21 ā 23 43 ā 46 (a) Includes amortization of debt issuance costs and discount costs. |
VARIABLE INTEREST ENTITIES (Tab
VARIABLE INTEREST ENTITIES (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
VARIABLE INTEREST ENTITIES | |
Schedule of assets and liabilities held through VIEs whose assets cannot be used for purposes other settlement of their obligations | ā ā ā ā ā ā (unaudited) ā ā ā ā (millions of dollars) June 30, 2019 December 31, 2018 ā ā ā ā ā ASSETS (LIABILITIES) (a) ā ā ā ā Cash and cash equivalents ā 14 ā 16 Accounts receivable and other ā 29 ā 39 Inventories ā 9 ā 8 Other current assets ā 3 ā 6 Equity investments ā 1,118 ā 1,196 Property, plant and equipment, net ā 1,240 ā 1,240 Other assets ā 1 ā 1 Accounts payable and accrued liabilities ā (22) ā (33) Accounts payable to affiliates, net ā (87) ā (40) Accrued interest ā (2) ā (2) Current portion of long-term debt ā (101) ā (36) Long-term debt ā (251) ā (341) Other liabilities ā (28) ā (27) Deferred state income tax ā (9) ā (9) (a) Bison, an asset held through our consolidated VIEs, is excluded at June 30, 2019 and at December 31, 2018 as the assets of this entity can be used for purposes other than the settlement of the VIEās obligations. |
ORGANIZATION - Ownership Intere
ORGANIZATION - Ownership Interests in Natural Gas Pipeline Systems (Details) | 6 Months Ended |
Jun. 30, 2019LimitedPartnership | |
ORGANIZATION | |
Number of intermediate limited partnerships through which pipeline assets are owned | 3 |
ACCOUNTING PRONOUNCEMENTS - Lea
ACCOUNTING PRONOUNCEMENTS - Leases (Details) - USD ($) $ in Millions | Jun. 30, 2019 | Jan. 01, 2019 |
ACCOUNTING PRONOUNCEMENTS | ||
Operating ROU assets | $ 0.5 | $ 0.6 |
Operating lease liabilities | $ 0.5 | $ 0.6 |
Weighted average remaining term (in years) | 2 years 4 months 28 days | |
Discount rate (in percent) | 3.57% |
REGULATORY (Details)
REGULATORY (Details) - FERC - item | Feb. 28, 2029 | Apr. 04, 2019 | Mar. 15, 2019 | Feb. 28, 2019 |
Iroquois | ||||
REGULATORY | ||||
Reduction of existing maximum system rates (as a percent) | 6.50% | 6.50% | ||
Number phases of reduction of rates | 2 | |||
Reduction of existing maximum system rates effective March 1,2019 (as a percent) | 3.25% | |||
Reduction of existing maximum system rates effective April 1,2020 (as a percent) | 3.25% | |||
Tuscarora Settlement | ||||
REGULATORY | ||||
Reduction of existing maximum system rates (as a percent) | 1.70% | |||
Additional decrease of unit rate (as a percent) | 10.80% | |||
Northern Border | ||||
REGULATORY | ||||
Decrease in rate (as a percent) | 2.00% |
EQUITY INVESTMENTS (Details)
EQUITY INVESTMENTS (Details) - USD ($) $ in Millions | Aug. 31, 2019 | Aug. 01, 2019 | Jul. 31, 2019 | Jun. 26, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Jun. 26, 2029 | Dec. 31, 2018 |
EQUITY INVESTMENTS | |||||||||||
Equity Earnings | $ 30 | $ 36 | $ 84 | $ 95 | |||||||
Equity Investments | 1,118 | 1,118 | $ 1,196 | ||||||||
Equity contribution | 5 | 4 | |||||||||
Distributions from Equity Investments | |||||||||||
Distributions received from equity investments | 108 | 56 | 167 | 101 | |||||||
Distributions from equity investments | 112 | 96 | |||||||||
Return on investment distribution classified as investing activities | 52.6 | 55.2 | |||||||||
Northern Border | |||||||||||
EQUITY INVESTMENTS | |||||||||||
Special distribution from equity investments | 100 | ||||||||||
Borrowings under the revolving credit facility | $ 100 | ||||||||||
Distribution financed by borrowings (as a percent) | 100.00% | ||||||||||
Northern Border | Revolving credit facility | |||||||||||
EQUITY INVESTMENTS | |||||||||||
Maximum borrowing capacity | $ 200 | ||||||||||
Great Lakes | |||||||||||
EQUITY INVESTMENTS | |||||||||||
Total cash call issued to fund debt repayment | 11 | ||||||||||
Iroquois | |||||||||||
Distributions from Equity Investments | |||||||||||
Distributions from equity investments | $ 14 | 14 | 14 | 28 | 28 | ||||||
Return on investment distribution classified as investing activities | $ 2.6 | $ 2.6 | 2.6 | $ 5.2 | 5.2 | ||||||
Limited partners, Distribution declared | $ 28 | ||||||||||
Northern Border | |||||||||||
