8-K

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT
PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934

Date of Report (Date of earliest event reported) November 30, 2010

Commission		Registrant; State of Incorporation;	IRS Employer
File Number		Address; and Telephone Number	Identification No.
1-9513	CMS ENERGY CORPORATION		38-2726431
		(A Michigan Corporation)
		One Energy Plaza
		Jackson, Michigan 49201
		(517) 788-0550
1-5611	CONSUMERS ENERGY COMPANY		38-0442310
		(A Michigan Corporation)
		One Energy Plaza
		Jackson, Michigan 49201
		(517) 788-0550

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Item 7.01. Regulation FD Disclosure.

CMS Energy Corporation’s (“CMS Energy”) management will be meeting with investors in New York City on November 30, 2010 through December 3, 2010. On December 3, 2010, CMS Energy’s chief financial officer, Tom Webb, will provide a business and financial outlook at the J.P.Morgan SMid Cap Conference, scheduled to begin at 8:45 a.m. EST. A webcast of the outlook will be available on the CMS Energy website, www.cmsenergy.com.

Copies of the CMS Energy presentations are furnished as Exhibits 99.1, 99.2 and 99.3 to this report.

In accordance with General Instruction B.2 of Form 8-K, the information in this Current Report on Form 8-K, including Exhibits 99.1, 99.2 and 99.3, shall not be deemed “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to the liabilities of that section, nor shall it be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended, except as shall be expressly set forth in such a filing.

Item 9.01. Financial Statements and Exhibits.

(d) Exhibits.

99.1 CMS Energy presentation dated November 30, 2010

99.2 CMS Energy presentation dated December 2010

99.3 CMS Energy presentation dated December 3, 2010

This Form 8-K contains “forward-looking statements” as defined in Rule 3b-6 of the Securities Exchange Act of 1934, as amended, Rule 175 of the Securities Act of 1933, as amended, and relevant legal decisions. The forward-looking statements are subject to risks and uncertainties. They should be read in conjunction with “FORWARD-LOOKING STATEMENTS AND INFORMATION” and “RISK FACTORS” sections of CMS Energy Corporation’s (“CMS Energy”) Form 10-K and Consumers Energy Company’s (“Consumers Energy”) Form 10-K each for the Year Ended December 31, 2009 and as updated in CMS Energy’s and Consumers Energy’s Forms 10-Q for the Quarters Ended March 31, 2010, June 30, 2010, and September 30, 2010. CMS Energy’s and Consumers Energy’s “FORWARD-LOOKING STATEMENTS AND INFORMATION” and “RISK FACTORS” sections are incorporated herein by reference and discuss important factors that could cause CMS Energy’s and Consumers Energy’s results to differ materially from those anticipated in such statements.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrants have duly caused this report to be signed on their behalf by the undersigned hereunto duly authorized.

	CMS ENERGY CORPORATION
Dated: November 30, 2010	By:	/s/ Thomas J. Webb
	Thomas J. Webb
	Executive Vice President and Chief Financial Officer
	CONSUMERS ENERGY COMPANY
Dated: November 30, 2010	By:	/s/ Thomas J. Webb
	Thomas J. Webb
	Executive Vice President and Chief Financial Officer

EXHIBIT INDEX

Exhibit
Number	Description of Document
99.1	CMS Energy presentation dated November 30, 2010
99.2	CMS Energy presentation dated December 2010
99.3	CMS Energy presentation dated December 3, 2010

EX-99.1

Exhibit 99.1

BMO Utility Conference November 30, 2010 Growing Forward

1 This presentation contains "forward-looking statements" as defined in Rule 3b-6 of the Securities Exchange Act of 1934, as amended, Rule 175 of the Securities Act of 1933, as amended, and relevant legal decisions. The forward-looking statements are subject to risks and uncertainties. They should be read in conjunction with "FORWARD-LOOKING STATEMENTS AND INFORMATION" and "RISK FACTORS" sections of CMS Energy's and Consumers Energy's Form 10-K for the year ended December 31 and as updated in subsequent 10-Qs. CMS Energy's and Consumers Energy's "FORWARD-LOOKING STATEMENTS AND INFORMATION" and "RISK FACTORS" sections are incorporated herein by reference and discuss important factors that could cause CMS Energy's and Consumers Energy's results to differ materially from those anticipated in such statements. The presentation also includes non-GAAP measures when describing CMS Energy's results of operations and financial performance. A reconciliation of each of these measures to the most directly comparable GAAP measure is included in the appendix and posted on our website at www.cmsenergy.com. CMS Energy expects 2010 reported earnings to be about the same as adjusted earnings. Reported earnings could vary because of several factors. CMS Energy is not providing reported earnings guidance reconciliation because of the uncertainties associated with those factors.

Consumers Energy Fourth largest combination utility in the United States 1.8 million electric and 1.7 million gas customers 9,500 MW of owned and purchased generation capacity Renewable energy 5% of present supply 307 Bcf of gas storage capacity Ludington Pumped Storage B C Cobb J H Campbell D E Karn J C Weadock Mio Alcona Cooke Foote Loud 5 Channels Hodenpyl Tippy Rogers Hardy Croton Webber Allegan Electric Gas Combination Overview Territory Investment growth balances responsible rate increases with attractive earnings growth. Zeeland 2

3 Business Strategy Consistent financial performance Fair and timely regulation Utility investment Customer value Safe, excellent operations Consistent financial performance

Key Takeaways Adjusted EPS (non-GAAP) growth (5% - 7%) Investment (not sales) driven Predictable No need for new equity next five years Risk mitigation through regulatory framework File and implement ratemaking reduces regulatory lag Sales decoupling mitigates revenue volatility Commodity cost recovery mechanism reduces price risk Competitive dividend (5% yield) Projected total shareowner return (10% - 12%) 4

