Exhibit 99(g)

CONSOLIDATED FINANCIAL STATEMENTS

With Report of Independent Registered Public Accounting Firm

SOUTHERN NATURAL GAS COMPANY, L.L.C.

As of December 31, 2017 and 2016 and

For the Year Ended December 31, 2017 and the Four Months Ended December 31, 2016

SOUTHERN NATURAL GAS COMPANY, L.L.C. AND SUBSIDIARY

TABLE OF CONTENTS

	Page Number
Report of Independent Registered Public Accounting Firm	1
Consolidated Financial Statements	2
Consolidated Statements of Income	2
Consolidated Balance Sheets	3
Consolidated Statements of Cash Flows	4
Consolidated Statements of Members' Equity	5
Notes to Consolidated Financial Statements	6

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Members of Southern Natural Gas Company, L.L.C.

Opinion on the Financial Statements

We have audited the accompanying consolidatedbalance sheets of Southern Natural Gas Company, L.L.C. and its subsidiary (the “Company”) as of December 31, 2017 and 2016, and the related consolidated statements of income, of cash flows and of members’ equity for the year ended December 31, 2017 and for the four months ended December 31, 2016, including the related notes (collectively referred to as the “consolidatedfinancial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as ofDecember 31, 2017 and 2016, and the results of their operations and their cash flows for the year ended December 31, 2017 and for the four months ended December 31, 2016in conformity with accounting principles generally accepted in the United States of America.

Basis for Opinion

These consolidatedfinancial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidatedfinancial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits of these consolidatedfinancial statements in accordance with the auditing standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud.

Our audits included performing procedures to assess the risks of material misstatement of the consolidatedfinancial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

Significant Transactions with Related Parties

As discussed in Note 6 to the consolidated financial statements, the Company has entered into significant transactions with related parties.

/s/ PricewaterhouseCoopers LLP

Houston, Texas

February 14, 2018

We have served as the Company's auditor since 2012.

1

SOUTHERN NATURAL GAS COMPANY, L.L.C. AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF INCOME

(In Millions)

	Year Ended December 31, 2017			Four Months Ended December 31, 2016
Revenues	$	544		$	230
Operating Costs and Expenses
Operations and maintenance	146			39
Depreciation and amortization	85			27
General and administrative	30			13
Taxes, other than income taxes	37			13
Total Operating Costs and Expenses	298			92
Operating Income	246			138
Other Income (Expense)
Earnings from equity investment	8			2
Interest, net	(69		)	(26		)
Other, net	(10		)	1
Total Other Income (Expense)	(71		)	(23		)
Net Income	$	175		$	115

The accompanying notes are an integral part of these consolidated financial statements.

2

SOUTHERN NATURAL GAS COMPANY, L.L.C. AND SUBSIDIARY

CONSOLIDATED BALANCE SHEETS

(In Millions)

	December 31,
	2017		2016
ASSETS
Current assets
Cash and cash equivalents	$	4	$	4
Accounts receivable, net	35		47
Accounts receivable from affiliates	19		18
Inventories	18		19
Other current assets	6		7
Total current assets	82		95
Property, plant and equipment, net	2,439		2,451
Investment	63		61
Regulatory assets	23		36
Deferred charges and other assets	35		32
Total Assets	$	2,642	$	2,675
LIABILITIES AND MEMBERS' EQUITY
Current liabilities
Current portion of debt	$	13	$	500
Accounts payable	21		25
Accounts payable to affiliates	15		9
Accrued interest	17		19
Accrued taxes, other than income taxes	20		22
Regulatory liabilities	15		3
Other current liabilities	9		10
Total current liabilities	110		588
Long-term liabilities and deferred credits
Long-term debt, net of debt issuance costs	1,102		706
Other long-term liabilities and deferred credits	76		22
Total long-term liabilities and deferred credits	1,178		728
Total Liabilities	1,288		1,316
Commitments and contingencies(Note 9)
Members' Equity	1,354		1,359
Total Liabilities and Members' Equity	$	2,642	$	2,675

The accompanying notes are an integral part of these consolidated financial statements.

3

SOUTHERN NATURAL GAS COMPANY, L.L.C. AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In Millions)

	Year Ended December 31, 2017			Four Months Ended December 31, 2016
Cash Flows From Operating Activities
Net income	$	175		$	115
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	85			27
Earnings from equity investment	(8		)	(2		)
Other non-cash items	1			1
Distributions from equity investment earnings	6			3
Changes in components of working capital:
Accounts receivable	8			(7		)
Regulatory assets	2			5
Accounts payable	1			10
Accrued interest	(2		)	(7		)
Accrued taxes, other than income	(2		)	(4		)
Regulatory liabilities	12			1
Other current assets and liabilities	3			—
Other long-term assets and liabilities	50			(1		)
Net Cash Provided by Operating Activities	331			141
Cash Flows From Investing Activities
Capital expenditures	(53		)	(33		)
Other, net	(5		)	—
Net Cash Used in by Investing Activities	(58		)	(33		)
Cash Flows From Financing Activities
Issuances of debt	570			56
Payments of debt	(659		)	(56		)
Debt issuance costs	(4		)	—
Contributions from Members	108			15
Distributions to Members	(288		)	(119		)
Net Cash Used in Financing Activities	(273		)	(104		)
Net Change in Cash and Cash Equivalents	—			4
Cash and Cash Equivalents, beginning of period	4			—
Cash and Cash Equivalents, end of period	$	4		$	4
Supplemental Disclosure of Cash Flow Information
Cash paid during the period for interest (net of capitalized interest)	$	69		$	24

The accompanying notes are an integral part of these consolidated financial statements.

4

SOUTHERN NATURAL GAS COMPANY, L.L.C. AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF MEMBERS' EQUITY

(In Millions)

	Year Ended December 31, 2017			Four Months Ended December 31, 2016
Beginning Balance	$	1,359		$	1,348
Net income	175			115
Contributions	108			15
Distributions	(288		)	(119		)
Ending Balance	$	1,354		$	1,359

The accompanying notes are an integral part of these consolidated financial statements.

