Attached files
| file | filename |
|---|---|
| EX-32 - EX-32 - NORTHWEST PIPELINE LLC | nwp_20170630xex-32.htm |
| EX-31.2 - EX-31.2 - NORTHWEST PIPELINE LLC | nwp_20170630xex-312.htm |
| EX-31.1 - EX-31.1 - NORTHWEST PIPELINE LLC | nwp_20170630xex-311.htm |
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
þ | QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the quarterly period ended June 30, 2017
or
¨ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from _____________ to _____________
Commission File Number: 1-7414
NORTHWEST PIPELINE LLC
(Exact name of registrant as specified in its charter)
DELAWARE | 26-1157701 | |
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | |
295 Chipeta Way Salt Lake City, Utah | 84108 | |
(Address of principal executive offices) | (Zip Code) | |
Registrant’s telephone number, including area code: (801) 583-8800
NO CHANGE
(Former name, former address, and former fiscal year, if changed since last report)
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No ¨
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer ¨ | Accelerated filer ¨ | Non-accelerated filer þ | Smaller reporting company ¨ | Emerging growth company ¨ | ||||
(Do not check if a smaller reporting company) | ||||||||
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No þ
THE REGISTRANT MEETS THE CONDITIONS SET FORTH IN GENERAL INSTRUCTION (H)(1)(a) AND (b) OF FORM 10-Q AND IS THEREFORE FILING THIS FORM 10-Q WITH THE REDUCED DISCLOSURE FORMAT.
NORTHWEST PIPELINE LLC
FORM 10-Q
INDEX
Page | |
Balance Sheet — June 30, 2017 and December 31, 2016 | |
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations | |
Forward-Looking Statements
The reports, filings, and other public announcements of Northwest Pipeline LLC, may contain or incorporate by reference statements that do not directly or exclusively relate to historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (Securities Act), and Section 21E of the Securities Exchange Act of 1934, as amended (Exchange Act). These forward-looking statements relate to anticipated financial performance, management’s plans and objectives for future operations, business prospects, outcome of regulatory proceedings, market conditions, and other matters.
All statements, other than statements of historical facts, included in this report that address activities, events, or developments that we expect, believe, or anticipate will exist or may occur in the future are forward-looking statements. Forward-looking statements can be identified by various forms of words or phrases such as “anticipates,” “believes,” “seeks,” “could,” “may,” “should,” “continues,” “estimates,” “expects,” “assumes,” “forecasts,” “intends,” “might,” “goals,” “objectives,” “targets,” “planned,” “potential,” “projects,” “scheduled,” “will,” “guidance,” “outlook,” “in service date,” or other similar expressions. These forward-looking statements are based on management’s beliefs and assumptions and on information currently available to management and include, among others, statements regarding:
• | Our and our affiliates' future credit ratings; |
• | Amounts and nature of future capital expenditures; |
• | Expansion and growth of our business and operations; |
• | Expected in service dates for capital projects; |
• | Financial condition and liquidity; |
• | Business strategy; |
• | Cash flow from operations or results of operations; |
• | Rate case filings; |
• | Natural gas prices, supply, and demand; and |
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• | Demand for our services. |
Forward-looking statements are based on numerous assumptions, uncertainties, and risks that could cause future events or results to be materially different from those stated or implied in this report. Many of the factors that will determine these results are beyond our ability to control or predict. Specific factors that could cause actual results to differ from results contemplated by forward-looking statements include, among others, the following:
• | Availability of supplies, including lower than anticipated volumes from third parties, and market demand; |
• | Volatility of pricing including the effect of lower than anticipated energy commodity prices and margins; |
• | Inflation, interest rates, and general economic conditions (including future disruptions and volatility in the global credit markets and the impact of these events on our customers and suppliers); |
• | The strength and financial resources of our competitors and the effects of competition; |
• | Whether we are able to successfully identify, evaluate and timely execute our capital projects and other investment opportunities in accordance with our capital expenditure budget; |
• | Whether Williams will be able to effectively manage the transition in its board of directors and management as well as successfully execute its business restructuring; |
• | Our ability to successfully expand our facilities and operations; |
• | Development and rate of adoption of alternative energy sources; |
• | The impact of operational and development hazards, unforeseen interruptions, and the availability of adequate insurance coverage for such interruptions; |
• | The impact of existing and future laws, regulations, the regulatory environment, environmental liabilities, and litigation, as well as our ability to obtain permits and achieve favorable rate proceeding outcomes; |
• | Our costs for defined benefit pension plans and other postretirement benefit plans sponsored by our affiliates; |
• | Changes in maintenance and construction costs; |
• | Changes in the current geopolitical situation; |
• | Our exposure to the credit risks of our customers and counterparties; |
• | Risks related to financing, including restrictions stemming from our debt agreements, future changes in our credit ratings and the availability and cost of capital; |
• | Risks associated with weather and natural phenomena, including climate conditions and physical damage to our facilities; |
• | Acts of terrorism, including cybersecurity threats, and related disruptions; and |
• | Additional risks described in our filings with the Securities and Exchange Commission (SEC). |
Given the uncertainties and risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement, we caution investors not to unduly rely on our forward-looking statements. We disclaim any obligations to and do not intend to update the above list or to announce publicly any revisions to any of the forward-looking statements to reflect future events or developments.