Retirements Some 2010 Highlights . . . . 5 .. . . . while Michigan economy is improving. January May August August September October November December December Dividend Up 20% Up 40% Parent Financing $300 M 6.25% $250 M 4.25% $250 M 5.05% Parent Financing $226 M 4.5% $132 M 3.38% Conv Pfd Conv Debt due 2023 $100 M 6.3% Sr Notes due 2012 $226 M 4.5% $132 M 3.38% Conv Pfd Conv Debt due 2023 $100 M 6.3% Sr Notes due 2012 $226 M 4.5% $132 M 3.38% Conv Pfd Conv Debt due 2023 $100 M 6.3% Sr Notes due 2012 $226 M 4.5% $132 M 3.38% Conv Pfd Conv Debt due 2023 $100 M 6.3% Sr Notes due 2012 Rate Cases Gas Rate Order $66 M; 74% of self-implementation Gas Rate Order $66 M; 74% of self-implementation Gas Rate Order $66 M; 74% of self-implementation Electric Rate Order $146 M; 97% of self-implementation Electric Rate Order $146 M; 97% of self-implementation Electric Rate Order $146 M; 97% of self-implementation January May August August September October November December December New Issues Orders

Electric Sales Trend (weather adjusted) . . . . .. . . . improving faster than we expected. Electric Sales Year-to-Year Comparison 0 7% decline 1979 to 1982 6% decline 2007 to 2009 Forecast 6% 6

Michigan Energy Legislation . . . . Self-implement rates six months after filing; final decision within 12 months Customer charge in place for renewable energy and energy optimization plans Sales decoupling Cap on customer choice - 10% of load Natural gas and power supply costs pass through to customers .. . . . provides constructive regulatory framework. 7 Working ? ? ? ? ?

Capital Investment . . . . 2010 2011 2012 2013 2014 2015 Average Rate Base (bils) $10.2 $10.8 $11.6 $12.5 $13.4 0 Rate Base Bils $ Present Rate Base 5%-7% Reliability/Deliverability Renewables Smart Grid Environmental Maintenance Depreciation .. . . . provides earnings growth. Utility Investment $6.4 Billion 2011-2015 8

Renewable Energy Plans . . . . Michigan energy law requires: 10% renewables by 2015 Purchase 50% and build 50% Plan to invest $600 million over next five years, primarily on wind power Lake Winds Energy Park - 100 MW operational in 2012 Cross Winds Energy Park - 150 MW operational in 2014 .. . . increase renewables from 5% to 8% in 2012; and 10% by 2015. ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ Existing Renewable Facilities Proposed Company-owned Wind Facilities New Power Purchase Agreement Contracts ^ Cross Winds Energy Park Lake Winds Energy Park 9

Environmental Expenditures . . . . .. . . . are recovered in customer rates. Pollution Control Equipment Baghouse Dry Scrubber Activated Carbon SCR Boiler Burners $1.5 billion investment 2011-2015 Clean Air Act Clean Water Act Other state and federal regulations Expenditures for environmental equipment for: NOx reduction SO2 reduction Mercury reduction 10

11 Operating Cash Flow Growth . . . . .. . . . driven by investment growth. 2008 2009 2010 2011 2012 2013 2014 2015 CF after Capex -598 39 -22 20 -76 -31 -326 -144 73 160 220 325 479 384 497 271 CF after dividends 756 726 790 676 814 898 1032 987 CF after working capital 81 113 137 166 184 210 230 250 CF after interest 698 44 138 165 82 141 278 452 Operating cash flow 335 362 355 379 400 417 456 505 Amount (bils) $ Operating cash flow a up $0.1 billion per year $1.9 Interest Working capital and taxes Base Investment $1.3 $1.6 $1.7 $1.8 $1.5 $2.0 Cash flow before dividend Investment choices _ _ _ _ _ a Non-GAAP

Mitigating EPS Volatility . . . . .. . . . through decoupling, and strong performance. Old Opportunities Old Risks Decouple Decouple Cost Performance Reinvest 12

Earnings Per Share (adjusted non-GAAP) . . . . 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 History 0.81 0.9 0.96 1.08 0.84 1.21 1.26 2009 Plan 1.35 1.43 1.5 1.58 1.68 1.77 5% - 7% (2010-15) .. . . . growth track record continues to support 10% - 12% TSR growth. 2003 - 2009 8% Growth Dividend Annual ¢/share _ _ _ _ _ a $1.25 excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock b Pre increase b 13 Uniqueness Investment (vs sales) driven Investment pull (vs push) NOLs no equity need (or dilution) Risk mitigation strong Energy law Solid regulation Cost discipline Customer driven

Earnings Per Share (adjusted non-GAAP) . . . . 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 History 0.81 0.9 0.96 1.08 0.84 1.21 1.26 2009 Plan 1.35 1.43 1.5 1.58 1.68 1.77 5% - 7% (2010-15) .. . . . growth track record continues to support 10% - 12% TSR growth. 2003 - 2009 8% Growth Dividend Annual ¢/share _ _ _ _ _ a $1.25 excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock b Pre increase b 14 Uniqueness Investment (vs sales) driven Investment pull (vs push) NOLs no equity need (or dilution) Risk mitigation strong Energy law Solid regulation Cost discipline Customer driven

Appendix

"Cushion" Regulatory Timeline . . . . .. . . . well into second year under new, comprehensive Michigan energy law. 2009 2010 2010 2010 2010 2010 2010 2010 2010 2011 Fourth Quarter Fourth Quarter First Quarter Second Quarter Third Quarter Fourth Quarter Fourth Quarter First Quarter 2009 Gas Rate Case U-15986 Self-implemented $89 M Self-implemented $89 M Final Order $66 M MPSC Staff $11 M refund MPSC Staff $11 M refund Final Refund Order 2010 Gas Rate Case U-16418 Filed $55 M Self- implement 2009 Electric Rate Case U-15645 Final Order $139 M Refunded $16 M 2010 Electric General Rate Case U-16191 Filed $178 M Filed $178 M MPSC Staff $91 M Self-implemented $150 M Final Order $146 M Final Order $146 M Big Rock Point U-15611 $85 M refund $85 M refund $85 M refund $85 M refund Electric Decoupling Reconciliation U-15645 File Plug-in Electric Vehicle (PEV) Tariff MPSC approved PEV rates Appendix 1

FINAL ELECTRIC RATE CASE U-16191*

On November 4, 2010, the Michigan Public Service Commission (MPSC) authorized Consumers Energy to increase its base electric rates by $146 million annually with an authorized ROE of 10.7%. The Order approved guidelines for cost recovery of Smart Grid expenditures, required the pre-1983 Department of Energy liability funds to be placed into an external trust within six months, made no changes to the current electric revenue decoupling mechanism, and terminated the uncollectibles expense tracker as of Nov. 30^th, and the forestry tracker immediately. In July, the Company self implemented a $150 million annual rate increase. As a result of the final order, the $4 million reduction from the annual self implemented rates will be refunded to customers in early 2011 after final refund amounts are determined and authorized by Commission order. Overall, customer rates will increase 4.2% versus rates set in the last electric case (U-15645).