5

SOUTHERN NATURAL GAS COMPANY, L.L.C. AND SUBSIDIARY

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. General

We are a Delaware limited liability company, originally formed in 1935 as a corporation. When we refer to “us,” “we,” “our,” “ours,” “the Company,” or “SNG,” we are describing Southern Natural Gas Company, L.L.C and its consolidated subsidiary.

The member interests in us are as follows:

•50.0% - Kinder Morgan SNG Operator, LLC, an indirect subsidiary of Kinder Morgan, Inc. (KMI); and

•50.0% - Evergreen Enterprise Holdings, LLC, an indirect subsidiary of The Southern Company (TSC).

Our operations are regulated by the Federal Energy Regulatory Commission (FERC) under the Natural Gas Act of 1938, the Natural Gas Policy Act of 1978 and the Energy Policy Act of 2005. The FERC approves tariffs that establish rates, cost recovery mechanisms and other terms and conditions of service to our customers.

Our primary business consists of the interstate transportation and storage of natural gas. Our natural gas pipeline system consists of approximately 6,900 miles of pipeline with a design capacity of approximately 4.2 billion cubic feet (Bcf) per day for natural gas. This pipeline system extends from supply basins in Louisiana, Mississippi and Alabama to market areas in Louisiana, Mississippi, Alabama, Florida, Georgia, South Carolina and Tennessee, including the metropolitan areas of Atlanta and Birmingham. We also own and operate 100% of the Muldon storage facility in Monroe County, Mississippi and own a 50% interest in Bear Creek Storage Company, L.L.C. (Bear Creek) in Bienville Parish, Louisiana. Bear Creek is a joint venture equally owned by us and Tennessee Gas Pipeline Company, L.L.C., an affiliate. Our interest in Bear Creek, the Muldon storage facilities and contracted storage have a combined working natural gas storage capacity of approximately 68 Bcf and peak withdrawal capacity of approximately 1.3 Bcf per day.

2. Summary of Significant Accounting Policies

Basis of Presentation

We have prepared our accompanying consolidated financial statements in accordance with the accounting principles contained in the Financial Accounting Standards Board's (FASB) Accounting Standards Codification, the single source of United States Generally Accepted Accounting Principles (GAAP) and referred to in this report as the Codification. Additionally, certain amounts from the prior year have been reclassified to conform to the current presentation.

Management has evaluated subsequent events through February 14, 2018, the date the financial statements were available to be issued.

Principles of Consolidation

We consolidate entities when we have the ability to control or direct the operating and financial decisions of the entity or when we have a significant interest in the entity that gives us the ability to direct the activities that are significant to that entity. The determination of our ability to control, direct or exert significant influence over an entity involves the use of judgment. All significant intercompany items have been eliminated in consolidation.

Use of Estimates

Certain amounts included in or affecting our financial statements and related disclosures must be estimated, requiring us to make certain assumptions with respect to values or conditions which cannot be known with certainty at the time our financial statements are prepared. These estimates and assumptions affect the amounts we report for assets and liabilities, our revenues and expenses during the reporting period, and our disclosures, including as it relates to contingent assets and liabilities at the date of our financial statements. We evaluate these estimates on an ongoing basis, utilizing historical experience, consultation with experts and other methods we consider reasonable in the particular circumstances. Nevertheless, actual results may differ significantly from our estimates. Any effects on our business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known.

6

In addition, we believe that certain accounting policies are of more significance in our financial statement preparation process than others, and set out below are the principal accounting policies we apply in the preparation of our consolidated financial statements.

Cash Equivalents

We define cash equivalents as all highly liquid short-term investments with original maturities of three months or less.

Accounts Receivable, net

We establish provisions for losses on accounts receivable due from shippers and operators if we determine that we will not collect all or part of the outstanding balance. We regularly review collectability and establish or adjust our allowance as necessary using the specific identification method. The allowance for doubtful accounts as of December 31, 2017 and 2016 was not significant.

Inventories

Our inventories, which consist of materials and supplies, are valued at weighted-average cost, and we periodically review for physical deterioration and obsolescence.

Natural Gas Imbalances

Natural gas imbalances occur when the amount of natural gas delivered from or received by a pipeline system or storage facility differs from the scheduled amount of gas to be delivered or received. We value these imbalances due to or from shippers and operators at current index prices. Imbalances are settled in cash or made up in-kind, subject to the terms of our FERC tariff. Imbalances due from others are reported on our accompanying Consolidated Balance Sheets in “Other current assets.” Imbalances owed to others are reported on our accompanying Consolidated Balance Sheets in “Other current liabilities.” We classify all imbalances due from or owed to others as current as we expect to settle them within a year.

Property, Plant and Equipment, net

Our property, plant and equipment is recorded at its original cost of construction or, upon acquisition, at either the fair value of the assets acquired or the cost to the entity that first placed the asset in utility service. For constructed assets, we capitalize all construction-related direct labor and material costs, as well as indirect construction costs. Our indirect construction costs primarily include an interest and equity return component (as more fully described below) and labor and related costs associated with supporting construction activities. The indirect capitalized labor and related costs are based upon estimates of time spent supporting construction projects.

We use the composite method to depreciate property, plant and equipment. Under this method, assets with similar economic characteristics are grouped and depreciated as one asset. The FERC-accepted depreciation rate is applied to the total cost of the group until the net book value equals the salvage value. For certain general plant, the asset is depreciated to zero. As part of periodic filings with the FERC, we also re-evaluate and receive approval for our depreciation rates. When property, plant and equipment is retired, accumulated depreciation and amortization is charged for the original cost of the assets in addition to the cost to remove, sell or dispose of the assets, less salvage value. We do not recognize gains or losses unless we sell land or an entire operating unit (as approved by the FERC). In those instances where we receive recovery in rates related to losses on dispositions of operating units, we record a regulatory asset for the estimated recoverable amount.

Included in our property balances are base gas and working gas at our storage facilities. We periodically evaluate natural gas volumes at our storage facilities for gas losses. When events or circumstances indicate a loss has occurred, we recognize a loss on our accompanying Consolidated Statements of Income or defer the loss as a regulatory asset on our accompanying Consolidated Balance Sheets if deemed probable of recovery through future rates charged to customers.