In addition to causing our actual results to differ, the factors listed above and referred to below may cause our intentions to change from those statements of intention set forth in this report. Such changes in our intentions may also cause our results to differ. We may change our intentions, at any time and without notice, based upon changes in such factors, our assumptions, or otherwise.
Because forward-looking statements involve risks and uncertainties, we caution that there are important factors, in addition to those listed above, that may cause actual results to differ materially from those contained in the forward-looking statements.
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For a detailed discussion of those factors, see Part I, Item 1A. Risk Factors in our Annual Report on Form 10-K filed with the SEC on February 22, 2017.
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PART I – FINANCIAL INFORMATION
Item 1. Financial Statements.
NORTHWEST PIPELINE LLC
STATEMENT OF COMPREHENSIVE INCOME
(Thousands of Dollars)
(Unaudited)
Three months ended June 30, | Six months ended June 30, | |||||||||||||||
2017 | 2016 | 2017 | 2016 | |||||||||||||
OPERATING REVENUES | $ | 115,094 | $ | 115,569 | $ | 235,594 | $ | 236,017 | ||||||||
OPERATING EXPENSES: | ||||||||||||||||
General and administrative | 13,421 | 13,038 | 27,502 | 26,865 | ||||||||||||
Operation and maintenance | 19,125 | 21,231 | 34,522 | 38,483 | ||||||||||||
Depreciation | 25,313 | 25,414 | 50,829 | 50,729 | ||||||||||||
Regulatory debits | 1,213 | 871 | 2,461 | 1,720 | ||||||||||||
Taxes, other than income taxes | 4,206 | 4,312 | 8,987 | 8,664 | ||||||||||||
Total operating expenses | 63,278 | 64,866 | 124,301 | 126,461 | ||||||||||||
OPERATING INCOME | 51,816 | 50,703 | 111,293 | 109,556 | ||||||||||||
OTHER (INCOME) AND OTHER EXPENSES: | ||||||||||||||||
Interest expense | 8,448 | 10,952 | 16,811 | 22,429 | ||||||||||||
Allowance for equity and borrowed funds used during construction | (362 | ) | (242 | ) | (512 | ) | (625 | ) | ||||||||
Miscellaneous other (income) expenses, net | 98 | 31 | 213 | 669 | ||||||||||||
Total other (income) and other expenses | 8,184 | 10,741 | 16,512 | 22,473 | ||||||||||||
NET INCOME | 43,632 | 39,962 | 94,781 | 87,083 | ||||||||||||
CASH FLOW HEDGES: | ||||||||||||||||
Amortization of cash flow hedges into Interest expense | — | (13 | ) | — | (28 | ) | ||||||||||
COMPREHENSIVE INCOME | $ | 43,632 | $ | 39,949 | $ | 94,781 | $ | 87,055 | ||||||||
See accompanying notes.
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NORTHWEST PIPELINE LLC
BALANCE SHEET
(Thousands of Dollars)
(Unaudited)
June 30, 2017 | December 31, 2016 | |||||||
ASSETS | ||||||||
CURRENT ASSETS: | ||||||||
Cash | $ | — | $ | — | ||||
Receivables: | ||||||||
Trade | 38,172 | 42,702 | ||||||
Affiliated companies | 1,505 | 1,321 | ||||||
Advances to affiliate | 123,999 | 45,137 | ||||||
Other | 595 | 598 | ||||||
Materials and supplies | 10,162 | 10,106 | ||||||
Exchange gas due from others | 1,082 | 3,869 | ||||||
Prepayments and other | 6,762 | 5,740 | ||||||
Total current assets | 182,277 | 109,473 | ||||||
PROPERTY, PLANT AND EQUIPMENT, at cost | 3,344,867 | 3,319,516 | ||||||
Less-Accumulated depreciation | 1,462,287 | 1,424,855 | ||||||
Total property, plant and equipment, net | 1,882,580 | 1,894,661 | ||||||
OTHER ASSETS: | ||||||||
Deferred charges | 1,112 | 2,122 | ||||||
Regulatory assets | 31,114 | 34,900 | ||||||
Total other assets | 32,226 | 37,022 | ||||||
Total assets | $ | 2,097,083 | $ | 2,041,156 | ||||
See accompanying notes.