					MPSC
	Consumers		MPSC		Final
	Self		Final		Order
	Implemented		Order		B/(W)
Item	(Mils)		(Mils)		(Mils)			Remarks
1. O&M	$	21	$	25	$	4		Final order O&M level greater than amount self-implemented: $4
2. Gross Margin		5		19		14		Recovery of Rate E-1 economic development discount on higher sales: $11 Misc. revenue: $3
3. Investment		106		102		(4	)	Net plant: $(6) Working capital: $(6) Taxes: $2 AFUDC: $6
4. Cost of Capital		18		0		(18	)	Lower return on equity of 10.7% vs. 11%: $(12) Cost rates & capital structure: $(6)
Total	$	150	$	146	$	(4	)

				Consumers
Ratemaking	Existing			Self			MPSC
Capital Structure %	(U-15645)			Implemented			Final Order
Long Term Debt		44.80	%		41.77	%		40.62	%
Short Term Debt		0.78			1.51			1.51
Preferred Stock		0.48			0.44			0.44
Common Equity		40.51	(1)		41.49	(2)		41.59	(3)
Deferred FIT		12.80			14.26			15.30
JDITC/Other		0.63			0.53			0.54
		100.00	%		100.00	%		100.00	%

				Consumers
Rate Base and Return	Existing			Self			MPSC
Percentage	(U-15645)			Implemented			Final Order
Rate Base — Jurisdictional ($ billions)	$	6.16		$	6.97		$	6.87
Return on Rate Base		6.98	%		7.16	%		6.98	%
Return on Equity		10.70	%		11.00	%		10.70	%

(1)	Equivalent to 47.23% on a financial basis
(2)	Equivalent to 49.57% on a financial basis
(3)	Equivalent to 50.32% on a financial basis
*	Electric Rate Case U-16191 can be accessed at the Michigan Public Service Commission’s website. http://efile.mpsc.cis.state.mi.us/efile/electric.html

Appendix 2

GAS RATE CASE U-16418*

On August 13, 2010, Consumers Energy filed an application with the Michigan Public Service Commission seeking an increase in its gas delivery and transportation rates based on a 2011 test year. The Company requests an authorized ROE of 11%, and proposes a full decoupling mechanism, including weather. If approved, this request would add about $2.95 per month, or about 3.4%, to the typical residential customer’s average monthly bill. The $55 million revenue deficiency is detailed below.

Item	$ Millions		Explanation
1. O&M	$	16	Gas operations expense: $13 Lost & unaccounted for and company use gas: $3
2. Margin		4	Miscellaneous revenues
3. Investment		30	Net plant: $19 Working capital: $(2) Depreciation and property taxes: $10 Taxes, AFUDC and other: $3
4. Cost of Capital		5	Return on equity: $8 (11.00% vs 10.55%) Capital structure and lower debt costs: $(3)
Total	$	55

Ratemaking	Existing			As Filed						After-Tax
Capital Structure	(U-15986)			Percent of Total			Annual Cost			Weighted Costs
Long Term Debt		43.58	%		41.86	%		5.95	%		2.49	%
Short Term Debt		0.59			1.82			3.46			0.06
Preferred Stock		0.46			0.42			4.46			0.02
Common Equity		40.78			40.51	(1)		11.00			4.46
Deferred Taxes		13.30			14.33			0.00			0.00
JDITC/Other		1.29			1.06			6.67			0.07
		100.00	%		100.00	%					7.10	%

Rate Base and Return	Existing
Percentage	(U-15986)			As Filed
Rate Base ($ billions)	$	2.74		$	2.90
Return on Rate Base		7.02	%		7.10	%
Return on Equity		10.55	%		11.00	%

⁽¹⁾ Equivalent to 48.93% on financial basis.

GAS RATE CASE SCHEDULE

Consumers files PA 286 self-implementation rates	January 6, 2011
Staff and Intervenors file direct cases	January 24, 2011
Staff/Intervenor filings on self-implementation	January 26, 2011
Self-Implementation Hearing	January 27, 2011
Rebuttal Testimony and exhibits	February 10, 2011
Motions to Strike Testimony	February 17, 2011
Cross of all witnesses	February 23 through March 4, 2011
Initial Briefs	March 30, 2011
Reply Briefs	April 19, 2011
Proposal for Decision target date	June 2, 2011
Exceptions	June 17, 2011
Replies to Exceptions	June 27, 2011
Commission Order	Not later than August 12, 2011

* Gas Rate Case U-16418 can be accessed at the Michigan Public Service Commission’s website.
http://efile.mpsc.cis.state.mi.us/efile/gas.html

Appendix 3

Utility Risk Mitigation . . . . Appendix 4 $6.1 Billion a Sales $5.5 Billion a Cost _ _ _ _ _ a Estimated 2010 .. . . . enhanced with decoupling.

Michigan Public Service Commission (MPSC) Composed of three members appointed by the Governor with the advice and consent of the Senate Appointed to serve staggered six-year terms No more than two Commissioners may represent the same political party One Commissioner is designated as Chairman by the Governor Orjiakor Isiogu, Chairman Appointed: 9/9/07 Term Ends: 7/2/13 Democrat Monica Martinez, Commissioner Appointed: 7/3/05 Term Ends: 7/2/11 Democrat Greg White, Commissioner Appointed: 12/4/09 Term Ends: 7/2/15 Independent Appendix 5

Electric Sales Trend (weather adjusted) . . . . Industrial Sales .. . . . continues to improve in our service territory, led by industrial customers. Total 2009 2010 2011 Year over Year Comparison by Quarter 2009 2010 2011 Forecast 10% 1.5% Forecast Appendix 6

Economic Indicators - U.S. Autos . . . . .. . . . production up substantially from 2009. U.S. Production (October 9 YTD) Days Supply (September) +46% Desired Supply Desired Supply 90 60 Appendix 7

Emission Reductions . . . . Appendix 8 .. . . . reduced NOx 74% and SO2 67%.