We capitalize a carrying cost (an allowance for funds used during construction or AFUDC) on debt and equity funds related to the construction of long-lived assets. This carrying cost consists of a return on the investment financed by debt and a return on the investment financed by equity. The debt portion is calculated based on our average cost of debt. Interest costs capitalized are included as a reduction in “Interest, net” on our accompanying Consolidated Statements of Income. The equity portion is calculated based on our most recent FERC approved rate of return. Equity amounts capitalized are included in “Other, net” on our accompanying Consolidated Statements of Income. The amounts of capitalized AFUDC were not significant for the year ended December 31, 2017 and the four months ended December 31, 2016.

7

Asset Retirement Obligations (ARO)

We record liabilities for obligations related to the retirement and removal of long-lived assets used in our businesses. We record, as liabilities, the fair value of ARO on a discounted basis when they are incurred and can be reasonably estimated, which is typically at the time the assets are installed or acquired.  Amounts recorded for the related assets are increased by the amount of these obligations. Over time, the liabilities increase due to the change in their present value, and the initial capitalized costs are depreciated over the useful lives of the related assets.  The liabilities are eventually extinguished when the asset is taken out of service.

We are required to operate and maintain our natural gas pipelines and storage systems, and intend to do so as long as supply and demand for natural gas exists, which we expect for the foreseeable future. Therefore, we believe that we cannot reasonably estimate the ARO for the substantial majority of our assets because these assets have indeterminate lives. We continue to evaluate our ARO and future developments could impact the amounts we record. Our recorded ARO were not significant as of December 31, 2017 and 2016.

Asset and Investment Impairments

We evaluate our assets and investments for impairment when events or circumstances indicate that their carrying values may not be recovered. These events include market declines that are believed to be other than temporary, changes in the manner in which we intend to use a long-lived asset, decisions to sell an asset or investment and adverse changes in market conditions or in the legal or business environment such as adverse actions by regulators. If an event occurs, which is a determination that involves judgment, we evaluate the recoverability of our carrying value based on either (i) the long-lived asset's ability to generate future cash flows on an undiscounted basis or (ii) the fair value of the investment in an unconsolidated affiliate. If an impairment is indicated, or if we decide to sell a long-lived asset or group of assets, we adjust the carrying value of the asset downward, if necessary, to its estimated fair value.

Our fair value estimates are generally based on assumptions market participants would use, including market data obtained through the sales process or an analysis of expected discounted future cash flows. There were no impairments for the year ended December 31, 2017 and the four months ended December 31, 2016.

Equity Method of Accounting

We account for investments, which we do not control but do have the ability to exercise significant influence, by the equity method of accounting. Under this method, our equity investments are carried originally at our acquisition cost, increased by our proportionate share of the investee’s net income and by contributions made, and decreased by our proportionate share of the investee’s net losses and by distributions received.

Revenue Recognition

We are subject to FERC regulations, therefore fees and rates established under our tariff are a function of our cost of providing services to our customers, including a reasonable return on our invested capital. Our revenues are primarily generated from natural gas transportation and storage services and include estimates of amounts earned but unbilled. We estimate these unbilled revenues based on contract data, regulatory information, and preliminary throughput and allocation measurements, among other items. Revenues for all services are based on the thermal quantity of gas delivered or subscribed at a price specified in the contract. For our transportation services and storage services, we recognize reservation revenues on firm contracted capacity ratably over the contract period regardless of the amount of natural gas that is transported or stored. For interruptible or volumetric-based services, we record revenues when physical deliveries of natural gas are made at the agreed upon delivery point or when gas is injected or withdrawn from the storage facility. For contracts with step-up or step-down rate provisions that are not related to changes in levels of service, we recognize reservation revenues ratably over the contract life. The revenues we collect may be subject to refund in a rate proceeding.

For the year ended December 31, 2017, revenues from our two largest customers (one affiliate and one third party) were approximately $269 million, and $55 million, each of which exceeded 10% of our operating revenues. For the the four months ended December 31, 2016, revenues from our largest affiliate and non-affiliate customers were approximately $89 million and $52 million, respectively, each of which exceeded 10% of our operating revenues for that period, see Note 6. Amounts for both periods include contracted capacity released by customers to third parties.

In September 2016, we recognized revenue of $37 million from an early termination of a customer contract.

8

Environmental Matters

We capitalize or expense, as appropriate, environmental expenditures. We capitalize certain environmental expenditures required in obtaining rights-of-way, regulatory approvals or permitting as part of the construction. We accrue and expense environmental costs that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation. We generally do not discount environmental liabilities to a net present value, and we record environmental liabilities when environmental assessments and/or remedial efforts are probable and we can reasonably estimate the costs. Generally, our recording of these accruals coincides with our completion of a feasibility study or our commitment to a formal plan of action. We recognize receivables for anticipated associated insurance recoveries when such recoveries are deemed to be probable.

We routinely conduct reviews of potential environmental issues and claims that could impact our assets or operations. These reviews assist us in identifying environmental issues and estimating the costs and timing of remediation efforts. We also routinely adjust our environmental liabilities to reflect changes in previous estimates. In making environmental liability estimations, we consider the material effect of environmental compliance, pending legal actions against us, and potential third-party liability claims. Often, as the remediation evaluation and effort progresses, additional information is obtained, requiring revisions to estimated costs. These revisions are reflected in our income in the period in which they are reasonably determinable. For more information on our environmental matters, see Note 9.

Other Contingencies

We recognize liabilities for other contingencies when we have an exposure that indicates it is both probable that a liability has been incurred and the amount of loss can be reasonably estimated. Where the most likely outcome of a contingency can be reasonably estimated, we accrue an undiscounted liability for that amount. Where the most likely outcome cannot be estimated, a range of potential losses is established and if no one amount in that range is more likely than any other, the low end of the range is accrued.

Postretirement Benefits

We maintain a postretirement benefit plan covering certain of our former employees that we have made contributions to in the past. These contributions are invested until the benefits are paid to plan participants. The net benefit cost of this plan is recorded on our accompanying Consolidated Statements of Income and is a function of many factors including expected returns on plan assets and amortization of certain deferred gains and losses. For more information on our policies with respect to our postretirement benefit plan, see Note 5.

