For the years ended December?31, 2018, 2017 and 2016, the amounts recognized in Principal transactions in the Consolidated Statement of Income related to derivatives not designated in a qualifying hedging relationship, as well as the underlying non-derivative instruments, are presented in Note?6 to the Consolidated Financial Statements.
Citigroup presents this disclosure by showing derivative gains and losses related to its trading activities together with gains and losses related to non-derivative instruments within the same trading portfolios, as this represents how these portfolios are risk managed.
The amounts recognized in Other revenue in the Consolidated Statement of Income related to derivatives not designated in a qualifying hedging relationship are shown below.
The table below does not include any offsetting gains (losses) on the economically hedged items to the extent that such amounts are also recorded in Other revenue.
## Table 0 ##
Accounting for Derivative Hedging Citigroup accounts for its hedging activities in accordance with ASC 815, Derivatives and Hedging.
As a general rule, hedge accounting is permitted where the Company is exposed to a particular risk, such as interest rate or foreign exchange risk, that causes changes in the fair value of an asset or liability or variability in the expected future cash flows of an existing asset, liability or a forecasted transaction that may affect earnings.
Derivative contracts hedging the risks associated with changes in fair value are referred to as fair value hedges, while contracts hedging the variability of expected future cash flows are cash flow hedges.
Hedges that utilize derivatives or debt instruments to manage the foreign exchange risk associated with equity investments in non-U.
S. -dollar-functionalcurrency foreign subsidiaries (net investment in a foreign operation) are net investment hedges.
To qualify as an accounting hedge under the hedge accounting rules (versus an economic hedge where hedge accounting is not applied), a hedging relationship must be highly effective in offsetting the risk designated as being hedged.
The hedging relationship must be formally documented at inception, detailing the particular risk management objective and strategy for the hedge.
This includes the item and risk(s) being hedged, the hedging instrument being used and how effectiveness will be assessed.
The effectiveness of these hedging relationships is evaluated at hedge inception and on an ongoing basis both on a retrospective and prospective basis, typically using quantitative measures of correlation, with hedge ineffectiveness measured and recorded in current earnings.
Hedge effectiveness assessment methodologies are performed in a similar manner for similar hedges, and are used consistently throughout the hedging relationships.
The assessment of effectiveness may exclude changes in the value of the hedged item that are unrelated to the risks being hedged and the changes in fair value of the derivative associated with time value.
Prior to January 1, 2018, these excluded items were recognized in current earnings for the hedging derivative, while changes in the value of a hedged item that were not related to the hedged risk were not recorded.
Upon adoption of ASC 2017-12, Citi excludes changes in the cross currency basis associated with cross currency swaps from the assessment of hedge effectiveness and records it in other comprehensive income.
Discontinued Hedge Accounting A hedging instrument must be highly effective in accomplishing the hedge objective of offsetting either changes in the fair value or cash flows of the hedged item for the risk being hedged.
Management may voluntarily de-designate an accounting hedge at any time, but if a hedging relationship is not highly effective, it no longer qualifies for hedge accounting and must be de-designated.
Subsequent changes in the fair value of the derivative are recognized in Other revenue or Principal transactions, similar to trading derivatives, with no offset recorded related to the hedged item.
For fair value hedges, any changes in the fair value of the hedged item remain as part of the basis of the asset or liability and are ultimately realized as an element of the yield on the item.
For cash flow hedges, changes in fair value of the end-user derivative remain in Accumulated other comprehensive income (loss) (AOCI) and are included in the earnings of future periods when the forecasted hedged cash flows impact earnings.
However, if it becomes probable that some or all of the hedged forecasted transactions will not occur, any amounts that remain in AOCI related to these transactions must be immediately reflected in Other revenue.
The foregoing criteria are applied on a decentralized basis, consistent with the level at which market risk is managed, but are subject to various limits and controls.
The underlying asset, liability or forecasted transaction may be an individual item or a portfolio of similar items.
Condensed Consolidating Statements of Cash Flows
## Table 1 ##
The foregoing review of factors should not be construed as exhaustive.