Federal Tax Benefits Year-End Estimate 2010 2011 2012 2013 2014 (bils) (bils) (bils) (bils) (bils) Gross NOL carry forwards $ 1.2 $ 0.7 $ 0.2 $ - $ - Net NOL cash benefit at 35% 0.4 0.2 0.1 - - Credit carry forwards 0.3 0.3 0.3 0.2 0.1 Remaining cash benefit $ 0.7 $ 0.5 $ 0.4 $ 0.2 $ 0.1 Appendix 9

2010 Financing Activities 2010 Financing Activities Appendix 10 $300 300

Share Dilution Sensitivity . . . . Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Convertible Notes Convertible Notes Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Before Conversion Before Conversion 2011 Average Annual Stock Price 2.88% (mils) 5.50% (mils) Total (mils) (2011 dilution over 2010) 3.375% Notes (mils) 4.5% Preferred (mils) 2011 Average Annual Stock Price 2.88% (mils) 5.50% (mils) Total (mils) (2011 dilution over 2010) 3.375% Notes (mils) 4.5% Preferred (mils) $16 4 1 5 1% 6 12 18 6 2 8 2 7 13 20 8 3 11 3 7 14 22 9 4 13 4 8 15 24 10 5 15 5 8 16 Outstanding (mils) $288 $173 Conversion price a 13.087 14.463 Trigger Price 15.70 18.80 Appendix 11 .. . . . reduced from calling convertible preferreds and 3.375% convertible notes. _ _ _ _ _ a As of December 2010; will be adjusted for future dividend payments.

Consumers Capital Expenditures Appendix 12

GAAP Reconciliation

CMS Energy
Earnings Reconciliation By Quarter and Year
December 31
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited Quarters
(millions, except per share amounts)	1Q03			2Q03			3Q03			4Q03			FY 2003
Reported net income	$	82		$	(65	)	$	(69	)	$	8		$	(44	)
After-tax items:
Electric and gas utility other											30			30
Enterprises other		5			7			62			37			111
Corporate other		1						19			4			24
Discontinued operations		(31	)		53			(2	)		(43	)		(23	)
Cumulative accounting changes		24												24
Ongoing earnings (non-GAAP)	$	81		$	(5	)	$	10		$	36		$	122
Average shares outstanding, basic		144.1			144.1			152.2			161.1			150.4
Average shares outstanding, diluted		165.0			144.1			152.2			161.1			150.4
Reported earnings per share	$	0.52		$	(0.45	)	$	(0.46	)	$	0.05		$	(0.30	)
After-tax items
Electric and gas utility other											0.19			0.21
Enterprises other		0.03			0.05			0.41			0.23			0.74
Corporate other								0.12			0.02			0.16
Discontinued operations		(0.19	)		0.37			(0.01	)		(0.27	)		(0.16	)
Cumulative accounting changes		0.14												0.16
Ongoing earnings per share (non-GAAP)	$	0.50		$	(0.03	)	$	0.06		$	0.22		$	0.81

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

2003 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited												31-Dec
(millions, except per share amounts)	1Q04*			2Q04			3Q04			4Q04			FY 2004
Reported net income — GAAP	$	(9	)	$	16		$	56		$	47		$	110
After-tax items:
Electric and gas utility other											(67	)		(67	)
Enterprises other		88						(29	)		48			107
Corporate other		(7	)					(1	)		1			(7	)
Discontinued operations		2						(8	)		10			4
Cumulative accounting changes		2												2
Adjusted earnings, including M-T-M	$	76		$	16		$	18		$	39		$	149
Mark-to-market impacts	NM				(13	)		9			9			5
Adjusted earnings, excluding M-T-M	$	76		$	3		$	27		$	48		$	154
Average shares outstanding, basic		161.1			161.2			161.5			190.2			168.6
Average shares outstanding, diluted		161.1			164.2			165.0			194.0			172.1
Reported earnings per share — GAAP	$	(0.06	)	$	0.10		$	0.34		$	0.24		$	0.64
After-tax items
Electric and gas utility other											(0.35	)		(0.39	)
Enterprises other		0.56						(0.17	)		0.25			0.62
Corporate other		(0.05	)					(0.01	)		0.01			(0.03	)
Discontinued operations		0.01						(0.05	)		0.05			0.02
Cumulative accounting changes		0.01												0.01
Adjusted earnings per share, including M-T-M	$	0.47		$	0.10		$	0.11		$	0.20		$	0.87
Mark-to-market impacts	NM				(0.08	)		0.06			0.05			0.03
Adjusted earnings per share, excluding M-T-M	$	0.47		$	0.02		$	0.17		$	0.25		$	0.90

Note: Year-to-date & full-year EPS may not equal sum of quarters due to share count differences.

* Quarterly amounts differ from amounts previously reported due to accelerating the measurement date on our benefit plans by one month and the remeasurement of our post retirement obligation.

NM: Not meaningful.

2004 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited												31-Dec
(millions, except per share amounts)	1Q05			2Q05			3Q05			4Q05			FY 2005
Reported net income — GAAP	$	150		$	27		$	(265	)	$	(6	)	$	(94	)
After-tax items:
Electric and gas utility other
Enterprises other		(2	)		(1	)		(1	)		13			9
Corporate other					1						8			9
Discontinued operations											(14	)		(14	)
Asset impairment								385						385
Adjusted earnings, including M-T-M	$	148		$	27		$	119		$	1		$	295
Mark-to-market impacts		(75	)		19			(75	)		40			(91	)
Adjusted earnings, excluding M-T-M	$	73		$	46		$	44		$	41		$	204
Average shares outstanding, basic		195.3			217.9			219.6			218.5			211.8
Average shares outstanding, diluted		206.3			228.9			219.6			218.5			211.8
Reported earnings per share — GAAP	$	0.74		$	0.12		$	(1.21	)	$	(0.03	)	$	(0.44	)
After-tax items
Electric and gas utility other
Enterprises other		(0.01	)	NM			NM				0.06			0.04
Corporate other				NM							0.03			0.04
Discontinued operations											(0.06	)		(0.07	)
Asset impairment								1.75						1.82
Adjusted earnings per share, including M-T-M	$	0.73		$	0.12		$	0.54		$	0.00		$	1.39
Mark-to-market impacts		(0.36	)		0.08			(0.34	)		0.19			(0.43	)
Adjusted earnings per share, excluding M-T-M	$	0.37		$	0.20		$	0.20		$	0.19		$	0.96

Note: Year-to-date & full-year EPS may not equal sum of quarters due to share count differences.