EQUITY INVESTMENTS | |||||||||||
Ownership interest (as a percent) | 50.00% | 50.00% | |||||||||
Equity Earnings | $ 14 | 15 | $ 35 | 32 | |||||||
Equity Investments | 431 | 431 | 497 | ||||||||
ASSETS | |||||||||||
Cash and cash equivalents | 26 | 26 | 10 | ||||||||
Other current assets | 33 | 33 | 36 | ||||||||
Property, plant and equipment, net | 1,008 | 1,008 | 1,037 | ||||||||
Other assets | 13 | 13 | 13 | ||||||||
Assets, total | 1,080 | 1,080 | 1,096 | ||||||||
LIABILITIES AND PARTNERS' EQUITY | |||||||||||
Current liabilities | 46 | 46 | 34 | ||||||||
Deferred credits and other | 37 | 37 | 35 | ||||||||
Net long-term debt, including current maturities | 365 | 365 | 264 | ||||||||
Partners' capital | 633 | 633 | 764 | ||||||||
Accumulated other comprehensive loss | (1) | (1) | (1) | ||||||||
Liabilities and Partners' Equity, total | 1,080 | 1,080 | 1,096 | ||||||||
Revenues (expenses) | |||||||||||
Transmission revenues | 67 | 68 | 148 | 140 | |||||||
Operating expenses | (20) | (19) | (40) | (38) | |||||||
Depreciation | (16) | (15) | (31) | (30) | |||||||
Financial charges and other | (4) | (4) | (8) | (7) | |||||||
Net income | 27 | 30 | 69 | 65 | |||||||
Long-term debt current maturities | 0 | 0 | 0 | ||||||||
Distributions from Equity Investments | |||||||||||
Distributions received from equity investments | $ 72 | 17 | 100 | 39 | |||||||
Return on investment distribution classified as investing activities | $ 50 | ||||||||||
Great Lakes | |||||||||||
EQUITY INVESTMENTS | |||||||||||
Ownership interest (as a percent) | 46.45% | 46.45% | |||||||||
Equity Earnings | $ 9 | 12 | $ 29 | 36 | |||||||
Equity Investments | 484 | 484 | 489 | ||||||||
Equity contribution | $ 5 | 4 | |||||||||
ASSETS | |||||||||||
Current assets | 56 | 56 | 75 | ||||||||
Property, plant and equipment, net | 687 | 687 | 689 | ||||||||
Assets, total | 743 | 743 | 764 | ||||||||
LIABILITIES AND PARTNERS' EQUITY | |||||||||||
Current liabilities | 26 | 26 | 26 | ||||||||
Net long-term debt, including current maturities | 229 | 229 | 240 | ||||||||
Other non-current liabilities | 4 | 4 | 4 | ||||||||
Partners' capital | 484 | 484 | 494 | ||||||||
Liabilities and Partners' Equity, total | 743 | 743 | 764 | ||||||||
Revenues (expenses) | |||||||||||
Transmission revenues | 51 | 53 | 123 | 134 | |||||||
Operating expenses | (19) | (15) | (35) | (32) | |||||||
Depreciation | (8) | (8) | (16) | (16) | |||||||
Financial charges and other | (5) | (5) | (9) | (9) | |||||||
Net income | 19 | 25 | 63 | 77 | |||||||
Long-term debt current maturities | $ 21 | $ 21 | 21 | ||||||||
Iroquois | |||||||||||
EQUITY INVESTMENTS | |||||||||||
Ownership interest (as a percent) | 49.34% | 49.34% | 49.34% | 49.34% | |||||||
Equity Earnings | $ 7 | 9 | $ 20 | 27 | |||||||
Equity Investments | 203 | 203 | 210 | ||||||||
ASSETS | |||||||||||
Cash and cash equivalents | 73 | 73 | 80 | ||||||||
Other current assets | 25 | 25 | 32 | ||||||||
Property, plant and equipment, net | 573 | 573 | 581 | ||||||||
Other assets | 14 | 14 | 8 | ||||||||
Assets, total | 685 | 685 | 701 | ||||||||
LIABILITIES AND PARTNERS' EQUITY | |||||||||||
Current liabilities | 15 | 15 | 19 | ||||||||
Net long-term debt, including current maturities | 319 | 319 | 325 | ||||||||
Other non-current liabilities | 21 | 21 | 14 | ||||||||
Partners' capital | 330 | 330 | 343 | ||||||||
Liabilities and Partners' Equity, total | 685 | 685 | 701 | ||||||||
Revenues (expenses) | |||||||||||
Transmission revenues | 40 | 44 | 92 | 105 | |||||||
Operating expenses | (13) | (14) | (28) | (28) | |||||||
Depreciation | (8) | (7) | (15) | (15) | |||||||
Financial charges and other | (4) | (4) | (7) | (7) | |||||||
Net income | 15 | $ 19 | 42 | 55 | |||||||
Long-term debt current maturities | $ 4 | 4 | $ 146 | ||||||||
Distributions from Equity Investments | |||||||||||
Return on investment distribution classified as investing activities | $ 5 | $ 5 |
REVENUES - Contract Balances (D
REVENUES - Contract Balances (Details) - USD ($) $ in Millions | Jun. 30, 2019 | Dec. 31, 2018 |
Contract Balances | ||
Receivables from contracts with customers | $ 31 | $ 44 |
DEBT AND CREDIT FACILITIES - Am