In accounting for our postretirement benefit plan, we record an asset or liability based on the difference between the fair value of the plan's assets and the plan's benefit obligation. Any deferred amounts related to unrecognized gains and losses or changes in actuarial assumptions are recorded on our Consolidated Balance Sheets as a regulatory asset or liability until those gains or losses are recognized on our accompanying Consolidated Statements of Income.

Income Taxes

We are a limited liability company and are not subject to federal or state income taxes. Our Members are responsible for income taxes on their allocated share of taxable income which may differ from income for financial statement purposes due to differences in the tax basis and financial reporting basis of assets and liabilities. However, we are subject to Texas margin tax (a revenue based calculation).

Regulatory Assets and Liabilities

Our interstate natural gas pipeline and storage operations are subject to the jurisdiction of the FERC and are accounted for in accordance with Accounting Standards Codification Topic 980, “Regulated Operations.” Under these standards, we record regulatory assets and liabilities that would not be recorded for non-regulated entities. Regulatory assets and liabilities represent probable future revenues or expenses associated with certain charges and credits that are expected to be recovered from or refunded to customers through the ratemaking process. Items to which we apply regulatory accounting requirements include certain postretirement employee benefit plan costs, losses on reacquired debt, taxes related to an equity return component on regulated capital projects prior to our change in legal structure to a non taxable entity, certain differences between gas retained and gas consumed in operations, amounts associated with the Tax Cuts and Jobs Act of 2017 (2017 Tax Reform) and other costs included in, or expected to be included in, future rates. For more information on our regulated operations, see Note 8.

9

3. Property, Plant and Equipment, net

Our property, plant and equipment, net consisted of the following (in millions, except for %):

		December 31,
	Annual Depreciation Rates %	2017			2016
Transmission and storage facilities	0.9-2.25	$	3,648		$	3,570
General plant	3.33-20	19			25
Intangible plant	5-10	20			19
Other		129			116
Accumulated depreciation and amortization(a)		(1,412		)	(1,344		)
		2,404			2,386
Land		13			12
Construction work in progress		22			53
Property, plant and equipment, net		$	2,439		$	2,451

_______________

(a) The composite weighted average depreciation rate for the year ended December 31, 2017 and the four months ended December 31, 2016 was approximately 2.3%.

4. Debt

We classify our debt based on the contractual maturity dates of the underlying debt instruments. We defer costs associated with debt issuance over the applicable term. These costs are then amortized as interest expense on our accompanying Consolidated Statements of Income.

The following table summarizes the net carrying value of our outstanding debt (in millions):

	December 31,
	2017		2016
5.90% Notes due April 2017	$	—	$	500
4.40% Notes due June 2021	300		300
7.35% Notes due February 2031	153		153
8.00% Notes due March 2032	258		258
4.80% Senior Notes due March 2047	400		—
Credit Facility	13		—
	1,124		1,211
Less: Unamortized discount and debt issuance costs	9		5
Total debt	$	1,115	$	1,206
Less: Current portion of debt	13		500
Total long-term debt	$	1,102	$	706

Credit Facility

Effective September 1, 2016, we entered into a $75 million, unsecured, 5-year revolving credit facility (Credit Facility). The facility is with a syndicate of financial institutions with Barclays Bank PLC as the administrative agent. Borrowings under our Credit Facility can be used for working capital and other general corporate purposes and are included within the caption “Current portion of debt” on our accompanying Consolidated Balance Sheet.

Our Credit Facility borrowings bear interest at either (i) London Interbank Offered Rate (LIBOR) plus an applicable margin ranging from 0.875% to 1.50% per annum based on our credit ratings or (ii) the greatest of the (a) Federal Funds Effective rate plus ½ of 1%, (b) the Prime Rate in effect for such day, and (c) the LIBOR rate for a one-month Eurodollar loan plus 1%, plus, in each

10

case, an applicable margin ranging from nil to 1.5%. In addition, we have agreed to pay the administrative agent a commitment fee, based on our credit rating, ranging from 0.075% to 0.200%.

Our Credit Facility includes the following restrictive covenants:

• total debt divided by earnings before interest, income taxes, depreciation and amortization may not exceed 5.00 to 1.00;

• certain limitations on indebtedness, including payments and amendments;

• certain limitations on entering into mergers, consolidations, sales of assets and investments;

• limitations on granting liens; and

• prohibitions on making any distributions if an event of default exists or would exist upon making such a distribution.

As of December 31, 2017, we had $13 million of borrowings outstanding under our Credit Facility. As of December 31, 2016, we had no borrowings outstanding under our Credit Facility. As of December 31, 2017 and 2016, we were in compliance with all required covenants.

Debt Issuance and Repayment

On March 15, 2017 we issued $400 million of 4.80% senior notes due March 2047 and incurred debt issuance costs of $4 million. On April 3, 2017 we used the net proceeds of $399 million received from the debt issuance and equity contributions from our Members to repay $500 million of our 5.90% notes due April 2017.

Debt Covenants

Under our various other financing documents, we are subject to certain restrictions and covenants. The most restrictive of these include limitations on the incurrence of liens and limitations on sale-leaseback transactions. For the year ended December 31, 2017 and the four months ended December 31, 2016, we were in compliance with our debt-related covenants.

5. Retirement Benefits

Pension and Retirement Savings Plans

KMI maintains a pension plan and a retirement savings plan covering substantially all of its U.S. employees, including certain of our former employees. The benefits under the pension plan are determined under a cash balance formula. Under its retirement savings plan, KMI contributes an amount equal to 5% of participants’ eligible compensation per year. KMI is responsible for benefits accrued under its plans and allocates certain costs based on a benefit allocation rate applied on payroll charged to its affiliates.

Postretirement Benefits Plan

We provide postretirement benefits, including medical benefits for a closed group of retirees. Medical benefits for pre-age 65 participants of this closed group may be subject to deductibles, co-payment provisions, dollar caps and other limitations on the amount of employer costs, and are subject to further benefit changes by KMI, the plan sponsor. Post-age 65 Medicare eligible participants are provided a fixed subsidy to purchase coverage through a retiree Medicare exchange. In addition, certain former employees continue to receive limited postretirement life insurance benefits. Our postretirement benefit plan costs were prefunded and were recoverable under prior rate case settlements. Currently, there is no cost recovery or related funding that is required as part of our current FERC approved rates, however, we can seek to recover any funding shortfall that may be required in the future. We do not expect to make any contributions to our postretirement benefit plan in 2018 and there were no contributions made in 2017 and 2016. KMI's postretirement plans have been merged. Prior to September 1, 2016, KMI used combined plan assets under the structure of the plans of its affiliated entities to fund participant benefits, including participants of affiliated entities.

