Note 14. Derivative Instruments, Hedging Activities and Fair Value Measurements

In the normal course of our business operations, we are exposed to certain risks, including changes in interest rates and commodity prices. In order to manage risks associated with assets, liabilities and certain anticipated future transactions, we use derivative instruments such as futures, forward contracts, swaps, options and other instruments with similar characteristics. Substantially all of our derivatives are used for non-trading activities.

On January 1, 2018, we early adopted ASU 2017-12, Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities. Since the impact of the new guidance was not material to our consolidated financial statements, no transition adjustments were recorded. In accordance with ASU 2017-12 both the effective and ineffective portion of a cash flow hedge are initially reported as a component of accumulated other comprehensive income (loss) and reclassified into earnings when the forecasted transaction affects earnings.

Interest Rate Hedging Activities

We may utilize interest rate swaps, forward starting swaps and similar derivative instruments to manage our exposure to changes in interest rates charged on borrowings under certain consolidated debt agreements. This strategy may be used in controlling our overall cost of capital associated with such borrowings.

As a result of market conditions, we terminated an aggregate $275 million notional amount of forward starting swaps in 2018, which resulted in cash proceeds totaling $22.1 million. As cash flow hedges, gains on these derivative instruments are reflected as a component of accumulated other comprehensive income and will be amortized to earnings (as a decrease in interest expense) over a 30-year period beginning in February 2019. Likewise, in 2017, we terminated an aggregate $275 million notional amount of forward starting swaps (cash flow hedges), which resulted in cash proceeds totaling $30.6 million that are being amortized to earnings (as a decrease in interest expense) over the 30-year life of the associated debt through February 2048. In 2016, we terminated an aggregate $250 million notional amount of forward starting swaps (cash flow hedges), which resulted in cash proceeds totaling $6.1 million that are being amortized to earnings (as a decrease in interest expense) over the 30-year life of the associated debt through September 2047.

In 2018, we sold swaptions related to our interest rate hedging activities that resulted in the recognition of an aggregate $29.4 million of cash gains (swaption premium income) that were reflected as a reduction in interest expense for the year.

Commodity Hedging Activities

The prices of natural gas, NGLs, crude oil, petrochemicals and refined products are subject to fluctuations in response to changes in supply and demand, market conditions and a variety of additional factors that are beyond our control. In order to manage such price risks, we enter into commodity derivative instruments such as physical forward contracts, futures contracts, fixed-for-float swaps and basis swaps.

At December 31, 2018, our predominant commodity hedging strategies consisted of (i) hedging anticipated future purchases and sales of commodity products associated with transportation, storage and blending activities, (ii) hedging natural gas processing margins and (iii) hedging the fair value of commodity products held in inventory.

§	The objective of our anticipated future commodity purchases and sales hedging program is to hedge the margins of certain transportation, storage, blending and operational activities by locking in purchase and sale prices through the use of derivative instruments and related contracts.

The objective of our natural gas processing hedging program is to hedge an amount of earnings associated with these activities. We achieve this objective by executing fixed-price sales for a portion of our expected equity NGL production using derivative instruments and related contracts. For certain natural gas processing contracts, the hedging of expected equity NGL production also involves the purchase of natural gas for shrinkage, which is hedged using derivative instruments and related contracts.

§	The objective of our inventory hedging program is to hedge the fair value of commodity products currently held in inventory by locking in the sales price of the inventory through the use of derivative instruments and related contracts.

The following table summarizes our portfolio of commodity derivative instruments outstanding at December 31, 2018 (volume measures as noted):