DEBT AND CREDIT FACILITIES - Amounts Outstanding and Description of Terms (Details) - USD ($) $ in Millions | Jun. 26, 2019 | Jun. 30, 2019 | Jun. 30, 2019 | Dec. 31, 2018 |
Credit facilities, short-term loan facility and long-term debt | ||||
Total credit facilities, short-term loan facility and long-term debt | $ 2,003 | $ 2,003 | $ 2,118 | |
Less: unamortized debt issuance costs and debt discount | 10 | 10 | 10 | |
Less: current portion | 101 | 101 | 36 | |
Long-term debt | $ 1,892 | $ 1,892 | 2,072 | |
2013 Term Loan Facility | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Repayments of secured debt | $ 50 | |||
Unwind rate of interest rate swap (as a percent) | 2.81% | |||
Senior Credit Facility due in 2021 and the Term Loan Facilities due in 2022 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Leverage ratio, actual (as a percent) | 2.78% | 2.78% | ||
Senior Credit Facility due in 2021 and the Term Loan Facilities due in 2022 | Each fiscal quarter except fiscal quarter and the two following fiscal quarters in which one or more acquisitions has been executed | Maximum | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Leverage ratio, covenant (as a percent) | 5.00% | |||
Senior Credit Facility due in 2021 and the Term Loan Facilities due in 2022 | Fiscal quarter and the two following fiscal quarters in which one or more acquisitions has been executed | Maximum | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Leverage ratio, covenant (as a percent) | 5.50% | |||
Revolving credit facility | TC PipeLines, LP Senior Credit Facility due 2021 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 0 | $ 0 | $ 40 | |
Weighted average interest rate (as a percent) | 3.61% | 3.14% | ||
Maximum borrowing capacity | $ 500 | 500 | ||
Amount outstanding under credit facility | 0 | 0 | $ 40 | |
Revolving credit facility | TC PipeLines, LP Senior Credit Facility due 2021 | LIBOR | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt interest rate, at period end (as a percent) | 3.77% | |||
Term loan | TC PipeLines, LP 2013 Term Loan Facility due 2022 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 450 | $ 450 | $ 500 | |
Weighted average interest rate (as a percent) | 3.73% | 3.23% | ||
Term loan | TC PipeLines, LP 2013 Term Loan Facility due 2022 | LIBOR borrowings | LIBOR | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Stated interest rate (as a percent) | 3.60% | |||
Debt interest rate, at period end (as a percent) | 3.69% | 3.69% | ||
Term loan | TC PipeLines, LP 2013 Term Loan Facility due 2022 | LIBOR borrowings | LIBOR | Hedges of cash flows | Interest rate swaps | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Weighted average interest rate (as a percent) | 3.26% | 3.26% | ||
Unsecured debt | TC PipeLines, LP 4.65% Senior Notes due 2021 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 350 | $ 350 | $ 350 | |
Stated interest rate (as a percent) | 4.65% | 4.65% | ||
Weighted average interest rate (as a percent) | 4.65% | 4.65% | ||
Unsecured debt | TC PipeLines, LP 4.375% Senior Notes due 2025 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 350 | $ 350 | $ 350 | |
Stated interest rate (as a percent) | 4.375% | 4.375% | ||
Weighted average interest rate (as a percent) | 4.375% | 4.375% | ||
Unsecured debt | TC PipeLines, LP 3.90% Senior Notes due 2027 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 500 | $ 500 | $ 500 | |
Stated interest rate (as a percent) | 3.90% | 3.90% | ||
Weighted average interest rate (as a percent) | 3.90% | 3.90% | ||
Unsecured debt | GTN 5.29% Senior Notes due 2020 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Stated interest rate (as a percent) | 5.29% | 5.29% | ||
Unsecured debt | GTN 5.69% Senior Notes due 2035 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Stated interest rate (as a percent) | 5.69% | 5.69% | ||
Unsecured debt | Tuscarora Term Loan due 2020 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 24 | $ 24 | $ 24 | |
Weighted average interest rate (as a percent) | 3.62% | 3.10% | ||
Unsecured debt | North Baja Term Loan Due 2021 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 50 | $ 50 | $ 50 | |