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NORTHWEST PIPELINE LLC
BALANCE SHEET
(Thousands of Dollars)
(Unaudited)
June 30, 2017 | December 31, 2016 | |||||||
LIABILITIES AND OWNER’S EQUITY | ||||||||
CURRENT LIABILITIES: | ||||||||
Payables: | ||||||||
Trade | $ | 13,372 | $ | 11,243 | ||||
Affiliated companies | 6,607 | 7,293 | ||||||
Accrued liabilities: | ||||||||
Taxes, other than income taxes | 12,719 | 11,435 | ||||||
Interest | 3,593 | 3,501 | ||||||
Exchange gas due to others | 3,181 | 4,169 | ||||||
Exchange gas offset | 1,881 | 1,428 | ||||||
Customer advances | 1,027 | 1,893 | ||||||
Other | 9,968 | 5,224 | ||||||
Long-term debt due within one year | 249,737 | 184,924 | ||||||
Total current liabilities | 302,085 | 231,110 | ||||||
LONG-TERM DEBT | 331,729 | 334,236 | ||||||
OTHER NONCURRENT LIABILITIES: | ||||||||
Asset retirement obligations | 59,880 | 60,762 | ||||||
Regulatory liabilities | 35,367 | 30,717 | ||||||
Other | 3,227 | 7,316 | ||||||
Total other noncurrent liabilities | 98,474 | 98,795 | ||||||
CONTINGENT LIABILITIES AND COMMITMENTS (Note 2) | ||||||||
OWNER’S EQUITY: | ||||||||
Owner’s capital | 1,073,892 | 1,073,892 | ||||||
Retained earnings | 290,903 | 303,123 | ||||||
Total owner’s equity | 1,364,795 | 1,377,015 | ||||||
Total liabilities and owner’s equity | $ | 2,097,083 | $ | 2,041,156 | ||||
See accompanying notes.
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NORTHWEST PIPELINE LLC
STATEMENT OF CASH FLOWS
(Thousands of Dollars)
(Unaudited)
Six months ended June 30, | ||||||||
2017 | 2016 | |||||||
OPERATING ACTIVITIES: | ||||||||
Net income | $ | 94,781 | $ | 87,083 | ||||
Adjustments to reconcile net income to net cash provided by (used in) operating activities: | ||||||||
Depreciation | 50,829 | 50,729 | ||||||
Regulatory debits | 2,461 | 1,720 | ||||||
Amortization of deferred charges and credits | 683 | (190 | ) | |||||
Allowance for equity funds used during construction | (388 | ) | (431 | ) | ||||
Changes in current assets and liabilities: | ||||||||
Trade and other accounts receivable | 4,533 | 3,221 | ||||||
Affiliated receivables | (184 | ) | (218 | ) | ||||
Exchange gas due from others | 2,787 | 658 | ||||||
Materials and supplies | (56 | ) | 3 | |||||
Other current assets | (1,022 | ) | (102 | ) | ||||
Trade accounts payable | (962 | ) | 799 | |||||
Affiliated payables | (686 | ) | (5,476 | ) | ||||
Exchange gas due to others | (2,787 | ) | (658 | ) | ||||
Other accrued liabilities | 5,691 | (1,324 | ) | |||||
Changes in noncurrent assets and liabilities: | ||||||||
Deferred charges | 298 | (2,900 | ) | |||||
Noncurrent liabilities | (1,055 | ) | 5,697 | |||||
Net cash provided by operating activities | 154,923 | 138,611 | ||||||
FINANCING ACTIVITIES: | ||||||||
Payments of long-term debt | (185,000 | ) | (175,000 | ) | ||||
Proceeds from long-term debt | 249,102 | — | ||||||
Debt issue costs | (2,082 | ) | — | |||||
Cash distributions to parent | (107,000 | ) | (86,000 | ) | ||||
Net cash used in financing activities | (44,980 | ) | (261,000 | ) | ||||
INVESTING ACTIVITIES: | ||||||||
Property, plant and equipment: | ||||||||
Capital expenditures, net of equity AFUDC* | (31,493 | ) | (22,843 | ) | ||||
Contributions and advances for construction costs | 365 | 252 | ||||||
Disposal of property, plant and equipment, net | 48 | (364 | ) | |||||
Advances to affiliates, net | (78,863 | ) | 135,399 | |||||
Proceeds from insurance | — | 9,776 | ||||||
Net cash provided by (used in) investing activities | (109,943 | ) | 122,220 | |||||
NET INCREASE (DECREASE) IN CASH | — | (169 | ) | |||||
CASH AT BEGINNING OF PERIOD | — | 169 | ||||||
CASH AT END OF PERIOD | $ | — | $ | — | ||||
____________________________________ | ||||||||
* Increases to property, plant and equipment | $ | (33,894 | ) | $ | (18,451 | ) | ||
Changes in related accounts receivable, accounts payable, and accrued liabilities | 2,401 | (4,392 | ) | |||||
Capital expenditures, net of equity AFUDC | $ | (31,493 | ) | $ | (22,843 | ) | ||
See accompanying notes.