	Volume (1)				Accounting
Derivative Purpose	Current (2)		Long-Term (2)		Treatment
Derivatives designated as hedging instruments:
Natural gas processing:
Forecasted natural gas purchases for plant thermal reduction (Bcf)		4.9		n/a	Cash flow hedge
Forecasted sales of NGLs (MMBbls)		1.0		n/a	Cash flow hedge
Octane enhancement:
Forecasted purchase of NGLs (MMBbls)		1.8		n/a	Cash flow hedge
Forecasted sales of octane enhancement products (MMBbls)		3.1		0.1	Cash flow hedge
Natural gas marketing:
Natural gas storage inventory management activities (Bcf)		3.3		n/a	Fair value hedge
NGL marketing:
Forecasted purchases of NGLs and related hydrocarbon products (MMBbls)		33.6		4.3	Cash flow hedge
Forecasted sales of NGLs and related hydrocarbon products (MMBbls)		45.0		1.7	Cash flow hedge
NGLs inventory management activities (MMBbls)		0.3		n/a	Fair value hedge
Refined products marketing:
Forecasted purchases of refined products (MMBbls)		1.0		n/a	Cash flow hedge
Forecasted sales of refined products (MMBbls)		2.0		n/a	Cash flow hedge
Refined products inventory management activities (MMBbls)		0.5		n/a	Fair value hedge
Crude oil marketing:
Forecasted purchases of crude oil (MMBbls)		18.4		1.9	Cash flow hedge
Forecasted sales of crude oil (MMBbls)		28.5		1.9	Cash flow hedge
Derivatives not designated as hedging instruments:
Natural gas risk management activities (Bcf) (3,4)		77.5		0.9	Mark-to-market
NGL risk management activities (MMBbls) (4)		3.3		n/a	Mark-to-market
Refined products risk management activities (MMBbls) (4)		2.6		n/a	Mark-to-market
Crude oil risk management activities (MMBbls) (4)		26.3		3.2	Mark-to-market

(1) Volume for derivatives designated as hedging instruments reflects the total amount of volumes hedged whereas volume for derivatives not designated as hedging instruments reflects the absolute value of derivative notional volumes. (2) The maximum term for derivatives designated as cash flow hedges, derivatives designated as fair value hedges and derivatives not designated as hedging instruments is December 2020, June 2019 and December 2020, respectively. (3) Current volume includes 29.8 Bcf of physical derivative instruments that are predominantly priced at a marked-based index plus a premium or minus a discount related to location differences. (4) Reflects the use of derivative instruments to manage risks associated with transportation, processing and storage assets.

The carrying amount of our inventories subject to fair value hedges was $50.2 million and $84.0 million at December 31, 2018 and 2017, respectively.

Certain basis swaps, basis spread options and other derivative instruments not designated as hedging instruments are used to manage market risks associated with anticipated purchases and sales of commodity products. There is some uncertainty involved in the timing of these transactions often due to the development of more favorable profit opportunities or when spreads are insufficient to cover variable costs thus reducing the likelihood that the transactions will occur during the periods originally forecasted. In accordance with derivatives accounting guidance, these instruments do not qualify for hedge accounting even though they are effective at managing the risk exposures of the underlying assets. Due to volatility in commodity prices, any non-cash, mark-to-market earnings variability cannot be predicted.

Tabular Presentation of Fair Value Amounts, and Gains and Losses on

Derivative Instruments and Related Hedged Items

The following table provides a balance sheet overview of our derivative assets and liabilities at the dates indicated:

	Asset Derivatives						Liability Derivatives
	December 31, 2018			December 31, 2017			December 31, 2018			December 31, 2017
	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Derivatives designated as hedging instruments
Interest rate derivatives	Current assets	$	--	Current assets	$	--	Current liabilities	$	--	Current liabilities	$	1.5
Interest rate derivatives	Other assets		--	Other assets		0.1	Other liabilities		--	Other liabilities		0.2
Total interest rate derivatives			--			0.1			--			1.7
Commodity derivatives	Current assets		138.5	Current assets		109.5	Current liabilities		115.0	Current liabilities		104.4
Commodity derivatives	Other assets		5.6	Other assets		6.4	Other liabilities		11.1	Other liabilities		6.8
Total commodity derivatives			144.1			115.9			126.1			111.2
Total derivatives designated as hedging instruments		$	144.1		$	116.0		$	126.1		$	112.9

Derivatives not designated as hedging instruments
Commodity derivatives	Current assets	$	15.9	Current assets	$	43.9	Current liabilities	$	33.2	Current liabilities	$	62.3
Commodity derivatives	Other assets		1.9	Other assets		1.9	Other liabilities		3.1	Other liabilities		3.4
Total commodity derivatives			17.8			45.8			36.3			65.7
Total derivatives not designated as hedging instruments		$	17.8		$	45.8		$	36.3		$	65.7

Certain of our commodity derivative instruments are subject to master netting arrangements or similar agreements. The following tables present our derivative instruments subject to such arrangements at the dates indicated:

	Offsetting of Financial Assets and Derivative Assets
										Gross Amounts Not Offset in the Balance Sheet
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Financial Instruments				Cash Collateral Paid		Cash Collateral Received		Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of December 31, 2018:
Commodity derivatives		$	161.9		$	--		$	161.9		$	(158.6	)	$	--	$	--		$	3.3
As of December 31, 2017:
Interest rate derivatives		$	0.1		$	--		$	0.1		$	(0.1	)	$	--	$	--		$	--
Commodity derivatives			161.7			--			161.7			(157.8	)		--		--			3.9

	Offsetting of Financial Liabilities and Derivative Liabilities
										Gross Amounts Not Offset in the Balance Sheet
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Financial Instruments				Cash Collateral Paid				Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of December 31, 2018:
Commodity derivatives		$	162.4		$	--		$	162.4		$	(158.6	)		$	(2.3	)		$	1.5
As of December 31, 2017:
Interest rate derivatives		$	1.7		$	--		$	1.7		$	(0.1	)		$	--			$	1.6
Commodity derivatives			176.9			--			176.9			(157.8	)			(17.3	)			1.8

Derivative assets and liabilities recorded on our Consolidated Balance Sheets are presented on a gross-basis and determined at the individual transaction level. This presentation method is applied regardless of whether the respective exchange clearing agreements, counterparty contracts or master netting agreements contain netting language often referred to as “rights of offset.” Although derivative amounts are presented on a gross-basis, having rights of offset enable the settlement of a net as opposed to gross receivable or payable amount under a counterparty default or liquidation scenario.

Cash is paid and received as collateral under certain agreements, particularly for those associated with exchange transactions. For any cash collateral payments or receipts, corresponding assets or liabilities are recorded to reflect the variation margin deposits or receipts with exchange clearing brokers and customers. These balances are also presented on a gross-basis on our Consolidated Balance Sheets.

The tabular presentation above provides a means for comparing the gross amount of derivative assets and liabilities, excluding associated accounts payable and receivable, to the net amount that would likely be receivable or payable under a default scenario based on the existence of rights of offset in the respective derivative agreements. Any cash collateral paid or received is reflected in these tables, but only to the extent that it represents variation margins. Any amounts associated with derivative prepayments or initial margins that are not influenced by the derivative asset or liability amounts or those that are determined solely on their volumetric notional amounts are excluded from these tables.

The following tables present the effect of our derivative instruments designated as fair value hedges on our Statements of Consolidated Operations for the years indicated:

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative
		For the Year Ended December 31,
		2018		2017			2016
Interest rate derivatives	Interest expense	$	1.3	$	(0.2	)	$	0.3
Commodity derivatives	Revenue		9.9		1.1			(90.5	)
Total		$	11.2	$	0.9		$	(90.2	)

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Hedged Item
		For the Year Ended December 31,
		2018			2017		2016
Interest rate derivatives	Interest expense	$	(1.4	)	$	0.4	$	(0.4	)
Commodity derivatives	Revenue		(6.9	)		27.4		125.0
Total		$	(8.3	)	$	27.8	$	124.6

The following tables present the effect of our derivative instruments designated as cash flow hedges on our Statements of Consolidated Operations and Statements of Consolidated Comprehensive Income for the years indicated:

Derivatives in Cash Flow Hedging Relationships	Change in Value Recognized in Other Comprehensive Income (Loss) On Derivative
	For the Year Ended December 31,
	2018		2017			2016
Interest rate derivatives	$	22.2	$	(5.7	)	$	42.3
Commodity derivatives – Revenue (1)		293.0		(33.7	)		(197.4	)
Commodity derivatives – Operating costs and expenses (1)		0.2		(4.8	)		3.6
Total	$	315.4	$	(44.2	)	$	(151.5	)

(1)The fair value of these derivative instruments will be reclassified to their respective locations on the Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate.

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income
		For the Year Ended December 31,
		2018			2017			2016
Interest rate derivatives	Interest expense	$	(38.1	)	$	(40.4	)	$	(37.4	)
Commodity derivatives	Revenue		131.7			(111.6	)		(53.6	)
Commodity derivatives	Operating costs and expenses		(1.3	)		(0.6	)		0.2
Total		$	92.3		$	(152.6	)	$	(90.8	)

Over the next twelve months, we expect to reclassify $38.0 million of losses attributable to interest rate derivative instruments from accumulated other comprehensive loss to earnings as an increase in interest expense. Likewise, we expect to reclassify $168.1 million of gains attributable to commodity derivative instruments from accumulated other comprehensive income to earnings, $166.9 million as an increase in revenue and $1.2 million as a decrease to operating costs and expenses.

