10-Q

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
PART I. FINANCIAL INFORMATION:
Item 1. Financial Statements -
Statement of Comprehensive Income — Three and Six Months Ended June 30, 2017 and 2016	1
Balance Sheet — June 30, 2017 and December 31, 2016	2
Statement of Cash Flows — Three and Six Months Ended June 30, 2017 and 2016	4
Notes to Financial Statements	5
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	10
Item 4. Controls and Procedures	11
PART II. OTHER INFORMATION:
Item 1. Legal Proceedings	12
Item 6. Exhibits	12

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

i

• 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.

ii

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.

iii

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.

1

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.

2

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.

3

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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NORTHWEST PIPELINE LLC

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

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.

5

NORTHWEST PIPELINE LLC

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

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

6

NORTHWEST PIPELINE LLC

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

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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NORTHWEST PIPELINE LLC

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

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,

8

NORTHWEST PIPELINE LLC

NOTES TO FINANCIAL STATEMENTS

(Unaudited)

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.

9

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.

10

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.

11

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.

12

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

EX-31.1

Exhibit 31.1

SECTION 302 CERTIFICATION

I, Walter J. Bennett, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Northwest Pipeline LLC;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2017

By:	/s/ Walter J. Bennett
	Walter J. Bennett
	Sr. Vice President—West
	(Principal Executive Officer)

EX-31.2

Exhibit 31.2

SECTION 302 CERTIFICATION

I, Ted T. Timmermans, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Northwest Pipeline LLC;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report; 

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: August 3, 2017

By:	/s/ Ted T. Timmermans
	Ted T. Timmermans
	Vice President, Controller, and Chief Accounting Officer
	(Principal Financial Officer)

EX-32

Exhibit 32

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Northwest Pipeline LLC (the “Company”) on Form 10-Q for the period ending June 30, 2017 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), each of the undersigned hereby certifies, in his capacity as an officer of the Company, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that to his knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Walter J. Bennett

Walter J. Bennett

Senior Vice President—West

August 3, 2017

/s/ Ted T. Timmermans

Ted T. Timmermans

Vice President, Controller, and Chief Accounting Officer

August 3, 2017

A signed original of this written statement required by Section 906 has been provided to, and will be retained by, the Company and furnished to the Securities and Exchange Commission or its staff upon request.

The foregoing certification is being furnished to the Securities and Exchange Commission as an exhibit to the Report and shall not be considered filed as part of the Report.

XML

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2017	Aug. 03, 2017
Entity Information [Line Items]
Entity registrant name	Northwest Pipeline LLC
Entity central index key	0000110019
Document type	10-Q
Document period end date	Jun. 30, 2017
Amendment flag	false
Document fiscal year focus	2017
Document fiscal period focus	Q2
Current fiscal year end date	--12-31
Entity filer category	Non-accelerated Filer
Entity common stock, shares outstanding		0

XML

Statement of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 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	0	(13)	0	(28)
COMPREHENSIVE INCOME	$ 43,632	$ 39,949	$ 94,781	$ 87,055

XML

Balance Sheet (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
CURRENT ASSETS:
Cash	$ 0	$ 0
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
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

XML

Statement of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2017	Jun. 30, 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	0
Debt issue costs	(2,082)	0
Cash distributions to parent	(107,000)	(86,000)
Net cash used in financing activities	(44,980)	(261,000)
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	0	9,776
Net cash provided by (used in) investing activities	(109,943)	122,220
NET INCREASE (DECREASE) IN CASH	0	(169)
CASH AT BEGINNING OF PERIOD	0	169
CASH AT END OF PERIOD	0	0
Increases to property, plant and equipment	(33,894)	(18,451)
Changes in related in accounts receivable, accounts payable, and accrued liabilities	2,401	(4,392)
Capital expenditures, net of equity AFUDC	$ (31,493)	$ (22,843)

XML

Basis of Presentation (Notes)

6 Months Ended

Jun. 30, 2017

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

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.

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.

XML

Rate and Regulatory Matters (Notes)

6 Months Ended

Jun. 30, 2017

Public Utilities, Rate Matters [Abstract]

Public Utilities, Disclosure of Rate Matters [Text Block]

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.

XML

Contingent Liabilities and Commitments (Notes)

6 Months Ended

Jun. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Contingent Liabilities and Commitments

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 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.

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Debt and Financing Arrangement (Notes)

6 Months Ended

Jun. 30, 2017

Debt Disclosure [Abstract]

Debt and Financing Arrangement

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

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.

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Financial Instruments (Notes)

6 Months Ended

Jun. 30, 2017

Fair Value Disclosures [Abstract]

Financial Instruments

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.