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1. BASIS OF PRESENTATION
Northwest Pipeline LLC (Northwest) is indirectly owned by Williams Partners L.P. (WPZ), a publicly traded Delaware limited partnership, which is consolidated by The Williams Companies, Inc. (Williams). In January 2017, Williams permanently waived the WPZ general partner's incentive distribution rights, converted its 2 percent general partner interest in WPZ to a non-economic interest, and purchased additional WPZ common units. At June 30, 2017, Williams owned an approximate 74 percent limited partner interest in WPZ.
In this report, Northwest is at times referred to in the first person as “we,” “us,” or “our.”
General
The accompanying interim financial statements do not include all the notes in our annual financial statements, and therefore, should be read in conjunction with the financial statements and notes thereto in our 2016 Annual Report on Form 10-K. The accompanying unaudited financial statements include all adjustments both normal recurring and others which, in the opinion of our management, are necessary to present fairly our interim financial statements.
The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Actual results could differ from those estimates.
Accounting Standards Issued But Not Yet Adopted
In August 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2016-15 "Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments" (ASU 2016-15). ASU 2016-15 provides specific guidance on eight cash flow classification issues, including debt prepayment or debt extinguishment costs and distributions received from equity method investees, to reduce diversity in practice. ASU 2016-15 is effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted. ASU 2016-15 requires a retrospective transition. We do not expect ASU 2016-15 to have a material impact on our financial statements.
In June 2016, the FASB issued ASU 2016-13 "Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments" (ASU 2016-13). ASU 2016-13 changes the impairment model for most financial assets and certain other instruments. For trade and other receivables, held-to-maturity debt securities, loans, and other instruments, entities will be required to use a new forward-looking "expected loss" model that generally will result in the earlier recognition of allowances for losses. The guidance also requires increased disclosures. ASU 2016-13 is effective for interim and annual periods beginning after December 15, 2019. Early adoption is permitted. ASU 2016-13 requires varying transition methods for the different categories of amendments. We do not expect ASU 2016-13 to have a significant impact on our financial statements.
In February 2016, the FASB issued ASU 2016-02 "Leases (Topic 842)" (ASU 2016-02). ASU 2016-02 establishes a comprehensive new lease accounting model. The ASU 2016-02 clarifies the definition of a lease, requires a dual approach to lease classification similar to current lease classifications, and causes lessees to recognize leases on the balance sheet as a lease liability with a corresponding right-of-use asset. ASU 2016-02 is effective for interim and annual periods beginning after December 15, 2018. Early adoption is permitted. ASU 2016-02 requires a modified retrospective transition for capital or operating leases existing at or entered into after the beginning of the earliest comparative period presented in the financial statements. We are in the process of reviewing contracts to identify leases, as well as evaluating the applicability of ASU 2016-02 to contracts involving easement/rights-of-way.
In May 2014, the FASB issued ASU 2014-09 establishing Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers" (ASC 606). ASC 606 establishes a comprehensive new revenue recognition model designed to depict the transfer of goods or services to a customer in an amount that reflects the consideration the entity expects to be entitled to receive in exchange for those goods or services and requires significantly enhanced revenue disclosures. In August 2015, the FASB issued ASU 2015-14 "Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date" (ASU 2015-14). Per ASU 2015-14, the standard is effective for interim and annual reporting periods beginning after December 15, 2017. ASC 606 allows either full retrospective or modified retrospective transition and early adoption is permitted for annual periods beginning after December 15, 2016.
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We continue to evaluate the impact the standard may have on our financial statements. For each revenue contract type, we are conducting a formal contract review process to evaluate the impact, if any, that the new revenue standard may have. We are continuing our evaluation of the application of accounting for noncash consideration as it relates to certain contracts where we receive or retain natural gas as part of the service arrangement. We are unable to determine the potential impact upon the amount and timing of revenue recognition. We continue to evaluate and develop disclosures required under the new standard, with a particular focus on the scope of contracts subject to disclosure of remaining performance obligations. Additionally, we have identified possible financial system and internal control changes necessary for adoption. We currently anticipate utilizing a modified retrospective transition upon the adoption of ASC 606 as of January 1, 2018.