New factors emerge from time to time, and it is not possible for management to predict all such factors, nor assess the impact of any such factor on the registrants’ business or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forwardlooking statements.
A security rating is not a recommendation to buy, sell or hold securities that may be subject to revision or withdrawal at any time by the assigning rating organization.
Each rating should be evaluated independently of any other rating.
The registrants expressly disclaim any current intention to update any forward-looking statements contained herein as a result of new information, future events or otherwise.
EXECUTIVE SUMMARY Earnings available to FirstEnergy Corp.  in 2009 were $1.01 billion, or basic earnings of $3.31 per share of common stock ($3.29 diluted), compared with earnings available to FirstEnergy Corp.  of $1.34 billion, or basic earnings of $4.41 per share of common stock ($4.38 diluted), in 2008 and $1.31 billion, or basic earnings of $4.27 per share ($4.22 diluted), in 2007.
## Table 2 ##
Financial Matters Proposed Merger with Allegheny Energy, Inc.  On February 10, 2010, we entered into a Merger Agreement with Allegheny the consummation of which will result, among other things, in our becoming an electric utility holding company for: ?
generation subsidiaries owning or controlling approximately 24,000 MWs of generating capacity from a diversified mix of regional coal, nuclear, natural gas, oil and renewable power, ?
ten regulated electric distribution subsidiaries providing electric service to more than six million customers in Pennsylvania, Ohio, Maryland, New Jersey, New York, Virginia and West Virginia, and ?
transmission subsidiaries owning over 20,000 miles of high-voltage lines connecting the Midwest and Mid-Atlantic.
Upon the terms and subject to the conditions set forth in the Merger Agreement, Merger Sub will merge with and into Allegheny with Allegheny continuing as the surviving corporation and a wholly-owned subsidiary of FirstEnergy.
Pursuant to the Merger Agreement, upon the closing of the merger, each issued and outstanding share of Allegheny common stock, including grants of restricted common stock, will automatically be converted into the right to receive 0.667 of a share of common stock of FirstEnergy.
Completion of the merger is conditioned upon, among other things, shareholder approval of both companies as well as expiration or termination of any applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976 and approval by the FERC, the Maryland Public Service Commission, PPUC, the Virginia State Corporation Commission and the West Virginia Public Service Commission.
We anticipate that the necessary approvals will be obtained within 12 to 14 months.
The Merger Agreement contains certain termination rights for both us and Allegheny, and further provides for the payment of fees and expenses upon termination under specified circumstances.
Further information concerning the proposed merger will be included in a joint proxy statement/prospectus contained in the registration statement on Form S-4 to be filed by us with the SEC in connection with the merger.
11: ASSET RETIREMENT OBLIGATIONS CMS Energy and Consumers record the fair value of the cost to remove assets at the end of their useful lives, if there is a legal obligation to remove them.
No market risk premiums were included in CMS Energy’s and Consumers’ ARO fair value estimates since reasonable estimates could not be made.
If a five percent market risk premium were assumed, CMS Energy’s and Consumers’ ARO liabilities would be $17 million higher at December 31, 2014 and $16 million higher at December 31, 2013.
In 2013, Consumers updated the ARO for asbestos abatement to reflect a revised estimate of future obligations at its steam electric generating units.
In 2014, Consumers recorded the initial estimate of $3 million for closure of the Cross Winds?
Energy Park.
If a reasonable estimate of fair value cannot be made in the period in which the ARO is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made.
CMS Energy and Consumers have not recorded liabilities for assets that have insignificant cumulative disposal costs, such as substation batteries.
Presented below are the categories of assets that CMS Energy and Consumers have legal obligations to remove at the end of their useful lives and for which they have an ARO liability recorded:
## Table 3 ##
No assets have been restricted for purposes of settling AROs.
Presented in the following tables are the changes in CMS Energy’s and Consumers’ ARO liabilities:
## Table 4 ##
Common Stocks: Common stocks in the OPEB Plan consist of equity securities with low transaction costs that were actively managed and tracked by the S&P 500 Index.
These securities were valued at their quoted closing prices.
Mutual Funds: Mutual funds represent shares in registered investment companies that are priced based on the daily quoted NAVs that are publicly available and are the basis for transactions to buy or sell shares in the funds.
Pooled Funds: Pooled funds include both common and collective trust funds as well as special funds that contain only employee benefit plan assets from two or more unrelated benefit plans.