Postretirement Benefit Obligation, Plan Assets and Funded Status

Our postretirement benefit obligations and net benefit costs are primarily based on actuarial calculations. We use various assumptions in performing these calculations, including those related to the return that we expect to earn on our plan assets, the estimated cost of health care when benefits are provided under our plan and other factors. A significant assumption we utilize is the discount rates used in calculating the benefit obligations. The discount rate used in the measurement of our postretirement benefit obligation is determined by matching the timing and amount of our expected future benefit payments for our postretirement benefit obligation to the average yields of various high-quality bonds with corresponding maturities. The service and interest cost

11

components of net periodic benefit cost (credit) for our other postretirement benefit plan are estimated by utilizing a full yield curve approach by applying the specific spot rates along the yield curve used in the determination of the benefit obligation to their underlying projected cash flows.

The table below provides information about our postretirement benefit plan (in millions):

	Year Ended December 31, 2017			Four Months Ended December 31, 2016
Change in plan assets:
Fair value of plan assets - beginning of period	$	58		$	57
Actual return on plan assets	5			2
Benefits paid	(3		)	(1		)
Fair value of plan assets - end of period	$	60		$	58
Change in postretirement benefit obligation:
Postretirement benefit obligation - beginning of period	$	29		$	30
Interest cost(a)	1			—
Actuarial gain(b)	—			—
Benefits paid	(3		)	(1		)
Postretirement benefit obligation - end of period	$	27		$	29
Reconciliation of funded status:
Fair value of plan assets	$	60		$	58
Less: Postretirement benefit obligation	27			29
Net asset at December 31(c)	$	33		$	29

_______________

(a) Amount during the four months ended December 31, 2016 was less than $500,000.

(b) Amounts during the year ended December 31, 2017 and the four months ended December 31, 2016 were less than $500,000.

(c) Net asset amounts are included in “Deferred charges and other assets” on our accompanying Consolidated Balance Sheets.

Plan Assets

The primary investment objective of our plan is to ensure that, over the long-term life of the plan, an adequate pool of sufficiently liquid assets exists to meet the benefit obligations to retirees and beneficiaries. Investment objectives are long-term in nature covering typical market cycles. Any shortfall of investment performance compared to investment objectives is generally the result of economic and capital market conditions. Although actual allocations vary from time to time from our targeted allocations, the target allocations of our postretirement plan’s assets are 30% equity, 30% fixed income and 40% master limited partnerships.

Below are the details of the postretirement benefit plan assets by class and a description of the valuation methodologies used for assets measured at fair value.

▪ Level 1 assets' fair values are based on quoted market prices for the instruments in actively traded markets. Included in this are equities and master limited partnerships using the quoted prices in actively traded markets;

▪ Level 2 assets' fair values are primarily based on pricing, data representative of quoted prices for similar assets in active markets (or identical assets in less active markets). Included in this are short term investment funds which are valued at cost plus calculated interest; and

▪ Plan assets with fair values that are based on the net asset value per share, or its equivalent (NAV), as reported by the issuers are determined based on the fair value of the underlying securities as of the valuation date and include private limited partnerships and fixed income trusts. The plan assets measured at NAV are not categorized within the fair value hierarchy described above, but are separately identified in the table below.

12

Listed below are the fair values of the plan's assets that are recorded at fair value by class and categorized by fair value measurement used at December 31, 2017 and 2016 (in millions):

	2017						2016
	Level 1		Level 2		Total		Level 1		Level 2		Total
Short-term investment fund (money market)	$	—	$	1	$	1	$	—	$	1	$	1
Equity securities, domestic	5		—		5		3		—		3
Master limited partnerships	14		—		14		14		—		14
Total assets in fair value hierarchy	$	19	$	1	$	20	$	17	$	1	$	18
Investments measured at NAV(a)					40						40
Investments at fair value					$	60					$	58

_______________

(a) In accordance with Subtopic 820-10 of Accounting Standards Update (ASU) No. 2015-07, Fair Value Measurement (Topic 820), certain Plan assets that were measured at NAV per share (or its equivalent) have not been classified in the fair value hierarchy. The fair value of the fixed income trusts as of December 31, 2017 and 2016 is $18 million and $15 million, respectively. The fair value of the private limited partnerships as of December 31, 2017 and 2016 is $22 million and $25 million, respectively.

Expected Payment of Future Benefits

As of December 31, 2017, we expect the following benefit payments under our plan (in millions):

Year	Total
2018	$	3
2019	3
2020	2
2021	2
2022	2
2023 - 2027	9

Actuarial Assumptions and Sensitivity Analysis

Postretirement benefit obligations and net benefit costs are based on actuarial estimates and assumptions. The following table details the weighted average actuarial assumptions used in determining our postretirement plan obligations and net benefit costs.

	2017	2016
	(%)
Assumptions related to benefit obligations at December 31:
Discount rate	3.45	3.63
Assumptions related to benefit costs for the year ended December 31:
Discount rate for benefit obligations	3.63	3.82
Discount rate for interest on benefit obligations	2.93	2.98
Expected return on plan assets(a)	7.00	7.25

_______________

(a) The expected return on plan assets listed in the table above is a pre-tax rate of return based on our portfolio of investments. We utilize an after-tax expected return on plan assets to determine our benefit costs, which is based on unrelated business income taxes with a weighted average rate of 21% for both 2017 and 2016.

Actuarial estimates for our postretirement benefits plan assumed a weighted average annual rate of increase in the per capita costs of covered health care benefits of 6.41%, gradually decreasing to 4.54% by the year 2038. A one-percentage point change in assumed health care trends would not have had a significant effect on the postretirement benefit obligation or interest costs as of and for the year ended December 31, 2017 and the four months ended December 31, 2016.