2. RATE AND REGULATORY MATTERS
Rate Case Settlement Filing
On January 23, 2017, we filed for Federal Energy Regulatory Commission (FERC) approval a Stipulation and Settlement Agreement (Settlement) and were assigned Docket No. RP17-346. The Settlement specified an annual cost of service of $440 million and established a new general system firm Rate Schedule TF-1 (Large Customer) demand rate of $0.39294/Dth with a $0.00832 commodity rate (Phase 1) and a demand rate of $0.39033/Dth with a $0.00832 commodity rate (Phase 2). Phase 1 rates become effective January 1, 2018, with Phase 2 rates becoming effective October 1, 2018. The annual cost of service does not change from Phase 1 to Phase 2, but the Phase 2 rates reflect the termination of fifteen-year levelized contracts that will now become Rate Schedule TF-1 (Large Customer) contracts. Provisions were included in the Settlement that we can file a general rate case to place new rates into effect after October 1, 2018, and that a general rate case must be filed for new rates to become effective no later than January 1, 2023.
The FERC has been without a quorum since February 4, 2017. This lack of quorum has left FERC unable to formally approve the Settlement. In response, on March 29, 2017, we filed tariff records with the FERC to extend our requirement to file an NGA section 4 general rate case "by not later than July 1, 2017" (as required in our prior Settlement in Docket No. RP12-490 and our pending 2017 Settlement in RP 17-346). These tariff records also provide a means to place the rate reductions of the 2017 Settlement into effect commencing January 1, 2018 until a quorum at FERC is restored and can formally approve the Settlement. This new filing was assigned Docket No. RP17-567. On April 12, 2017, the FERC issued an order accepting the tariff records effective May 1, 2017.
3. CONTINGENT LIABILITIES AND COMMITMENTS
Environmental Matters
We are subject to the National Environmental Policy Act and other federal and state legislation regulating the environmental aspects of our business. Except as discussed below, our management believes that we are in substantial compliance with existing environmental requirements. Environmental expenditures are expensed or capitalized depending on their future economic benefit and potential for rate recovery. We believe that, with respect to any expenditures required to meet applicable standards and regulations, the Federal Energy Regulatory Commission would grant the requisite rate relief so that substantially all of such expenditures would be permitted to be recovered through rates.
Beginning in the mid-1980s, we evaluated many of our facilities for the presence of toxic and hazardous substances to determine to what extent, if any, remediation might be necessary. We identified polychlorinated biphenyl (PCB) contamination in air compressor systems, soils, and related properties at certain compressor station sites. Similarly, we identified hydrocarbon impacts at these facilities due to the former use of earthen pits, lubricating oil leaks or spills, and excess pipe coating released to the environment. In addition, heavy metals have been identified at these sites due to the former use of mercury containing meters and paint and welding rods containing lead, cadmium, and arsenic. The PCBs were remediated pursuant to a Consent Decree with the U.S. Environmental Protection Agency (EPA) in the late 1980s, and we conducted a voluntary clean-up of the hydrocarbon and mercury impacts in the early 1990s. In 2005, the Washington Department of Ecology required us to re-evaluate our previous clean-ups in Washington. During 2006 to 2015, 129 meter stations were evaluated, of which 82 required remediation. As of June 30, 2017, all of the meter stations have been remediated. Initial assessments have been completed at all thirteen compressor stations in Washington. Additional assessments are ongoing at two of these compressor stations. Remediation has been completed at eleven of the thirteen compressor stations. On the basis of the findings to date, we estimate that environmental assessment and
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remediation costs will total approximately $4.4 million, measured on an undiscounted basis, and are expected to be incurred through 2020. At June 30, 2017 and December 31, 2016, we had accrued liabilities totaling approximately $4.4 million and $4.4 million, respectively, for these costs. We are conducting environmental assessments and implementing a variety of remedial measures that may result in increases or decreases in the total estimated costs.
In March 2008, the EPA promulgated a new, lower National Ambient Air Quality Standard (NAAQS) for ground-level ozone. In May 2012, the EPA completed designation of new eight-hour ozone non-attainment areas. Based on the published designations, no Northwest facilities are located within the non-attainment areas. At this time, it is unknown whether future state regulatory actions associated with implementation of the 2008 ozone standard will impact our operations and increase the cost of additions to property, plant and equipment. Until any additional state regulatory actions are proposed, we are unable to estimate the cost of additions that may be required to meet any such new regulation.