2005 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with

Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited
	2006												2006
(In millions, except per share amounts)	1Q			2Q			3Q			4Q			Dec YTD
Reported net income — GAAP	$	(27	)	$	72		$	(103	)	$	(32	)	$	(90	)
After-tax items:
Electric and gas utility other		—			—			—			—			—
Enterprises other		—			—			(29	)		25			(4	)
Corporate interest and other		2			(15	)		4			82			73
Discontinued operations (gain)		(1	)		(2	)		(1	)		(2	)		(6	)
Asset impairment charges		—			—			169			—			169
Adjusted earnings, including MTM	$	(26	)	$	55		$	40		$	73		$	142
Mark-to-market impacts		74			21			30			(13	)		112
Adjusted earnings, excluding MTM	$	48		$	76		$	70		$	60		$	254
Average shares outstanding, basic		219.1			219.6			220.1			220.6			219.9
Average shares outstanding, diluted		219.1			229.6			220.1			220.6			219.9
Reported earnings per share — GAAP	$	(0.12	)	$	0.31		$	(0.47	)	$	(0.15	)	$	(0.41	)
After-tax items
Electric and gas utility other		—			—			—			—			—
Enterprises other		—			—			(0.13	)		0.11			(0.02	)
Corporate other		0.01			(0.07	)		0.02			0.38			0.27
Discontinued operations		(0.01	)		(0.01	)		—			(0.01	)		(0.03	)
Asset impairment charges		—			—			0.76			—			0.76
Adjusted earnings per share, including MTM	$	(0.12	)	$	0.23		$	0.18		$	0.33		$	0.57
Mark-to-market impacts		0.34			0.10			0.13			(0.06	)		0.51
Adjusted earnings per share, excluding MTM	$	0.22		$	0.33		$	0.31		$	0.27		$	1.08

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

NM: Not Meaningful.

2006 A-1

CMS Energy Corporation
Earnings By Quarter and Year GAAP Reconciliation
(Unaudited)

	(In millions, except per share amounts)
	2007
	1Q			2Q			3Q			4Q			Dec YTD
Reported net income (loss) — GAAP	$	(215	)	$	33		$	82		$	(127	)	$	(227	)
After-tax items:
Electric and gas utility		4			—			—			—			4
Enterprises		49			19			(10	)		222			280
Corporate interest and other		(81	)		32			9			(38	)		(78	)
Discontinued operations (income) loss		178			(91	)		—			2			89
Asset impairment charges, net		157			25			(49	)		—			133
Adjusted income — non-GAAP	$	92		$	18		$	32		$	59		$	201
Average shares outstanding, basic		221.5			222.6			223.0			223.4			222.6
Average shares outstanding, diluted		221.5			222.6			241.3			223.4			222.6
Reported earnings (loss) per share — GAAP	$	(0.97	)	$	0.15		$	0.34		$	(0.57	)	$	(1.02	)
After-tax items:
Electric and gas utility		0.01			—			—			—			(0.07	)
Enterprises		0.23			0.08			(0.04	)		0.99			1.25
Corporate interest and other		(0.36	)		0.15			0.03			(0.17	)		(0.32	)
Discontinued operations (income) loss		0.80			(0.41	)		—			0.01			0.40
Asset impairment charges, net		0.71			0.11			(0.20	)		—			0.60
Adjusted earnings per share — non-GAAP	$	0.42		$	0.08		$	0.13		$	0.26		$	0.84

(In millions, except per share amounts)	2008
	1Q			2Q			3Q			4Q		Dec YTD
Reported net income — GAAP	$	102		$	44		$	78		$	60	$	284
After-tax items:
Electric and gas utility		—			1			6			5		12
Enterprises		*			(4	)		*			1		(3	)
Corporate interest and other		—			—			(6	)		1		(5	)
Discontinued operations (income) loss		(1	)		1			(1	)		*		(1	)
Adjusted income — non-GAAP	$	101		$	42		$	77		$	67	$	287
Average shares outstanding, basic		225.2			225.4			225.8			226.3		225.7
Average shares outstanding, diluted		237.6			240.6			236.3			228.1		236.2
Reported earnings per share — GAAP	$	0.43		$	0.18		$	0.33		$	0.26	$	1.20
After-tax items:
Electric and gas utility		—			0.01			0.02			0.03		0.05
Enterprises		*			(0.02	)		0.01			0.01		(0.02	)
Corporate interest and other		—			—			(0.03	)		*		(0.02	)
Discontinued operations (income) loss		(*	)		—			(0.01	)		*		(*	)
Adjusted earnings per share — non-GAAP (a)	$	0.43		$	0.17		$	0.32		$	0.30	$	1.21

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

*	Less than $500 thousand or $0.01 per share.
(a)	Excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock, adjusted earnings per share was $0.44, $0.19, $0.33, $0.30, and $1.25, respectively.

2008 A-1

CMS ENERGY CORPORATION
Earnings By Quarter and Year GAAP Reconciliation
(Unaudited)

(In millions, except per share amounts)	2009
	1Q		2Q			3Q		4Q			Dec YTD
Reported net income — GAAP	$	70	$	75		$	67	$	6		$	218
After-tax items:
Electric and gas utility		—		—			—		79			79
Enterprises		*		16			2		4			22
Corporate interest and other		*		1			1		(1	)		1
Discontinued operations (income) loss		1		(25	)		1		3			(20	)
Adjusted income — non-GAAP	$	71	$	67		$	71	$	91		$	300
Average shares outstanding, basic		226.6		226.9			227.3		227.8			227.2
Average shares outstanding, diluted		233.2		234.6			238.5		243.0			237.9
Reported earnings per share — GAAP	$	0.30	$	0.32		$	0.28	$	0.02		$	0.91
After-tax items:
Electric and gas utility		—		—			—		0.33			0.33
Enterprises		*		0.07			0.01		0.02			0.09
Corporate interest and other		*		*			*		(*	)		0.01
Discontinued operations (income) loss		0.01		(0.11	)		0.01		0.01			(0.08	)
Adjusted earnings per share — non-GAAP	$	0.31	$	0.28		$	0.30	$	0.38		$	1.26