13

Components of Net Benefit Income

The components of net benefit costs (income) are as follows (in millions):

	Year Ended December 31, 2017			Four Months Ended December 31, 2016
Interest cost(a)	$	1		$	—
Expected return on plan assets	(3		)	(1		)
Amortization of prior service credit(a)	(2		)	—
Net benefit income	$	(4	)	$	(1	)

_______________

(a) Amounts during the four months ended December 31, 2016 were less than $500,000.

6. Related Party Transactions

Affiliate Balances and Activities

We enter into transactions with our affiliates within the ordinary course of business, including natural gas transportation services to and from affiliates under long-term contracts, storage contracts and various operating agreements, and the services are based on the same terms as non-affiliates. As of December 31, 2017 and 2016, we had approximately $1 million of natural gas imbalance receivable with our affiliates which is included in “Other current assets” on our accompanying Consolidated Balance Sheets.

We do not have employees and are operated by an indirect subsidiary of KMI; therefore, KMI employees provide services to us. Subsequent to TSC's acquisition, we entered into an Operations and Management Agreement (O&M Agreement) with Kinder Morgan SNG Operator, LLC, a subsidiary of KMI, whereby we reimburse KMI monthly for direct operating expenses incurred on our behalf and pay a fixed annual fee for general and administrative costs. The fixed fee for the year ended December 31, 2017 and the four months ended December 31, 2016 was $30 million and $13 million, respectively. The fixed fee will be $31 million for each of the years 2018 through 2020, and is subject to review and approval for each of the next four years pursuant to the O&M Agreement. These costs are reflected, as appropriate, in the “Operations and maintenance”, “General and administrative” and “Capitalized costs” lines in the table below.

The following table shows revenues and costs from our affiliates (in millions):

	Year Ended December 31, 2017		Four Months Ended December 31, 2016
Revenues	$	200	$	67
Operations and maintenance	90		24
General and administrative	30		13
Capitalized costs	9		4

Subsequent Event

In January 2018, we made a cash distribution to our Members of $22 million and received contributions from our Members of approximately $21 million.

14

7. Fair Value

The following table reflects the carrying amount and estimated fair value of our outstanding debt balances (in millions):

	As of December 31,
	2017		2016
	Carrying Amount	Estimated Fair Value	Carrying Amount	Estimated Fair Value
Total debt	$1,115	$1,302	$1,206	$1,312

We separate the fair values of our financial instruments into levels based on our assessment of the availability of observable market data and the significance of non-observable data used to determine the estimated fair value. We estimated the fair values of our outstanding debt balance primarily based on quoted market prices for the same or similar issues, a Level 2 fair value measurement. Our assessment and classification of an instrument within a level can change over time based on the maturity or liquidity of the instrument and this change would be reflected at the end of the period in which the change occurs. During the year ended December 31, 2017 and the four months ended December 31, 2016, there were no changes to the inputs and valuation techniques used to measure fair value, the types of instruments, or the levels in which they were classified.

15

8. Accounting for Regulatory Activities

Regulatory Assets and Liabilities

Regulatory assets and liabilities represent probable future revenues or expenses associated with certain charges and credits that will be recovered from or refunded to customers through the ratemaking process. As of December 31, 2017, the regulatory assets are being recovered in our rates, without earning a return, over a period of approximately one year to 27 years. Below are the details of our regulatory assets and liabilities as of (in millions):

	December 31,
	2017		2016
Current regulatory assets
Difference between gas retained and gas consumed in operations	$	1	$	3
Other	1		1
Total current regulatory assets(a)	2		4
Non-current regulatory assets
Taxes on capitalized funds used during construction(b)	13		24
Unamortized loss on reacquired debt	9		10
Other	1		2
Total non-current regulatory assets	23		36
Total regulatory assets	$	25	$	40
Current regulatory liabilities
Difference between gas retained and gas consumed in operations	$	12	$	1
Other	3		2
Total current regulatory liabilities	15		3
Non-current regulatory liabilities
Postretirement benefits	19		19
Income taxes(b)	55		—
Other	1		2
Total non-current regulatory liabilities(c)	75		21
Total regulatory liabilities	$	90	$	24

_______________

(a)    Included in “Other current assets” on our accompanying Consolidated Balance Sheets.

(b)    See “2017 Tax Reform” below.

(c)    Included in “Other long-term liabilities and deferred credits” on our accompanying Consolidated Balance Sheets.

Our significant regulatory assets and liabilities include:

Difference between gas retained and gas consumed in operations

Amounts reflect the value of the difference between the gas retained and consumed in our operations. Pursuant to our tariff, these amounts are expected to be recovered from our customers in subsequent periods.

Taxes on capitalized funds used during construction

Amounts represent the recovery of deferred income taxes on AFUDC Equity recognized during the time prior to 2007 when we were a taxable entity. These amounts are included in our tariff rates and are recovered over the depreciable lives of the asset in which they apply.

16

Unamortized loss on reacquired debt

Amounts represent the deferred and unamortized portion of loss on reacquired debt which are recovered in our rates. Amounts are amortized over the original life of the debt issue, or in the case of refinanced debt, over the life of the new debt issue.

Postretirement Benefits

Amounts represent unrecognized gains and losses related to our postretirement benefit plan.

2017 Tax Reform

On December 22, 2017, the U.S. enacted the 2017 Tax Reform. Among the many provisions included in the 2017 Tax Reform is a provision to reduce the U.S. federal corporate income tax rate from 35% to 21% effective January 1, 2018. As income taxes are a component in our maximum recourse rates, the income tax rate change resulted in us recording a provisional $66 million non-cash charge to our earnings related to an adjustment to our deferred income tax related regulatory assets and  liabilities. The charge was recorded as a reduction to Revenues of $55 million and an increase to Other, net of $11 million for the year ended December 31, 2017.

As the impact on the regulatory ratemaking process is currently uncertain, and we have not completed our assessment of the 2017 Tax Reform's effect, these amounts are subject to further adjustments. We continue to assess the impact of the 2017 Tax Reform on our business in order to complete our analysis. Any adjustments to our provisional amount will be reported in the reporting period in which any such adjustments are determined and may be material in the period in which the adjustments are made.