In December 2014, the EPA proposed to further reduce the ground-level ozone NAAQS from the March 2008 levels and subsequently finalized a rule on October 1, 2015. We are monitoring the rule's implementation as the reduction will trigger additional federal and state regulatory actions that may impact our operations. As a result, the cost of additions to property, plant, and equipment is expected to increase. We are unable at this time to estimate with any certainty the cost of additions that may be required to meet new regulations.
On January 22, 2010, the EPA set a new one-hour nitrogen dioxide (NO2) NAAQS. The effective date of the new NO2 standard was April 12, 2010. On January 20, 2012, the EPA determined pursuant to available information that no area in the country is violating the 2010 NO2 NAAQS, and thus, designated all areas of the country as “unclassifiable/attainment.” Also, at that time, the EPA noted its plan to deploy an expanded NO2 monitoring network beginning in 2013. However, on October 5, 2012, the EPA proposed a graduated implementation of the monitoring network between January 1, 2014 and January 1, 2017. Once three years of data are collected from the new monitoring network, the EPA will reassess attainment status with the one-hour NO2 NAAQS. Until that time, the EPA or states may require ambient air quality modeling on a case by case basis to demonstrate compliance with the NO2 standard. Because we are unable to predict the outcome of the EPA’s or states’ future assessment using the new monitoring network, we are unable to estimate the cost of additions that may be required to meet this regulation.
Other Matters
Various other proceedings are pending against us and are considered incidental to our operations.
Summary
We estimate that for all matters for which we are able to reasonably estimate a range of loss, including those noted above and others that are not individually significant, our aggregate reasonably possible losses beyond amounts accrued for all of our contingent liabilities are immaterial to our expected future annual results of operations, liquidity, and financial position. These calculations have been made without consideration of any potential recovery from third parties. We have disclosed all significant matters for which we are unable to reasonably estimate a range of possible loss.
4. DEBT AND FINANCING ARRANGEMENT
Credit Facility
We, along with WPZ and Transcontinental Gas Pipe Line Company, LLC, are party to a credit agreement with aggregate commitments available of $3.5 billion, with up to an additional $500 million increase in aggregate commitments available under certain circumstances. Total letter of credit capacity available to WPZ under this credit facility is $1.125 billion. We are able to borrow up to $500 million under this credit facility to the extent not otherwise utilized by the other co-borrowers. At June 30, 2017, no letters of credit have been issued and no loans were outstanding under the credit facility.
WPZ participates in a commercial paper program, and WPZ management considers amounts outstanding under this program to be a reduction of available capacity under the credit facility. The program allows a maximum outstanding amount at any time of $3 billion of unsecured commercial paper notes. At June 30, 2017, no commercial paper was outstanding under the commercial paper program.
Issuance and Retirement of Long-Term Debt
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On April 3, 2017, we issued $250 million of 4.00 percent senior unsecured notes due 2027 to investors in a private debt placement. We used the net proceeds to repay the $185 million, 5.95 percent notes that matured on April 15, 2017, and to fund capital expenditures. As part of the issuance, we entered into a registration rights agreement with the initial purchaser of the unsecured notes. We are obligated to file and consummate a registration statement for an offer to exchange the notes for a new issue of substantially identical notes registered under the Securities Act of 1933, as amended, within 365 days from the closing and to use commercially reasonable efforts to complete the exchange offer. We are required to provide a shelf registration statement to cover resales of the notes under certain circumstances. If we fail to fulfill these obligations, additional interest will be accrued on the affected securities. The rate of additional interest will be 0.25 percent per annum on the principal amount of the affected securities for the first 90-day period immediately following the occurrence of a registration default, increasing by an additional 0.25 percent per annum with respect to each subsequent 90-day period thereafter, up to a maximum amount for all such registration defaults of 0.5 percent annually. Following the cure of any registration defaults, the accrual of additional interest will cease.
Long-Term Debt due within one-year
The $250 million, 6.05 percent notes due June 15, 2018, are classified as long-term debt due within in one-year in the accompanying Balance Sheet as of June 30, 2017.
5. FINANCIAL INSTRUMENTS
Fair Value of Financial Instruments
The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate that value:
Cash and advances to affiliate—The carrying amounts approximate fair value because of the short-term nature of these instruments.
Long-term debt—The disclosed fair value of our long-term debt, which we consider as a level 2 measurement, is determined by a market approach using broker quoted indicative period-end bond prices. The quoted prices are based on observable transactions in less active markets for our debt or similar instruments. The carrying amount and estimated fair value of our long-term debt, including current maturities, were $581.5 million and $614.5 million, respectively, at June 30, 2017, and $519.2 million and $546.8 million, respectively, at December 31, 2016.