Weighted average interest rate (as a percent) | 3.56% | 3.54% | ||
Unsecured debt | North Baja Term Loan Due 2021 | LIBOR | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt interest rate, at period end (as a percent) | 3.52% | 3.52% | 3.54% | |
GTN | Unsecured debt | GTN 5.29% Senior Notes due 2020 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 100 | $ 100 | $ 100 | |
Weighted average interest rate (as a percent) | 5.29% | 5.29% | ||
GTN | Unsecured debt | GTN 5.69% Senior Notes due 2035 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 150 | 150 | $ 150 | |
Weighted average interest rate (as a percent) | 5.69% | 5.69% | ||
GTN | Unsecured debt | Term Loan Facility due 2019 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 0 | $ 0 | $ 35 | |
Weighted average interest rate (as a percent) | 2.93% | |||
Percentage of debt to total capitalization, covenant | 39.90% | |||
GTN | Unsecured debt | Term Loan Facility due 2019 | Maximum | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Percentage of debt to total capitalization, covenant | 70.00% | |||
GTN | Unsecured debt | Term Loan Facility due 2019 | LIBOR | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt interest rate, at period end (as a percent) | 3.30% | |||
PNGTS | Secured debt | PNGTS Revolving Credit Facility due 2023 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt and credit facilities | $ 29 | $ 29 | $ 19 | |
Weighted average interest rate (as a percent) | 3.74% | 3.55% | ||
Leverage ratio, covenant (as a percent) | 0.50% | |||
PNGTS | Secured debt | PNGTS Revolving Credit Facility due 2023 | Maximum | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Leverage ratio, covenant (as a percent) | 5.00% | |||
PNGTS | Secured debt | PNGTS Revolving Credit Facility due 2023 | LIBOR | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt interest rate, at period end (as a percent) | 3.69% | 3.69% | 3.60% | |
Tuscarora | Unsecured debt | Tuscarora Term Loan due 2020 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt service coverage, covenant (as a percent) | 9.44% | |||
Tuscarora | Unsecured debt | Tuscarora Term Loan due 2020 | Minimum | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt service coverage, covenant (as a percent) | 3.00% | |||
Tuscarora | Unsecured debt | Tuscarora Term Loan due 2020 | LIBOR | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Debt interest rate, at period end (as a percent) | 3.57% | 3.57% | 3.47% | |
North Baja | Unsecured debt | North Baja Term Loan Due 2021 | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Percentage of debt to total capitalization, actual | 39.06% | 39.06% | ||
North Baja | Unsecured debt | North Baja Term Loan Due 2021 | Maximum | ||||
Credit facilities, short-term loan facility and long-term debt | ||||
Percentage of debt to total capitalization, covenant | 70.00% |
DEBT AND CREDIT FACILITIES - Pr
DEBT AND CREDIT FACILITIES - Principal Repayments Required (Details) $ in Millions | Jun. 30, 2019USD ($) |
Principal repayments required on debt | |
2019 | $ 1 |
2020 | 123 |
2021 | 400 |
2022 | 450 |
2023 | 29 |
Thereafter | 1,000 |
Total debt | $ 2,003 |
PARTNERS' EQUITY - ATM Equity I
PARTNERS' EQUITY - ATM Equity Issuance Program (Details) | 6 Months Ended |
Jun. 30, 2019shares | |
ATM Equity Issuance Program | Common Units | |
PARTNERS' EQUITY | |
Units sold | 0 |
PARTNERS' EQUITY - Class B Unit
PARTNERS' EQUITY - Class B Units (Details) - USD ($) $ / shares in Units, $ in Millions | 3 Months Ended | 6 Months Ended | 12 Months Ended | ||
Mar. 31, 2019 | Jun. 30, 2019 | Jun. 30, 2018 | Dec. 31, 2019 | Dec. 31, 2018 | |
PARTNERS' EQUITY | |||||
Limited Partners, Distributions paid | $ 13 | $ 15 | |||
Distributions | Class B Units | |||||
PARTNERS' EQUITY | |||||
Limited Partners, Distributions paid | $ 13 | ||||
TC Energy | Distributions | Class B Units | |||||
PARTNERS' EQUITY | |||||
Percentage of reduction in distributions payable | 35.00% | ||||
TC Energy | Distributions | Common Units | |||||
PARTNERS' EQUITY | |||||
Percentage of reduction in distributions payable | 35.00% | ||||
Minimum distribution payable per common unit | $ 3.94 | ||||