Regulatory Assets Amortization

Our amortizations of the regulatory assets for the year ended December 31, 2017 and the four months ended December 31, 2016 were $1 million, related to deferred losses on reacquired debt included in “Interest, net” on our accompanying Consolidated Statements of Income.

Regulatory Matters

Rate Case

On July 12, 2013, the FERC approved a comprehensive rate case settlement for SNG's general system-wide tariff rates. Under the settlement, we are required to file a new rate case no later than February 28, 2018 for new storage and transportation tariff rates to go into effect September 1, 2018. In August 2017, we commenced pre-filing settlement negotiations with our customers to try and resolve the rate proceeding prior to filing a rate case with FERC. We have filed on January 29, 2018 a request to FERC to extend the obligation to file the rate case from February 28 to May 1, 2018 in order to continue negotiations of a pre-filing settlement.  If we were to succeed in obtaining a pre-filing settlement, new transportation, storage and park and loan tariff rates would go into effect September 1, 2018.

Other

We applied with the FERC on February 3, 2017 in Docket No. CP17-46-000 to expand our system in Georgia (Fairburn Expansion project) to provide additional firm transportation capacity of approximately 347,000 dekatherms per day in the Southeast market. The estimated capital cost of the project is approximately $240 million and its anticipated in-service date is October 1, 2018.

9. Litigation, Environmental and Commitments

We are party to various legal, regulatory and other matters arising from the day-to-day operations of our businesses that may result in claims against the Company. Although no assurance can be given, we believe, based on our experiences to date and taking into account established reserves, that the ultimate resolution of such items will not have a material adverse impact on our business, financial position, results of operations or cash flows. We believe we have meritorious defenses to the matters to which we are a party and intend to vigorously defend the Company. When we determine a loss is probable of occurring and is reasonably estimable, we accrue an undiscounted liability for such contingencies based on our best estimate using information available at that time. If the estimated loss is a range of potential outcomes and there is no better estimate within the range, we accrue the amount at the low end

17

of the range. We disclose contingencies where an adverse outcome may be material, or in the judgment of management, we conclude the matter should otherwise be disclosed.

Legal Proceedings

Cliffs Natural Resources (Cliffs)

We filed a lawsuit against Cliffs in the Circuit Court of Jefferson County, Alabama (Case No. 68-CV-2014-900533) to determine whether Cliffs’ longwall coal mining operations require the relocation of a large segment of our pipelines in Jefferson County, Alabama and who will be responsible for the cost of any such relocation. Prior to the initiation of the lawsuit, Cliffs notified us of its intent to conduct underground longwall coal mining operations in the vicinity of four of our pipelines in Jefferson County. Upon being informed by Cliffs that its planned coal mining operations would cause surface subsidence of three to six feet, we determined that such level of subsidence presented a safety hazard to our pipelines and that relocating the affected pipelines may be the safest and most economical option to mitigate the safety hazard. We alleged in the lawsuit that easements governing our property rights to operate our pipelines do not allow Cliffs’ mining operations to proceed as planned. We also alleged, among other things, that if Cliffs is allowed to proceed with its mining plan, Cliffs should be responsible for the pipeline relocation costs and any other damages. We have completed the relocation of the pipelines, at a cost of approximately $34 million, to avoid the mining threat. On March 3, 2017, the parties reached a confidential settlement agreement to resolve all disputes related to the relocation and the lawsuit was dismissed in May 2017.

General

As of December 31, 2017, we had no accruals for our outstanding legal proceedings. As of December 31, 2016, we had less than $1 million accrued for our outstanding legal proceedings.

Environmental Matters

We are subject to environmental cleanup and enforcement actions from time to time. In particular, the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) generally imposes joint and several liability for cleanup and enforcement costs on current and predecessor owners and operators of a site, among others, without regard to fault or the legality of the original conduct, subject to the right of a liable party to establish a “reasonable basis” for apportionment of costs. Our operations are also subject to federal, state and local laws and regulations relating to protection of the environment. Although we believe our operations are in substantial compliance with applicable environmental laws and regulations, risks of additional costs and liabilities are inherent in our operations, and there can be no assurance that we will not incur significant costs and liabilities. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies under the terms of authority of those laws, and claims for damages to property or persons resulting from our operations, could result in substantial costs and liabilities to us.

Southeast Louisiana Flood Protection Litigation

On July 24, 2013, the Board of Commissioners of the Southeast Louisiana Flood Protection Authority - East (SLFPA) filed a petition for damages and injunctive relief in a state district court for Orleans Parish, Louisiana against us and approximately 100 other energy companies, alleging that defendants’ drilling, dredging, pipeline and industrial operations since the 1930’s have caused direct land loss and increased erosion and submergence resulting in alleged increased storm surge risk, increased flood protection costs and unspecified damages to the plaintiff. The SLFPA asserts claims for negligence, strict liability, public nuisance, private nuisance, and breach of contract. Among other relief, the petition seeks unspecified monetary damages, attorney fees, interest, and injunctive relief in the form of abatement and restoration of the alleged coastal land loss including but not limited to backfilling and re-vegetation of canals, wetlands and reef creation, land bridge construction, hydrologic restoration, shoreline protection, structural protection, and bank stabilization. On August 13, 2013, the suit was removed to the U.S. District Court for the Eastern District of Louisiana. On February 13, 2015, the Court granted defendants’ motion to dismiss the suit for failure to state a claim, and issued an order dismissing the SLFPA’s claims with prejudice. On March 3, 2017, the Fifth Circuit Court of Appeals affirmed the U.S. District Court’s decision, and the SLFPA’s petition for writ of certiorari to the U.S. Supreme Court was denied on October 30, 2017, thereby resolving this matter in its entirety.