6. TRANSACTIONS WITH AFFILIATES
We are a participant in WPZ’s cash management program. At June 30, 2017 and December 31, 2016, the advances due to us by WPZ totaled approximately $124.0 million and $45.1 million, respectively. These advances are represented by demand notes and are classified as Current Assets in the accompanying Balance Sheet. The interest rate on these intercompany demand notes is based upon the daily overnight investment rate paid on WPZ’s excess cash at the end of each month, which was 0.83 percent at June 30, 2017. The interest income from these advances was minimal during the three and six months ended June 30, 2017 and June 30, 2016. Such interest income is included in Other (Income) and Other Expenses – Miscellaneous other (income) expenses, net on the accompanying Statement of Comprehensive Income.
We have no employees. Services necessary to operate our business are provided to us by Williams and certain affiliates of Williams. We reimburse Williams and its affiliates for all direct and indirect expenses incurred or payments made (including salary, bonus, incentive compensation, and benefits) in connection with these services. Employees of Williams also provide general administrative and management services to us, and we are charged for certain administrative expenses incurred by Williams. These charges are either directly identifiable or allocated to our assets. Direct charges are for goods and services provided by Williams at our request. Allocated charges are based on a three-factor formula, which considers revenues; property, plant, and equipment; and payroll. In management’s estimation, the allocation methodologies used are reasonable and result in a reasonable allocation to us of our costs of doing business incurred by Williams. We were billed $23.2 million and $46.2 million in the three and six months ended June 30, 2017, respectively, and $21.1 million and $46.1 million in the three and six months ended June 30, 2016, respectively, for these services. Such expenses are primarily included in General and administrative and Operation and maintenance expenses on the accompanying Statement of Comprehensive Income. The amount billed to us for the six months ended June 30,
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2016, includes $2.0 million recognized in the first quarter of 2016 for severance and other related costs associated with a reduction in workforce.
During the six months ended June 30, 2017 and 2016, we declared and paid cash distributions to our parent of $107.0 million and $86.0 million, respectively. During July 2017, we declared and paid an additional cash distribution of $41.0 million to our parent.
We have entered into various other transactions with certain related parties, the amounts of which were not significant. These transactions and the above-described transactions are made on the basis of commercial relationships and prevailing market prices or general industry practices.
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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
GENERAL
The following discussion should be read in conjunction with the Management’s Discussion and Analysis, Financial Statements, and Notes contained in Items 7 and 8 of our 2016 Annual Report on Form 10-K and with the Financial Statements and Notes contained in this Form 10-Q.
RESULTS OF OPERATIONS
Analysis of Financial Results
This analysis discusses financial results of our operations for the six-month periods ended June 30, 2017 and 2016. Variances due to changes in natural gas prices and transportation volumes have little impact on revenues, because under our rate design methodology, the majority of overall cost of service is recovered through firm capacity reservation charges in our transportation rates.
Our operating revenues were relatively flat in the first six months of 2017 as compared with the first six months of 2016. Transportation services accounted for 97 percent and gas storage service accounted for 3 percent of our operating revenues for both periods.
Operating expenses decreased $4.0 million, or 10 percent, for the first six months of 2017 as compared to the first six months of 2016, due primarily to a $2.1 million decrease in contractual and other outside services, a $0.5 million decrease in charges billed from affiliates in the first six months of 2017 as well as the absence of $1.0 million in severance and $0.2 million of employee relocation costs recorded in the first six months of 2016, associated with a reduction and movements in workforce.
Interest expense decreased $5.6 million, or 25 percent, as a result of the retirement of our $175.0 million 7 percent senior unsecured notes that matured on June 15, 2016 and the retirement of the $185 million 5.95 percent notes in April 2017 partially offset by the interest expense recorded on the $250 million 4 percent senior unsecured notes issued on April 3, 2017.
Financing
On April 3, 2017, we issued $250 million of 4.00 percent senior unsecured notes due 2027 to investors in a private debt placement. We used the net proceeds to repay the $185 million, 5.95 percent notes that matured on April 15, 2017, and to fund capital expenditures.
Capital Expenditures
Our capital expenditures were $31.5 million and $22.8 million for the six months ended June 30, 2017 and 2016, respectively. Our capital expenditures estimate for 2017 is discussed in our 2016 Annual Report on Form 10-K.