The following table presents the effect of our derivative instruments not designated as hedging instruments on our Statements of Consolidated Operations for the years indicated:

Derivatives Not Designated as Hedging Instruments	Location	Gain (Loss) Recognized in Income on Derivative
		For the Year Ended December 31,
		2018			2017			2016
Commodity derivatives	Revenue	$	(462.9	)	$	(42.7	)	$	(38.4	)
Commodity derivatives	Operating costs and expenses		8.2			0.1			(0.4	)
Total		$	(454.7	)	$	(42.6	)	$	(38.8	)

The $454.7 million loss recognized in 2018 from derivatives not designated as hedging instruments (as noted in the preceding table) reflects $443.8 million of realized losses and $10.9 million of net unrealized mark-to-market losses.

In the aggregate, our net unrealized mark-to-market loss for the year ended December 31, 2018 attributable to derivatives designated as fair value hedges and derivatives not designated as hedging instruments was $19.1 million. The following table summarizes the impact of this net unrealized loss on our gross operating margin by segment for the year ended December 31, 2018:

Unrealized mark-to-market gains (losses) by segment:
NGL Pipelines & Services	$	18.0
Crude Oil Pipelines & Services		(44.1	)
Natural Gas Pipelines & Services		5.3
Petrochemical & Refined Products Services		1.7
Total	$	(19.1	)

Fair Value Measurements

The following tables set forth, by level within the Level 1, 2 and 3 fair value hierarchy (see Note 2), the carrying values of our financial assets and liabilities at the dates indicated. These assets and liabilities are measured on a recurring basis and are classified based on the lowest level of input used to estimate their fair value. Our assessment of the relative significance of such inputs requires judgment.

The values for commodity derivatives are presented before and after the application of Chicago Mercantile Exchange (“CME”) Rule 814, which deems that financial instruments cleared by the CME are settled daily in connection with variation margin payments. As a result of this exchange rule, CME-related derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes; however, the derivatives remain outstanding and subject to future commodity price fluctuations until they are settled in accordance with their contractual terms. Derivative transactions cleared on exchanges other than the CME (e.g., the Intercontinental Exchange or ICE) continue to be reported on a gross basis.

	At December 31, 2018 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total
Financial assets:
Commodity derivatives:
Value before application of CME Rule 814	$	172.3		$	282.4		$	2.2		$	456.9
Impact of CME Rule 814 change		(134.8	)		(159.3	)		(0.9	)		(295.0	)
Total commodity derivatives		37.5			123.1			1.3			161.9
Total	$	37.5		$	123.1		$	1.3		$	161.9

Financial liabilities:
Liquidity Option Agreement (see Note 17)	$	--		$	--		$	390.0		$	390.0
Commodity derivatives:
Value before application of CME Rule 814		85.5			291.2			21.4			398.1
Impact of CME Rule 814 change		(48.6	)		(172.9	)		(14.2	)		(235.7	)
Total commodity derivatives		36.9			118.3			7.2			162.4
Total	$	36.9		$	118.3		$	397.2		$	552.4

In the aggregate, the fair value of our commodity hedging portfolios at December 31, 2018 was a net derivative asset of $58.8 million prior to the impact of CME Rule 814.

	At December 31, 2017 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)		Total
Financial assets:
Interest rate derivatives	$	--		$	0.1		$	--	$	0.1
Commodity derivatives:
Value before application of CME Rule 814		47.1			184.9			2.9		234.9
Impact of CME Rule 814 change		(47.1	)		(26.1	)		--		(73.2	)
Total commodity derivatives		--			158.8			2.9		161.7
Total	$	--		$	158.9		$	2.9	$	161.8

Financial liabilities:
Liquidity Option Agreement (see Note 17)	$	--		$	--		$	333.9	$	333.9
Interest rate derivatives		--			1.7			--		1.7
Commodity derivatives:
Value before application of CME Rule 814		118.4			270.6			1.7		390.7
Impact of CME Rule 814 change		(118.4	)		(95.4	)		--		(213.8	)
Total commodity derivatives		--			175.2			1.7		176.9
Total	$	--		$	176.9		$	335.6	$	512.5