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Transactions with Affiliates (Notes)

6 Months Ended

Jun. 30, 2017

Related Party Transactions [Abstract]

Transactions with Affiliates

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, 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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Basis of Presentation (Details)	1 Months Ended	6 Months Ended
	Jan. 31, 2017	Jun. 30, 2017
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Parent, limited partner ownership percentage		74.00%
Financial Repositioning [Member]
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Parent, general partner ownership percentage	2.00%

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Rate and Regulatory Matters (Details) $ in Millions	Oct. 01, 2018 $ / dekatherm	Jan. 01, 2018 $ / dekatherm	Jan. 23, 2017 USD ($)
Public Utilities, General Disclosures [Line Items]
Annual Cost of Service Pending | $			$ 440
Subsequent Event [Member] | Phase 1 Demand Rate per Dth Pending [Member]
Public Utilities, General Disclosures [Line Items]
Demand Rate Pending		0.39294
Subsequent Event [Member] | Phase 1 Commodity Rate Pending [Member]
Public Utilities, General Disclosures [Line Items]
Commodity Rate Pending		0.00832
Subsequent Event [Member] | Phase 2 Demand Rate per Dth Pending [Member]
Public Utilities, General Disclosures [Line Items]
Demand Rate Pending	0.39033
Subsequent Event [Member] | Phase 2 Commodity Rate Pending [Member]
Public Utilities, General Disclosures [Line Items]
Commodity Rate Pending	0.00832

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Contingent Liabilities and Commitments (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Environmental Matters [Abstract]
Environmental assessment and remediation costs, undiscounted	$ 4.4
Accrued environmental liabilities	$ 4.4	$ 4.4

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Debt and Financing Arrangement (Details) $ in Millions	Jun. 30, 2017 USD ($)
Line of Credit Facility [Line Items]
Commercial paper, outstanding	$ 0.0
Williams Partners L.P. [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	3,500.0
$3.5 billion credit facility [Member]
Line of Credit Facility [Line Items]
Additional Amount By Which Credit Facility Can Be Increased	500.0
Letters of credit outstanding, amount	0.0
Line of credit facility, amount outstanding	0.0
$3.5 billion credit facility [Member] | Williams Partners L.P. [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	3,000.0
$3.5 billion credit facility [Member] | Letter of credit | Williams Partners L.P. [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,125.0

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Debt and Financing Arrangement Long-term Debt Instruments (Details) - USD ($) $ in Thousands	Apr. 15, 2017	Jun. 30, 2017	Apr. 03, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Additional Interest Rate Accrued For Default Of Registration Rights Agreements First Period			0.25%
Additional Interest Rate Accrued For Default Of Registration Rights Agreements Each Subsequent Period			0.25%
Maximum Additional Interest Rate Accrued For Default Of Registration Rights Agreements All Periods			0.50%
Long-term debt due within one year		$ 249,737		$ 184,924
4% Senior Unsecured Notes Due 2027 [Member]
Debt Instrument [Line Items]
Long-term debt, face amount			$ 250,000
Senior Unsecured Interest Rate			4.00%
5.95% Senior Unsecured Notes due 2017 [Member]
Debt Instrument [Line Items]
Retirement of Long-Term Debt	$ 185,000
Senior Unsecured Interest Rate	5.95%
6.05% due 2018 [Member]
Debt Instrument [Line Items]
Senior Unsecured Interest Rate		6.05%
Long-term debt due within one year		$ 250,000

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Financial Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Carrying (reported) amount, fair value disclosure [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt including current maturities	$ 581.5	$ 519.2
Estimate of fair value, fair value disclosure [Member] | Fair value, inputs, level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Long-term debt including current maturities	$ 614.5	$ 546.8

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Transactions with Affiliates (Details) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Jul. 31, 2017 USD ($)	Jun. 30, 2017 USD ($) employee	Jun. 30, 2016 USD ($)	Jun. 30, 2017 USD ($) employee	Jun. 30, 2016 USD ($)	Dec. 31, 2016 USD ($)
Related Party Transaction [Line Items]
Advances to affiliate		$ 123,999		$ 123,999		$ 45,137
Related party transaction, rate				0.83%
Entity number of employees | employee		0		0
Related party transaction, expenses from transactions with related party		$ 23,200	$ 21,100	$ 46,200	$ 46,100
Severance and other related costs					2,000
Cash distributions to parent				107,000	$ 86,000
Williams Partners L.P. [Member]
Related Party Transaction [Line Items]
Advances to affiliate		$ 124,000		$ 124,000		$ 45,100
Subsequent Event [Member]
Related Party Transaction [Line Items]
Cash distributions to parent	$ 41,000