Pipeline Projects
The North Seattle Lateral Upgrade (Project) involves an expanded delivery capabilities of Northwest’s North Seattle Lateral. On May 11, 2017, we filed the FERC 7(c) application for the Project. The Project consists of the removal and replacement of approximately 6.9 miles of 8-inch diameter pipeline with new 20-inch diameter pipeline. We plan to place the Project into service as early as the fourth quarter of 2019, and it is expected to increase the delivery capacity by up to 196 MDth/d.
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Item 4. Controls and Procedures
Our management, including our Senior Vice President—West and our Vice President, Controller and Chief Accounting Officer, does not expect that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act) (Disclosure Controls) or our internal control over financial reporting (Internal Controls) will prevent all errors and all fraud. A control system, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met. Further, the design of a control system must reflect the fact that there are resource constraints, and the benefits of controls must be considered relative to their costs. Because of the inherent limitations in all control systems, no evaluation of controls can provide absolute assurance that all control issues and instances of fraud, if any, within the company have been detected. These inherent limitations include the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions. Because of the inherent limitations in a cost-effective control system, misstatements due to error or fraud may occur and not be detected. We monitor our Disclosure Controls and Internal Controls and make modifications as necessary; our intent in this regard is that the Disclosure Controls and Internal Controls will be modified as systems change and conditions warrant.
Evaluation of Disclosure Controls and Procedures
An evaluation of the effectiveness of the design and operation of our Disclosure Controls was performed as of the end of the period covered by this report. This evaluation was performed under the supervision and with the participation of our management, including our Senior Vice President—West and our Vice President, Controller and Chief Accounting Officer. Based upon that evaluation, our Senior Vice President—West and our Vice President, Controller and Chief Accounting Officer concluded that these Disclosure Controls are effective at a reasonable assurance level.
Changes in Internal Control Over Financial Reporting
There have been no changes during the second quarter of 2017 that have materially affected, or are reasonably likely to materially affect, our Internal Control over Financial Reporting.
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PART II. OTHER INFORMATION
Item 1. Legal Proceedings
The information called for by this item is provided in Note 2. Contingent Liabilities and Commitments, included in the Notes to Financial Statements included under Part 1, Item 1. Financial Statements of this Form 10-Q, which information is incorporated by reference into this item.
Item 6. Exhibits
The following instruments are included as exhibits to this report.
Exhibit | Description | |
2 | Certificate of Conversion of Northwest Pipeline GP (Exhibit 2.1 to our report on Form 8-K, filed July 3, 2013 (File No. 001-07414)) and incorporated herein by reference. | |
3.1 | Certificate of Formation of Northwest Pipeline LLC (Exhibit 2.2 to our report on Form 8-K, filed July 3, 2013 (File No. 001-07414)) and incorporated herein by reference. | |
3.2 | Operating Agreement of Northwest Pipeline LLC (Exhibit 3.1 to our report on Form 8-K, filed July 3, 2013 (File No. 001-07414)) and incorporated herein by reference. | |
4.1 | Indenture, dated as of April 3, 2017, between Northwest Pipeline LLC and The Bank of New York Mellon Trust Company, N.A., as trustee (filed on April 3, 2017 as Exhibit 4.1 to Northwest Pipeline LLC’s current report on Form 8-K (File No. 0001-07414) and incorporated herein by reference). | |
10.1 | Registration Rights Agreement, dated April 3, 2017, between Northwest Pipeline LLC and the initial purchasers listed therein (filed on April 3, 2017 as Exhibit 10.1 to Northwest Pipeline LLC’s current report on Form 8-K (File No. 0001-07414) and incorporated herein by reference). | |
31.1* | Certification of Principal Executive Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of The Sarbanes-Oxley Act of 2002. | |
31.2* | Certification of Principal Financial Officer pursuant to Rules 13a-14(a) and 15d-14(a) promulgated under the Securities Exchange Act of 1934, as amended, and Item 601(b)(31) of Regulation S-K, as adopted pursuant to Section 302 of The Sarbanes-Oxley Act of 2002. | |
32** | Certification of Principal Executive Officer and Principal Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002. | |
101.INS* | XBRL Instance Document. | |
101.SCH* | XBRL Taxonomy Extension Schema. | |
101.CAL* | XBRL Taxonomy Extension Calculation Linkbase. | |
101.DEF* | XBRL Taxonomy Definition Linkbase. | |
101.LAB* | XBRL Taxonomy Extension Label Linkbase. | |
101.PRE* | XBRL Taxonomy Extension Presentation Linkbase. | |
* | Filed herewith. |
** | Furnished herewith. |
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SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
NORTHWEST PIPELINE LLC | |||
Registrant | |||
By: | /s/ Ted T. Timmermans | ||
Ted T. Timmermans Vice President, Controller and Chief Accounting Officer (Principal Accounting Officer) | |||
Date: August 3, 2017