(In millions, except per share amounts)	2010
	1Q		2Q			3Q
Reported net income — GAAP	$	85	$	80		$	134
After-tax items:
Electric and gas utility		6		—			—
Enterprises		1		(31	)		(2	)
Corporate interest and other		*		*			—
Discontinued operations loss		1		16			*
Adjusted income — non-GAAP	$	93	$	65		$	132
Average shares outstanding, basic		228.0		228.2			229.0
Average shares outstanding, diluted		246.5		247.6			254.7
Reported earnings per share — GAAP	$	0.34	$	0.32		$	0.53
After-tax items:
Electric and gas utility		0.03		—			—
Enterprises		*		(0.13	)		(0.01	)
Corporate interest and other		*		*			—
Discontinued operations loss		0.01		0.07			*
Adjusted earnings per share — non-GAAP	$	0.38	$	0.26		$	0.52

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

* Less than $500 thousand or $0.01 per share.

2010 A-1

CMS Energy Corporation
Earnings Segment Results GAAP Reconciliation
(Unaudited)

	Three Months Ended
September 30	2010			2009
Electric Utility
Reported	$	0.61		$	0.46
Downsizing Program		—			—
Adjusted	$	0.61		$	0.46
Gas Utility
Reported	$	0.01		$	(0.05	)
Downsizing Program		—			—
Adjusted	$	0.01		$	(0.05	)
Enterprises
Reported	$	0.04		$	0.02
Asset Sales (Gain) Loss and Other		(0.01	)		0.01
Adjusted	$	0.03		$	0.03
Corporate Interest and Other
Reported	$	(0.13	)	$	(0.14	)
Asset Sales Loss and Other		—			*
Adjusted	$	(0.13	)	$	(0.14	)
Discontinued Operations
Reported	$	(*	)	$	(0.01	)
Discontinued Operations Loss (Gain)		*			0.01
Adjusted	$	—		$	—
Totals
Reported	$	0.53		$	0.28
Discontinued Operations Loss (Gain)		*			0.01
Downsizing Program		—			—
Asset Sales (Gain) Loss and Other		(0.01	)		0.01
Adjusted	$	0.52		$	0.30
Average Common Shares Outstanding — Diluted (in millions)		254.7			238.5

2010 A-2

Consumers Energy
2010 Forecasted Cash Flow GAAP Reconciliation (in millions) (unaudited)

				Reclassifications From Sources and Uses to Statement of Cash Flows
Presentation Sources and Uses				Tax			Interest			Pension			Accts/Rec			Capital			Securitization			Preferred			Common			Consolidated Statements of Cash Flows
	non-GAAP			Sharing			Payments			Contribution			Financing			Lease Pymts			Debt Pymts			Dividends			Dividends			GAAP
Description	Amount			Operating			as Operating			as Operating			as Operating			as Financing			as Financing			as Financing			as Financing			Amount			Description
Cash at year end 2009	$	39		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	39		Cash at year end 2009
Sources
Operating	$	1,485		$	(130	)	$	(221	)	$	—		$	—		$	23		$	35		$	—		$	—		$	1,192
Other working capital		(30	)		—			—			(97	)		(50	)		—			—			—			—			(177	)	Net cash provided by operating activities
Sources	$	1,455		$	(130	)	$	(221	)	$	(97	)	$	(50	)	$	23		$	35		$	—		$	—		$	1,015
Uses
Interest and preferred dividends	$	(223	)	$	—		$	221		$	—		$	—		$	—		$	—		$	2		$	—		$	—
Pension Contribution		(97	)		—			—			97			—			—			—			—			—			—
Capital expenditures		(950	)		—			—			—			—			—			—			—			—			(950	)
Dividends/tax sharing to CMS		(490	)		130			—			—			—			—			—			—			360			—		Net cash provided by investing activities
Uses	$	(1,760	)	$	130		$	221		$	97		$	—		$	—		$	—		$	2		$	360		$	(950	)	Cash flow from operating and investing activities
Cash flow	$	(305	)	$	—		$	—		$	—		$	(50	)	$	23		$	35		$	2		$	360		$	65
Financing
Equity	$	250		$	—		$	—		$	—		$	—		$	—		$	—		$	(2	)	$	—		$	248
New Issues		600			—			—			—			—			—			—			—			—			600
Retirements		(446	)		—			—			—			—			(23	)		(35	)		—			(360	)		(864	)
Net short-term financing & other		(53	)		—			—			—			50			—			—			—			—			(3	)	Net cash provided by financing activities
Financing	$	351		$	—		$	—		$	—		$	50		$	(23	)	$	(35	)	$	(2	)	$	(360	)	$	(19	)
Net change in cash	$	46		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	46		Net change in cash
Cash at year end 2010	$	85		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	85		Cash at year end 2010

2010 A-3

CMS Energy Parent
2010 Forecasted Cash Flow GAAP Reconciliation (in millions) (unaudited)

				Reclassifications From Sources and Uses to Statement of Cash Flows
Presentation Sources and Uses				Interest			Overheads &			Other			Preferred			Cash From			Consolidated Statements of Cash Flows
	non-GAAP			Payments			Tax Payments			Uses (a)			Dividends			Consolidated			GAAP
Description	Amount			as Operating			as Operating			as Operating			as Financing			Companies			Amount			Description
Cash at year end 2009	$	23		$	—		$	—		$	—		$	—		$	28		$	51		Cash at year end 2009
Sources
Consumers Energy dividends/tax sharing	$	490		$	(122	)	$	(20	)	$	—		$	—		$	—		$	348
Enterprises		30																		30
Insurance settlement		50			—			—			(8	)		—			10			52		Net cash provided by operating activities
Sources	$	570		$	(122	)	$	(20	)	$	(8	)	$	—		$	10		$	430
Uses
Interest and preferred dividends	$	(130	)	$	122		$	—		$	—		$	8		$	—		$	—
Overhead and Federal tax payments		(20	)		—			20			—			—			—			—
Pension Contributions		(3	)		—			—			—			—			—			(3	)
Equity infusions		(250	)		—			—			8			—			(85	)		(327	)	Net cash provided by investing activities
Uses (a)	$	(415	)	$	122		$	20		$	8		$	8		$	(85	)	$	(342	)
Cash flow	$	155		$	—		$	—		$	—		$	8		$	(75	)	$	88		Cash flow from operating and investing activities
Financing and dividends
New Issues	$	550		$	—		$	—		$	—		$	(8	)	$	105		$	647
Retirements		(314	)		—			—			—			—			(40	)		(354	)
Net short-term financing & other		(23	)		—			—			—			—			—			(23	)
Common dividend		(151	)		—			—			—			—			—			(151	)	Net cash provided by financing activities
Financing	$	62		$	—		$	—		$	—		$	(8	)	$	65		$	119
Net change in cash	$	217		$	—		$	—		$	—		$	—		$	(10	)	$	207		Net change in cash
Cash at year end 2010	$	240		$	—		$	—		$	—		$	—		$	18		$	258		Cash at year end 2010