GTN | TC Energy | Distributions | Class B Units | |||||
PARTNERS' EQUITY | |||||
Portion of GTN's annual distributions to which the Class B units are entitled to receive a percentage share of the distributions above threshold (as a percent) | 30.00% | ||||
Percentage applied to 30 percent of GTN's distributions above threshold for the year ending December 31, 2019 | 100.00% | ||||
Threshold of GTN's total distributable cash flows for payment to Class B units for the year ending December 31, 2019 | $ 20 | ||||
Percentage applied to 30 percent of GTN's distributions above threshold for the year ending December 31, 2020 | 43.75% | ||||
Threshold of GTN's total distributable cash flows for payment to Class B units for the year ending December 31, 2020 | $ 20 | ||||
Percentage applied to 30 percent of GTN's distributions above threshold thereafter | 25.00% | ||||
Threshold of GTN's distributions for payment to Class B units | $ 20 | $ 20 | $ 20 |
NET INCOME PER COMMON UNIT - Ge
NET INCOME PER COMMON UNIT - General Partner Effective Interest and Allocated Incentive Distributions (Details) | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2029 | Jun. 30, 2019 | Jun. 30, 2018 | |
General Partner | General Partner | |||||
PARTNERS' EQUITY | |||||
General partner interest (as a percent) | 2.00% | 2.00% | 2.00% | 2.00% | 2.00% |
NET INCOME PER COMMON UNIT- Ter
NET INCOME PER COMMON UNIT- Terms of Class B Unit Distributions and Determination of Net Income (Loss) per Common Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | 12 Months Ended | |||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Dec. 31, 2019 | Dec. 31, 2018 | |
Net income per common unit | ||||||
Net income attributable to controlling interests | $ 55 | $ 73 | $ 148 | $ 169 | ||
Net income attributable to the General Partner | (1) | (1) | (3) | (3) | ||
Class B Units | ||||||
Net income per common unit | ||||||
Net income attributable to common units | 0 | 0 | 0 | 0 | ||
Common Units | ||||||
Net income per common unit | ||||||
Net income attributable to common units | $ 54 | $ 72 | $ 145 | $ 166 | ||
Weighted average common units outstanding - basic and diluted (in units) | 71.3 | 71.3 | 71.3 | 71.2 | ||
Net income (loss) per common unit - basic and diluted (in dollars per unit) | $ 0.75 | $ 1 | $ 2.03 | $ 2.33 | ||
GTN | Class B Units | TC Energy | Distributions | ||||||
Distributions | ||||||
Percentage applied to GTN's distributable cash flow | 30.00% | |||||
GTN's distributions for payment to Class B units | $ 20 | $ 20 | $ 20 |
CASH DISTRIBUTIONS PAID TO CO_2
CASH DISTRIBUTIONS PAID TO COMMON UNITS (Details) - USD ($) $ / shares in Units, $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2029 | Jun. 30, 2019 | Jun. 30, 2018 | |
Common Units | |||||
Partners' Equity | |||||
Per Unit Distribution, paid (in dollars per unit) | $ 0.65 | $ 0.65 | $ 1.30 | $ 1.65 | |
Total cash distribution | $ 47 | $ 47 | $ 95 | $ 123 | |
General Partner | General Partner | |||||
Partners' Equity | |||||
Total distribution for General Partner interest | $ 1 | $ 1 | $ 2 | 3 | |
Incentive distribution paid to the General Partner | $ 3 | ||||
General partner interest (as a percent) | 2.00% | 2.00% | 2.00% | 2.00% | 2.00% |
General Partner | General Partner | Incentive Distribution Rights | |||||
Partners' Equity | |||||
Incentive distribution paid to the General Partner | $ 0 |
CHANGE IN OPERATING WORKING C_3
CHANGE IN OPERATING WORKING CAPITAL - Components (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2019 | Jun. 30, 2018 | |
CHANGE IN OPERATING WORKING CAPITAL | ||
Change in accounts receivable and other | $ 15 | $ 2 |
Change in inventories | (1) | |
Change in other current assets | 3 | (1) |
Change in accounts payable and accrued liabilities | (12) | (6) |
Change in accrued interest | (1) | |
Change in operating working capital | $ 4 | $ (5) |
RELATED PARTY TRANSACTIONS (Det
RELATED PARTY TRANSACTIONS (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Dec. 31, 2018 | |
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | $ 6 | $ 6 | $ 6 | ||
Amount included in receivables from related party | 1 | 1 | 2 | ||