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Gains (losses) included inOther revenue Year ended December 31,
In millions of dollars	2018	2017	2016
Interest rate contracts	$-25	$-73	$51
Foreign exchange	-197	2,062	-847
Credit derivatives	-155	-538	-1,174
Total	$-377	$1,451	$-1,970

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Year ended December 31, 2016
In millions of dollars	Citigroup parent company	CGMHI	Other Citigroup subsidiaries and eliminations	Consolidating adjustments	Citigroup consolidated
Net cash provided by operating activities of continuing operations	$11,605	$20,610	$21,518	$—	$53,733
Cash flows from investing activities of continuing operations
Purchases of investments	$—	$-14	$-211,388	$—	$-211,402
Proceeds from sales of investments	3,024	—	129,159	—	132,183
Proceeds from maturities of investments	234	—	65,291	—	65,525
Change in loans	—	—	-39,761	—	-39,761
Proceeds from sales and securitizations of loans	—	—	18,140	—	18,140
Change in federal funds sold and resales	—	-15,294	-1,844	—	-17,138
Proceeds from significant disposals	—	—	265	—	265
Payments due to transfers of net liabilities associated with significant disposals	—	—	—	—	—
Changes in investments and advances—intercompany	-18,083	-5,574	23,657	—	—
Other investing activities	—	57	-2,004	—	-1,947
Net cash used in investing activities of continuing operations	$-14,825	$-20,825	$-18,485	$—	$-54,135
Cash flows from financing activities of continuing operations
Dividends paid	$-2,287	$—	$—	$—	$-2,287
Issuance of preferred stock	2,498	—	—	—	2,498
Treasury stock acquired	-9,290	—	—	—	-9,290
Proceeds (repayments) from issuance of long-term debt, net	7,005	5,916	-4,575	—	8,346
Proceeds (repayments) from issuance of long-term debt—intercompany, net	—	-9,453	9,453	—	—
Change in deposits	—	—	24,394	—	24,394
Change in federal funds purchased and repos	—	3,236	-7,911	—	-4,675
Change in short-term borrowings	-164	1,168	8,618	—	9,622
Net change in short-term borrowings and other advances—intercompany	4,620	680	-5,300	—	—
Other financing activities	-316	—	—	—	-316
Net cash provided by financing activities of continuing operations	$2,066	$6,557	$19,669	$—	$28,292
Effect of exchange rate changes on cash and due from banks	$—	$—	$-493	$—	$-493
Change in cash and due from banks and deposits with banks	$-1,154	$6,342	$22,209	$—	$27,397
Cash and due from banks and deposits with banks atbeginning of period	21,966	18,777	92,354	—	133,097
Cash and due from banks and deposits with banks at end of period	$20,812	$25,119	$114,563	$—	$160,494
Cash and due from banks	$142	$4,690	$18,211	$—	$23,043
Deposits with banks	20,670	20,429	96,352	—	137,451
Cash and due from banks and deposits with banks at end of period	$20,812	$25,119	$114,563	$—	$160,494
Supplemental disclosure of cash flow information for continuing operations
Cash paid during the year for income taxes	$351	$92	$3,916	$—	$4,359
Cash paid during the year for interest	4,397	3,115	4,555	—	12,067
Non-cash investing activities
Transfers to loans held-for-sale from loans	$—	$—	$13,900	$—	$13,900
Transfers to OREO and other repossessed assets	—	—	165	—	165

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Change in Basic Earnings Per Share From Prior Year	2009	2008
Basic Earnings Per Share – Prior Year	$4.41	$4.27
Non-core asset sales/impairments	0.47	0.02
Litigation settlement	-0.03	0.03
Trust securities impairment	0.16	-0.20
Saxton decommissioning regulatory asset – 2007	-	-0.05
Regulatory charges	-0.55	-
Derivative mark-to-market adjustment	-0.42	-
Organizational restructuring	-0.14	-
Debt redemption premiums	-0.31	-
Income tax resolution	0.68	-
Revenues	-1.85	1.61
Fuel and purchased power	-0.09	-1.24
Amortization of regulatory assets, net	-0.02	-0.44
Investment income	0.20	0.08
Interest expense	-0.14	0.04
Reduced common shares outstanding	-	0.03
Transmission expenses	0.73	-0.02
Other expenses	0.21	0.28
Basic Earnings Per Share	$3.31	$4.41

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Company and ARO Description	In-Service Date	Long-Lived Assets
CMS Energy, including Consumers
Closure of gas treating plant and gas wells	Various	Gas transmission and storage
Closure of coal ash disposal areas	Various	Generating plants coal ash areas
Asbestos abatement	1973	Electric and gas utility plant
Gas distribution cut, purge, and cap	Various	Gas distribution mains and services
Closure of wind parks	2012, 2014	Wind generation facilities
Consumers
Closure of coal ash disposal areas	Various	Generating plants coal ash areas
Asbestos abatement	1973	Electric and gas utility plant
Gas distribution cut, purge, and cap	Various	Gas distribution mains and services
Closure of wind parks	2012, 2014	Wind generation facilities

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Company and ARO Description	ARO Liability 12/31/2013	Incurred	Settled 1	Accretion	Cash flow Revisions	In Millions ARO Liability 12/31/2014
CMS Energy, including Consumers
Gas treating plant and gas wells	$ 1	$ -	$ -	$ -	$ -	$ 1
Consumers	324	9	-12	18	-	339
Total CMS Energy	$ 325	$ 9	$ -12	$ 18	$ -	$ 340
Consumers
Coal ash disposal areas	$ 118	$ -	$ -3	$ 5	$ -	$ 120
Asbestos abatement	49	-	-1	3	-	51
Gas distribution cut, purge, and cap	154	6	-8	10	-	162
Wind parks	3	3	-	-	-	6
Total Consumers	$ 324	$ 9	$ -12	$ 18	$ -	$ 339

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Question: What is the sum of the Consumers in the section where Consumers is greater than 1 (in million)
Answer: 690.0