The following tables provide quantitative information regarding our recurring Level 3 fair value measurements for commodity derivatives at the dates indicated:

	Fair Value At December 31, 2018
	Financial Assets		Financial Liabilities		Valuation Techniques	Unobservable Input	Range
Commodity derivatives – Crude oil	$	0.9	$	0.8	Discounted cash flow	Forward commodity prices	$37.59-$51.99/barrel
Commodity derivatives – Ethane		0.4		0.6	Discounted cash flow	Forward commodity prices	$0.28-$0.31/gallon
Commodity derivatives – Propane		--		1.0	Discounted cash flow	Forward commodity prices	$0.61-$0.66/gallon
Commodity derivatives – Normal butane		--		0.7	Discounted cash flow	Forward commodity prices	$0.66-$0.72/gallon
Commodity derivatives – Natural gasoline		--		4.1	Discounted cash flow	Forward commodity prices	$0.99-$1.01/gallon
Total	$	1.3	$	7.2

	Fair Value At December 31, 2017
	Financial Assets		Financial Liabilities		Valuation Techniques	Unobservable Input	Range
Commodity derivatives – Crude oil	$	2.9	$	1.7	Discounted cash flow	Forward commodity prices	$60.21-$66.05/barrel
Total	$	2.9	$	1.7

With respect to commodity derivatives, we believe forward commodity prices are the most significant unobservable inputs in determining our Level 3 recurring fair value measurements at December 31, 2018. In general, changes in the price of the underlying commodity increases or decreases the fair value of a commodity derivative depending on whether the derivative was purchased or sold. We generally expect changes in the fair value of our derivative instruments to be offset by corresponding changes in the fair value of our hedged exposures.

The recurring fair value measurement pertaining to the Liquidity Option Agreement is based on a number of Level 3 inputs. See Note 17 for a discussion of this liability.

The following table sets forth a reconciliation of changes in the fair values of our recurring Level 3 financial assets and liabilities on a combined basis for the years indicated:

		For the Year Ended December 31,
	Location	2018			2017
Financial asset (liability) balance, net, January 1		$	(332.7	)	$	(268.2	)
Total gains (losses) included in:
Net income (1)	Revenue		0.7			2.3
Net income	Other expense, net – Liquidity Option Agreement		(56.1	)		(64.3	)
Other comprehensive income (loss)	Commodity derivative instruments – changes in fair value of cash flow hedges		(3.2	)		0.1
Settlements (1)	Revenue		(1.9	)		(2.4	)
Transfers out of Level 3 (2)			(2.7	)		(0.2	)
Financial liability balance, net, December 31 (2)		$	(395.9	)	$	(332.7	)

(1)There were $1.2 million and $0.1 million of unrealized losses included in these amounts for the years ended December 31, 2018 and 2017, respectively. (2)Transfers out of Level 3 into Level 2 were due to shorter remaining transaction maturities falling inside of the Level 2 range at December 31, 2018 and 2017.

Nonrecurring Fair Value Measurements

Long-lived assets (including intangible assets with finite useful lives and property, plant and equipment) are reviewed for impairment (i.e., subject to nonrecurring fair value measurements) when events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Long-lived assets with carrying values that are not expected to be recovered through future cash flows are written-down to their estimated fair values. Similarly, we evaluate our equity method investments for impairment to determine whether there are events or changes in circumstances that indicate there is a loss in value of the investment attributable to an other than temporary decline. In the event we determine that the loss in value of an investment is an other than temporary decline, we record a non-cash impairment charge to equity earnings to adjust the carrying value of the investment to its estimated fair value.

The following table summarizes our non-cash asset impairment charges by segment during the years indicated:

	For the Year Ended December 31,
	2018		2017		2016
NGL Pipelines & Services	$	18.6	$	11.5	$	21.0
Crude Oil Pipelines & Services		11.2		10.2		2.3
Natural Gas Pipelines & Services		13.9		14.3		12.3
Petrochemical & Refined Products Services		3.1		1.8		9.6
Total	$	46.8	$	37.8	$	45.2

As presented in the following tables, our estimated fair values were based on management’s expectation of the market values for such assets based on their knowledge and experience in the industry (a Level 3 type measure involving significant unobservable inputs). In many cases, there are no active markets (Level 1) or other similar recent transactions (Level 2) to compare to. Our assumptions used in such analyses are based on the highest and best use of the asset and includes estimated probabilities where multiple cash flow outcomes are possible.