Great Lakes | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 12 | $ 16 | |||
Impact on the Partnership's net income attributable to controlling interests | 5 | 7 | |||
Northern Border | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 10 | 9 | |||
Impact on the Partnership's net income attributable to controlling interests | 5 | 4 | |||
PNGTS | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 1 | 2 | |||
Impact on the Partnership's net income attributable to controlling interests | 1 | 1 | |||
GTN | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 11 | 8 | |||
Impact on the Partnership's net income attributable to controlling interests | 8 | 7 | |||
Bison | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 1 | ||||
Impact on the Partnership's net income attributable to controlling interests | 1 | ||||
North Baja | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 2 | 1 | |||
Impact on the Partnership's net income attributable to controlling interests | 1 | 1 | |||
Tuscarora | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 1 | 1 | |||
Impact on the Partnership's net income attributable to controlling interests | 1 | 1 | |||
General Partner | Reimbursement of costs of services provided | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 1 | $ 1 | 2 | $ 2 | |
TC Energy | Great Lakes | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | 5 | $ 5 | 3 | ||
Percentage of capital and operating costs charged | 100.00% | 100.00% | |||
Amount included in receivables from related party | $ 13 | $ 13 | 18 | ||
TC Energy | Great Lakes | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 23 | $ 24 | |||
Impact on the Partnership's net income attributable to controlling interests | $ 10 | $ 11 | |||
Percentage of capital and operating costs charged | 100.00% | 100.00% | |||
TC Energy | Great Lakes | Transportation contracts | Total net revenues | Customer concentration risk | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Percent of total revenues | 73.00% | 72.00% | 70.00% | ||
TC Energy | Northern Border | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | $ 4 | $ 4 | 3 | ||
Percentage of capital and operating costs charged | 100.00% | 100.00% | |||
TC Energy | Northern Border | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | $ 19 | $ 18 | |||
Impact on the Partnership's net income attributable to controlling interests | $ 9 | $ 8 | |||
Percentage of capital and operating costs charged | 100.00% | 100.00% | |||
TC Energy | PNGTS | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | 1 | $ 1 | 1 | ||
Percentage of capital and operating costs charged | 100.00% | 100.00% | |||
TC Energy | PNGTS | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | $ 3 | $ 4 | |||
Impact on the Partnership's net income attributable to controlling interests | $ 2 | $ 2 | |||
Percentage of capital and operating costs charged | 100.00% | 100.00% | |||
TC Energy | PNGTS | Transportation contracts | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Amount included in receivables from related party | 0 | $ 0 | 0 | ||
Revenues from related party | 0 | $ 1 | 0 | ||
TC Energy | GTN | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | 4 | 4 | 4 | ||
TC Energy | GTN | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 21 | $ 16 | |||
Impact on the Partnership's net income attributable to controlling interests | 16 | 14 | |||
TC Energy | Bison | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | 1 | ||||
TC Energy | Bison | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 1 | 3 | |||
Impact on the Partnership's net income attributable to controlling interests | 1 | 3 | |||
TC Energy | North Baja | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | $ 1 | 1 | |||
TC Energy | North Baja | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 3 | 2 | |||
Impact on the Partnership's net income attributable to controlling interests | 2 | 2 | |||
TC Energy | Tuscarora | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Net amounts payable | $ 1 | ||||
TC Energy | Tuscarora | Capital and operating costs | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Costs charged | 2 | 2 | |||