Vintage Assets, Inc. Coastal Erosion Litigation

On December 18, 2015, Vintage Assets, Inc. and several individual landowners filed a petition in the State District Court for Plaquemines Parish, Louisiana alleging that its 5,000 acre property is composed of coastal wetlands, and that we failed to maintain

18

pipeline canals and banks, causing widening of the canals, land loss, and damage to the ecology and hydrology of the marsh, in breach of right of way agreements, prudent operating practices, and Louisiana law. The suit also claims that defendants’ alleged failure to maintain pipeline canals and banks constitutes negligence and has resulted in encroachment of the canals, constituting trespass. The suit seeks in excess of $80 million in money damages, including recovery of litigation costs, damages for trespass, and money damages associated with an alleged loss of natural resources and projected reconstruction cost of replacing or restoring wetlands. The suit was removed to the U.S. District Court for the Eastern District of Louisiana. Our assets at issue were sold to Highpoint Gas Transmission, LLC in 2011, which was subsequently purchased by American Midstream Partners, LP. In response to our demand for defense and indemnity, American Midstream Partners agreed to pay 50% of joint defense costs and expenses, with a percentage of indemnity to be determined upon final resolution of the suit. On October 20, 2016, plaintiffs filed an amended complaint naming Highpoint Gas Transmission, LLC as an additional defendant. A non-jury trial was held during September 2017. We anticipate a ruling in the first quarter 2018. We will continue to vigorously defend the suit, and intend to appeal any adverse ruling that may result from the trial.

Superfund Matters

In our recorded environmental liabilities there were projects where we had received notice that we had been designated or could be designated as a Potentially Responsible Party (PRP) under CERCLA, commonly known as Superfund, or state equivalents for one site. On September 29, 2017, we entered into a Consent Decree after meeting the Environmental Protection Agency's requirements for a final settlement for the remaining liability at the Port Refinery Superfund site, including payment of a settlement amount which is the final judgment against us for the site.

General

Although it is not possible to predict the ultimate outcomes, we believe that the resolution of the environmental matters set forth in this note, and other matters to which we and our subsidiary are a party, will not have a material adverse effect on our business, financial position, results of operations or cash flows. As of December 31, 2017 and 2016, we had less than $1 million accrued for our environmental matters.

Commitments

Capital Commitments

As of December 31, 2017, we have capital commitments of $15 million, which we expect to spend during 2018. We have other planned capital and investment projects that are discretionary in nature, with no substantial contractual capital commitments made in advance of the actual expenditures.

Transportation Commitments

We have transportation commitments totaling $359 million as of December 31, 2017, which are primarily related to a transportation contract with our affiliate, Elba Express Company, L.L.C., which we expect to spend $32 million each year for the period from 2018 to 2022 and $199 million in total thereafter.

Storage Commitments

We have storage capacity commitments totaling $8 million as of December 31, 2017, most of which are related to storage capacity contracts with our equity investee, Bear Creek, which we expect to spend during 2018. We expect annual renewal of this contract to occur into the foreseeable future.

19

Operating Leases

We lease property, facilities and equipment under various operating leases. Our future minimum annual rental commitments under our operating leases as of December 31, 2017, are as follows (in millions):

Year	Total
2018	$	2
2019	2
2020	2
2021	2
2022	2
Thereafter	11
Total	$	21

Rent expense on our lease obligations for the year ended December 31, 2017 and the four months ended December 31, 2016 was approximately $2 million and $1 million, respectively, and is reflected in “Operations and maintenance” and “General and administrative” on our accompanying Consolidated Statements of Income. For certain operating leases related to shared facilities, we may be the primary obligor, but the rent expense is allocated to various KMI subsidiaries and is administered and funded by KMI.

10. Recent Accounting Pronouncements

Accounting Standards Updates

Topic 606

On May 28, 2014, the FASB issued ASU No. 2014-09, “Revenue from Contracts with Customers” followed by a series of related accounting standard updates (collectively referred to as “Topic 606”). Topic 606 is designed to create greater revenue recognition and disclosure comparability in financial statements. The provisions of Topic 606 include a five-step process by which an entity will determine revenue recognition, depicting the transfer of goods or services to customers in amounts reflecting the payment to which an entity expects to be entitled in exchange for those goods or services. Topic 606 requires certain disclosures about contracts with customers and provides more comprehensive guidance for transactions such as service revenue, contract modifications, and multiple-element arrangements.

Topic 606 will require that our revenue recognition policy disclosure include further detail regarding our performance obligations as to the nature, amount, timing, and estimates of revenue and cash flows generated from our contracts with customers. Topic 606 will also require disclosure of significant changes in contract asset and contract liability balances period to period and the amount of the transaction price allocated to performance obligations that are unsatisfied (or partially unsatisfied) as of the end of the reporting period, as applicable. We utilized the modified retrospective method to adopt the provisions of this standard effective January 1, 2018, which required us to apply the new revenue standard to (i) all new revenue contracts entered into after January 1, 2018 and (ii) all existing revenue contracts as of January 1, 2018 through a cumulative adjustment to equity. In accordance with this approach, our consolidated revenues for periods prior to January 1, 2018 will not be revised. The cumulative effect of the adoption of this standard as of January 1, 2018 was not material.

ASU No. 2016-02

On February 25, 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842).” This ASU requires that lessees recognize assets and liabilities on the balance sheet for the present value of the rights and obligations created by all leases with terms of more than 12 months. The ASU also will require disclosures designed to give financial statement users information on the amount, timing, and uncertainty of cash flows arising from leases. ASU No. 2016-02 will be effective for us as of January 1, 2019. We are currently reviewing the effect of ASU No. 2016-02.

20

ASU No. 2017-07

On March 10, 2017, the FASB issued ASU No. 2017-07, “Compensation - Retirement Benefits (Topic 715).” This ASU requires an employer to disaggregate the service cost component from the other components of net benefit cost, allows only the service cost component of net benefit cost to be eligible for capitalization, and addresses how to present the service cost component and the other components of net benefit cost in the income statement. We adopted ASU No. 2017-07 effective January 1, 2018 with no material impact to our financial statements.

ASU No. 2018-01

On January 25, 2018, the FASB issued ASU No. 2018-01, “Land Easement Practical Expedient for Transition to Topic 842.” This ASU provides an optional transition practical expedient that, if elected, would not require companies to reconsider its accounting for existing or expired land easements before the adoption of Topic 842 and that were not previously accounted for as leases under Topic 840. ASU No. 2018-01 will be effective for us as of January 1, 2019, and earlier adoption is permitted. We are currently reviewing the effect of this ASU to our financial statements.

21