(a) Includes other and roundings

2010 A-4

Consolidated CMS Energy
2010 Forecasted Consolidation of Consumers Energy and CMS Energy Parent Statements of Cash Flow (in millions) (unaudited)

							Eliminations/Reclassifications to Arrive at the
							Consolidated Statement of Cash Flows
Statements of Cash Flows							Consumers			Equity
	Consumers			CMS Parent			Common Dividend			Infusions to			Consolidated Statements of Cash Flows
Description	Amount			Amount			as Financing			Consumers			Amount			Description
Cash at year end 2009	$	39		$	51		$	—		$	—		$	90		Cash at year end 2009
Net cash provided by operating activities	$	1,015		$	430		$	(360	)	$	—		$	1,085		Net cash provided by operating activities
Net cash provided by investing activities		(950	)		(342	)		—			250			(1,042	)	Net cash provided by investing activities
Cash flow from operating and investing activities	$	65		$	88		$	(360	)	$	250		$	43		Cash flow from operating and investing activities
Net cash provided by financing activities	$	(19	)	$	119		$	360		$	(250	)	$	210		Net cash provided by financing activities
Net change in cash	$	46		$	207		$	—		$	—		$	253		Net change in cash
Cash at year end 2010	$	85		$	258		$	—		$	—		$	343		Cash at year end 2010

2010 A-5

CMS Energy
Reconciliation of 2010 Operating Cash Flow Target to GAAP Operating Activities
(unaudited)

	Amount
	(mils)
Consumers Operating (Consumers PTOI + Depreciation)	$	1,485
Enterprises (Project Cash Flows)		30
Operating Cash Flow	$	1,515		non-GAAP
Other operating activies including taxes, interest payments and working capital		(430	)
Net cash provided by operating activites	$	1,085		GAAP

2010 A-6

EX-99.2

Exhibit 99.2

Investor Meetings December 2010 Growing Forward

1 This presentation contains "forward-looking statements" as defined in Rule 3b-6 of the Securities Exchange Act of 1934, as amended, Rule 175 of the Securities Act of 1933, as amended, and relevant legal decisions. The forward-looking statements are subject to risks and uncertainties. They should be read in conjunction with "FORWARD-LOOKING STATEMENTS AND INFORMATION" and "RISK FACTORS" sections of CMS Energy's and Consumers Energy's Form 10-K for the year ended December 31 and as updated in subsequent 10-Qs. CMS Energy's and Consumers Energy's "FORWARD-LOOKING STATEMENTS AND INFORMATION" and "RISK FACTORS" sections are incorporated herein by reference and discuss important factors that could cause CMS Energy's and Consumers Energy's results to differ materially from those anticipated in such statements. The presentation also includes non-GAAP measures when describing CMS Energy's results of operations and financial performance. A reconciliation of each of these measures to the most directly comparable GAAP measure is included in the appendix and posted on our website at www.cmsenergy.com. CMS Energy expects 2010 reported earnings to be about the same as adjusted earnings. Reported earnings could vary because of several factors. CMS Energy is not providing reported earnings guidance reconciliation because of the uncertainties associated with those factors.

Consumers Energy Fourth largest combination utility in the United States 1.8 million electric and 1.7 million gas customers 9,500 MW of owned and purchased generation capacity Renewable energy 5% of present supply 307 Bcf of gas storage capacity Ludington Pumped Storage B C Cobb J H Campbell D E Karn J C Weadock Mio Alcona Cooke Foote Loud 5 Channels Hodenpyl Tippy Rogers Hardy Croton Webber Allegan Electric Gas Combination Overview Territory Investment growth balances responsible rate increases with attractive earnings growth. Zeeland 2

3 Business Strategy Consistent financial performance Fair and timely regulation Utility investment Customer value Safe, excellent operations Consistent financial performance

Key Takeaways Adjusted EPS (non-GAAP) growth (5% - 7%) Investment (not sales) driven Predictable No need for new equity next five years Risk mitigation through regulatory framework File and implement ratemaking reduces regulatory lag Sales decoupling mitigates revenue volatility Commodity cost recovery mechanism reduces price risk Competitive dividend (5% yield) Projected total shareowner return (10% - 12%) 4

Retirements Some 2010 Highlights . . . . 5 .. . . . while Michigan economy is improving. New Issues Orders

Electric Sales Trend (weather adjusted) . . . . .. . . . improving faster than we expected. Electric Sales Year-to-Year Comparison 0 7% decline 1979 to 1982 6% decline 2007 to 2009 Forecast 6% 6

Michigan Energy Legislation . . . . Self-implement rates six months after filing; final decision within 12 months Customer charge in place for renewable energy and energy optimization plans Sales decoupling Cap on customer choice - 10% of load Natural gas and power supply costs pass through to customers .. . . . provides constructive regulatory framework. 7 Working ? ? ? ? ?