Impact on the Partnership's net income attributable to controlling interests | 2 | 2 | |||
ANR Pipeline Company | Great Lakes | Transportation contracts | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Contract term | 15 years | ||||
Total contract value | $ 1,300 | $ 1,300 | |||
Affiliates | PNGTS | Construction of facilities | |||||
Capital and operating costs charged to the pipeline systems and amount payable | |||||
Reimbursement of costs | $ 99 |
FAIR VALUE MEASUREMENTS - Estim
FAIR VALUE MEASUREMENTS - Estimated Fair Value of Debt (Details) - USD ($) $ in Millions | Jun. 30, 2019 | Dec. 31, 2018 |
Fair Value | Level 2 | ||
Financial Instruments | ||
Fair value of debt | $ 2,064 | $ 2,101 |
FAIR VALUE MEASUREMENTS - Inter
FAIR VALUE MEASUREMENTS - Interest Rate Swaps (Details) - USD ($) $ in Millions | Jun. 26, 2019 | Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Dec. 31, 2018 |
Interest rate derivatives | ||||||
Change in fair value of interest rate derivative instruments recognized in other comprehensive income (loss) | $ (2) | $ (2) | ||||
Reclassification of net income of gains and losses on cash flow hedges | $ 1 | 3 | $ 1 | 3 | ||
Net realized gain related to the interest rate swaps included in financial charges and other | 2 | |||||
Amortization of derivatives loss | 2 | 2 | ||||
Change in fair value of interest rate derivative instruments recognized in other comprehensive income | $ (9) | (1) | $ (14) | 6 | ||
2013 Term Loan Facility | ||||||
Interest rate derivatives | ||||||
Repayments of secured debt | $ 50 | |||||
Unwind rate of interest rate swap (as a percent) | 2.81% | |||||
Interest rate swaps | Term loan | TC PipeLines, LP 2013 Term Loan Facility due 2022 | ||||||
Interest rate derivatives | ||||||
Weighted average fixed interest rate (as a percent) | 3.26% | 3.26% | ||||
Hedges of cash flows | Interest rate swaps | ||||||
Interest rate derivatives | ||||||
Change in fair value of interest rate derivative instruments recognized in other comprehensive income | $ (9) | (1) | $ (14) | 6 | ||
Hedges of cash flows | Interest rate swaps | Financial charges and other | ||||||
Interest rate derivatives | ||||||
Net realized gain related to the interest rate swaps included in financial charges and other | 0 | $ 1 | 1 | $ 2 | ||
Hedges of cash flows | Recurring fair value measurement | Level 2 | Interest rate swaps | ||||||
Interest rate derivatives | ||||||
Fair value of derivative asset, gross | $ 8 | |||||
Fair value of derivative liability, gross | 5 | 5 | ||||
Fair value of derivative asset, net | $ 8 | |||||
Fair value of derivative liability, net | $ 5 | $ 5 |
ACCOUNTS RECEIVABLE AND OTHER_2
ACCOUNTS RECEIVABLE AND OTHER (Details) - USD ($) $ in Millions | Jun. 30, 2019 | Dec. 31, 2018 |
ACCOUNTS RECEIVABLE AND OTHER | ||
Trade accounts receivable, net of allowance of nil | $ 31 | $ 44 |
Imbalance receivable from affiliates | 1 | 2 |
Other | 1 | 2 |
Accounts receivable and other | $ 33 | $ 48 |
FINANCIAL CHARGES AND OTHER (De
FINANCIAL CHARGES AND OTHER (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
FINANCIAL CHARGES AND OTHER | ||||
Interest expense | $ 22 | $ 24 | $ 45 | $ 48 |
PNGTS' amortization of loss on derivative instruments | 2 | 2 | ||
Net realized gain related to the interest rate swaps | (1) | (1) | (2) | |
Other income | (1) | (2) | (1) | (2) |
Financial charges and other | $ 21 | $ 23 | $ 43 | $ 46 |
VARIABLE INTEREST ENTITIES - Co
VARIABLE INTEREST ENTITIES - Consolidated VIEs (Details) - USD ($) $ in Millions | Jun. 30, 2019 | Dec. 31, 2018 |
ASSETS (LIABILITIES) | ||
Cash and cash equivalents | $ 45 | $ 33 |
Accounts receivable and other | 33 | 48 |
Inventories | 9 | 8 |
Other current assets | 3 | 8 |
Equity investments | 1,118 | 1,196 |
Property, plant and equipment, net | 1,520 | 1,529 |
Other assets | 6 | |
Accounts payable and accrued liabilities | (26) | (36) |
Accounts payable to affiliates, net | (6) | (6) |
Accrued interest | (11) | (12) |
Current portion of long-term debt | (101) | (36) |
Long-term debt | (1,892) | (2,072) |
Other liabilities | (34) | (29) |
Consolidated VIEs | Restricted VIEs | ||
ASSETS (LIABILITIES) | ||
Cash and cash equivalents | 14 | 16 |