When probability weights are used, the weights are generally obtained from business management personnel having oversight responsibilities for the assets being tested. Key commercial assumptions (e.g., anticipated operating margins, throughput or processing volume growth rates, timing of cash flows, etc.) that represent Level 3 unobservable inputs and test results are reviewed and certified by members of senior management.

There were no impairment charges related to our equity method investments during the years ended December 31, 2018, 2017 or 2016.

The following table presents categories of long-lived assets, primarily property, plant and equipment, that were subject to non-recurring fair value measurements during the year ended December 31, 2018:

				Fair Value Measurements at the End of the Reporting Period Using
	Carrying Value at December 31, 2018			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total Non-Cash Impairment Loss
Long-lived assets disposed of other than by sale		$	--		$	--		$	--		$	--		$	43.7
Long-lived assets held and used			--			--			--			--			3.1
Total														$	46.8

Total non-cash asset impairment and related charges during 2018 were $50.5 million, which consisted of $46.8 million of impairment charges attributable to long-lived assets and $3.7 million of impairment charges attributable to the write-down of surplus materials classified as current assets. Impairment charges attributable to long-lived assets were primarily due to the planned abandonment of certain terminal and natural gas processing plants in Texas.

			Fair Value Measurements at the End of the Reporting Period Using
	Carrying Value at December 31, 2017		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total Non-Cash Impairment Loss
Long-lived assets disposed of other than by sale	$	--	$	--	$	--	$	--	$	16.7
Long-lived assets held and used		1.5		--		--		1.5		15.4
Long-lived assets held for sale		2.5		--		--		2.5		2.5
Long-lived assets disposed of by sale		--		--		--		--		3.2
Total									$	37.8

Total non-cash asset impairment and related charges during 2017 were $49.8 million, which consisted of $37.8 million of impairment charges attributable to long-lived assets and $12.0 million of impairment charges attributable to the write-down of surplus materials classified as current assets. Impairment charges attributable to long-lived assets were primarily due to the write-down of certain natural gas pipeline laterals and other pipelines in Texas, which accounted for $13.0 million in charges, and for the planned abandonment of certain storage and pipeline assets in Texas, which accounted for an additional $12.4 million in charges.

The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the year ended December 31, 2016:

			Fair Value Measurements at the End of the Reporting Period Using
	Carrying Value at December 31, 2016		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total Non-Cash Impairment Loss
Long-lived assets disposed of other than by sale	$	--	$	--	$	--	$	--	$	29.9
Long-lived assets held and used		8.0		8.0		--		--		2.2
Long-lived assets disposed of by sale		--		--		--		--		13.1
Total									$	45.2

Total non -cash asset impairment and related charges during 2016 were $53.5 million, which consisted of $45.2 million of impairment charges attributable to long-lived assets, $1.2 million of impairment charges attributable to the write-down of surplus materials classified as current assets, and $7.1 million of related charges for equipment destroyed by fire at our Pascagoula gas plant. Impairment charges attributable to long-lived assets primarily relate to the planned abandonment of certain plant and pipeline assets in Texas and New Mexico.

Other Fair Value Information

The carrying amounts of cash and cash equivalents (including restricted cash balances), accounts receivable, commercial paper notes and accounts payable approximate their fair values based on their short-term nature.

The estimated total fair value of our fixed-rate debt obligations was $25.97 billion and $23.47 billion at December 31, 2018 and 2017, respectively. The aggregate carrying value of these debt obligations was $26.15 billion and $21.48 billion at December 31, 2018 and 2017, respectively. These values are primarily based on quoted market prices for such debt or debt of similar terms and maturities (Level 2) and our credit standing. Changes in market rates of interest affect the fair value of our fixed-rate debt. The amounts reported for fixed-rate debt obligations exclude those amounts hedged using fixed-to-floating interest rate swaps. See “Interest Rate Hedging Activities” within this Note 14 for additional information.

The carrying values of our variable-rate long-term debt obligations approximate their fair values since the associated interest rates are market-based. We do not have any long-term investments in debt or equity securities recorded at fair value.