Accounts receivable and other | 29 | 39 |
Inventories | 9 | 8 |
Other current assets | 3 | 6 |
Equity investments | 1,118 | 1,196 |
Property, plant and equipment, net | 1,240 | 1,240 |
Other assets | 1 | 1 |
Accounts payable and accrued liabilities | (22) | (33) |
Accounts payable to affiliates, net | (87) | (40) |
Accrued interest | (2) | (2) |
Current portion of long-term debt | (101) | (36) |
Long-term debt | (251) | (341) |
Other liabilities | (28) | (27) |
Deferred state income tax | $ (9) | $ (9) |
SUBSEQUENT EVENTS - Distributio
SUBSEQUENT EVENTS - Distributions (Details) - USD ($) $ / shares in Units, $ in Millions | Aug. 01, 2029 | Aug. 14, 2019 | Aug. 01, 2019 | Jul. 31, 2019 | Jul. 23, 2019 | Jul. 16, 2019 | Jul. 12, 2019 | Jul. 08, 2019 | Aug. 31, 2019 | Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2029 | Jun. 30, 2019 | Jun. 30, 2018 |
Distributions | ||||||||||||||
Limited Partners, Distributions paid | $ 13 | $ 15 | ||||||||||||
Partnership's share of distributions | $ 112 | $ 96 | ||||||||||||
Northern Border | ||||||||||||||
Distributions | ||||||||||||||
Ownership interest (as a percent) | 50.00% | 50.00% | ||||||||||||
Great Lakes | ||||||||||||||
Distributions | ||||||||||||||
Ownership interest (as a percent) | 46.45% | 46.45% | ||||||||||||
Subsequent Events | Northern Border | ||||||||||||||
Distributions | ||||||||||||||
Ownership interest (as a percent) | 50.00% | |||||||||||||
Partnership's share of distributions | $ 7 | |||||||||||||
Subsequent Events | Great Lakes | ||||||||||||||
Distributions | ||||||||||||||
Ownership interest (as a percent) | 46.45% | |||||||||||||
Partnership's share of distributions | $ 9 | |||||||||||||
Subsequent Events | Iroquois | ||||||||||||||
Distributions | ||||||||||||||
Ownership interest (as a percent) | 49.34% | |||||||||||||
Partnership's share of distributions | $ 14 | |||||||||||||
Interest in unrestricted cash | $ 2.6 | |||||||||||||
Subsequent Events | Northern Border | ||||||||||||||
Distributions | ||||||||||||||
Limited partners, Distribution declared | $ 15 | |||||||||||||
Subsequent Events | Great Lakes | ||||||||||||||
Distributions | ||||||||||||||
Limited partners, Distribution declared | $ 20 | |||||||||||||
Subsequent Events | Iroquois | ||||||||||||||
Distributions | ||||||||||||||
Limited partners, Distribution declared | $ 28 | |||||||||||||
Subsequent Events | PNGTS | ||||||||||||||
Distributions | ||||||||||||||
Limited partners, Distribution declared | $ 7 | |||||||||||||
Share of distributions to its non-controlling interest owner | $ 3 | |||||||||||||
General Partner | General Partner | ||||||||||||||
Distributions | ||||||||||||||
Ownership interest in the Partnership (as a percent) | 2.00% | 2.00% | 2.00% | 2.00% | 2.00% | |||||||||
Incentive distribution paid to the General Partner | $ 3 | |||||||||||||
Forecast | Subsequent Events | ||||||||||||||
Distributions | ||||||||||||||
Limited Partners, Distributions paid | $ 47 | |||||||||||||
Distribution to General Partner | $ 1 | |||||||||||||
Common Units | Subsequent Events | ||||||||||||||
Distributions | ||||||||||||||
Per Unit Distribution, declared (in dollars per unit) | $ 0.65 | |||||||||||||
Common Units | Subsequent Events | General Partner | ||||||||||||||
Distributions | ||||||||||||||
Ownership interest in the Partnership (as a percent) | 2.00% | |||||||||||||
Common Units | General Partner | Subsequent Events | ||||||||||||||
Distributions | ||||||||||||||
Number of units held by investor | 5,797,106 | |||||||||||||
Common Units | TC Energy | Subsequent Events | ||||||||||||||
Distributions | ||||||||||||||
Number of units held by investor | 11,287,725 | |||||||||||||
Common Units | Forecast | Subsequent Events | ||||||||||||||
Distributions | ||||||||||||||
Limited Partners, Distributions paid | $ 46 | |||||||||||||
Common Units | Forecast | General Partner | Subsequent Events | ||||||||||||||
Distributions | ||||||||||||||
Limited Partners, Distributions paid | 4 | |||||||||||||
Common Units | Forecast | TC Energy | Subsequent Events | ||||||||||||||
Distributions | ||||||||||||||
Limited Partners, Distributions paid | $ 7 |