Capital Investment . . . . 2010 2011 2012 2013 2014 2015 Average Rate Base (bils) $10.2 $10.8 $11.6 $12.5 $13.4 0 Rate Base Bils $ Present Rate Base 5%-7% Reliability/Deliverability Renewables Smart Grid Environmental Maintenance Depreciation .. . . . provides earnings growth. Utility Investment $6.4 Billion 2011-2015 8

Renewable Energy Plans . . . . Michigan energy law requires: 10% renewables by 2015 Purchase 50% and build 50% Plan to invest $600 million over next five years, primarily on wind power Lake Winds Energy Park - 100 MW operational in 2012 Cross Winds Energy Park - 150 MW operational in 2014 .. . . increase renewables from 5% to 8% in 2012; and 10% by 2015. ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ Existing Renewable Facilities Proposed Company-owned Wind Facilities New Power Purchase Agreement Contracts ^ Cross Winds Energy Park Lake Winds Energy Park 9

Environmental Expenditures . . . . .. . . . are recovered in customer rates. Pollution Control Equipment Baghouse Dry Scrubber Activated Carbon SCR Boiler Burners $1.5 billion investment 2011-2015 Clean Air Act Clean Water Act Other state and federal regulations Expenditures for environmental equipment for: NOx reduction SO2 reduction Mercury reduction 10

11 Operating Cash Flow Growth . . . . .. . . . driven by investment growth. 2008 2009 2010 2011 2012 2013 2014 2015 CF after Capex -598 39 -22 20 -76 -31 -326 -144 73 160 220 325 479 384 497 271 CF after dividends 756 726 790 676 814 898 1032 987 CF after working capital 81 113 137 166 184 210 230 250 CF after interest 698 44 138 165 82 141 278 452 Operating cash flow 335 362 355 379 400 417 456 505 Amount (bils) $ Operating cash flow a up $0.1 billion per year $1.9 Interest Working capital and taxes Base Investment $1.3 $1.6 $1.7 $1.8 $1.5 $2.0 Cash flow before dividend Investment choices _ _ _ _ _ a Non-GAAP

Mitigating EPS Volatility . . . . .. . . . through decoupling, and strong performance. Old Opportunities Old Risks Decouple Decouple Cost Performance Reinvest 12

Earnings Per Share (adjusted non-GAAP) . . . . 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 History 0.81 0.9 0.96 1.08 0.84 1.21 1.26 2009 Plan 1.35 1.43 1.5 1.58 1.68 1.77 5% - 7% (2010-15) .. . . . growth track record continues to support 10% - 12% TSR growth. 2003 - 2009 8% Growth Dividend Annual ¢/share _ _ _ _ _ a $1.25 excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock b Pre increase b 13 Uniqueness Investment (vs sales) driven Investment pull (vs push) NOLs no equity need (or dilution) Risk mitigation strong Energy law Solid regulation Cost discipline Customer driven

Earnings Per Share (adjusted non-GAAP) . . . . 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 History 0.81 0.9 0.96 1.08 0.84 1.21 1.26 2009 Plan 1.35 1.43 1.5 1.58 1.68 1.77 5% - 7% (2010-15) .. . . . growth track record continues to support 10% - 12% TSR growth. 2003 - 2009 8% Growth Dividend Annual ¢/share _ _ _ _ _ a $1.25 excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock b Pre increase b 14 Uniqueness Investment (vs sales) driven Investment pull (vs push) NOLs no equity need (or dilution) Risk mitigation strong Energy law Solid regulation Cost discipline Customer driven

Appendix

"Cushion" Regulatory Timeline . . . . .. . . . well into second year under new, comprehensive Michigan energy law. .. . . . well into second year under new, comprehensive Michigan energy law. Appendix 1

FINAL ELECTRIC RATE CASE U-16191*

On November 4, 2010, the Michigan Public Service Commission (MPSC) authorized Consumers Energy to increase its base electric rates by $146 million annually with an authorized ROE of 10.7%. The Order approved guidelines for cost recovery of Smart Grid expenditures, required the pre-1983 Department of Energy liability funds to be placed into an external trust within six months, made no changes to the current electric revenue decoupling mechanism, and terminated the uncollectibles expense tracker as of Nov. 30^th, and the forestry tracker immediately. In July, the Company self implemented a $150 million annual rate increase. As a result of the final order, the $4 million reduction from the annual self implemented rates will be refunded to customers in early 2011 after final refund amounts are determined and authorized by Commission order. Overall, customer rates will increase 4.2% versus rates set in the last electric case (U-15645).

					MPSC
	Consumers		MPSC		Final
	Self		Final		Order
	Implemented		Order		B/(W)
Item	(Mils)		(Mils)		(Mils)			Remarks
1. O&M	$	21	$	25	$	4		Final order O&M level greater than amount self- implemented: $4
2. Gross Margin		5		19		14		Recovery of Rate E-1 economic development discount on higher sales: $11 Misc. revenue: $3
3. Investment		106		102		(4	)	Net plant: $(6) Working capital: $(6) Taxes: $2 AFUDC: $6
4. Cost of Capital		18		0		(18	)	Lower return on equity of 10.7% vs. 11%: $(12) Cost rates & capital structure: $(6)
Total	$	150	$	146	$	(4	)

				Consumers
Ratemaking	Existing			Self			MPSC
Capital Structure %	(U-15645)			Implemented			Final Order
Long Term Debt		44.80	%		41.77	%		40.62	%
Short Term Debt		0.78			1.51			1.51
Preferred Stock		0.48			0.44			0.44
Common Equity		40.51	(1)		41.49	(2)		41.59	(3)
Deferred FIT		12.80			14.26			15.30
JDITC/Other		0.63			0.53			0.54
		100.00	%		100.00	%		100.00	%

				Consumers
Rate Base and Return	Existing			Self			MPSC
Percentage	(U-15645)			Implemented			Final Order
Rate Base – Jurisdictional ($ billions)	$	6.16		$	6.97		$	6.87
Return on Rate Base		6.98	%		7.16	%		6.98	%
Return on Equity		10.70	%		11.00	%		10.70	%

(1)	Equivalent to 47.23% on a financial basis
(2)	Equivalent to 49.57% on a financial basis
(3)	Equivalent to 50.32% on a financial basis
*	Electric Rate Case U-16191 can be accessed at the Michigan Public Service Commission’s website. http://efile.mpsc.cis.state.mi.us/efile/electric.html

Appendix 2

GAS RATE CASE U-16418*

On August 13, 2010, Consumers Energy filed an application with the Michigan Public Service Commission seeking an increase in its gas delivery and transportation rates based on a 2011 test year. The Company requests an authorized ROE of 11%, and proposes a full decoupling mechanism, including weather. If approved, this request would add about $2.95 per month, or about 3.4%, to the typical residential customer’s average monthly bill. The $55 million revenue deficiency is detailed below.

Item	$ Millions		Explanation
1. O&M	$	16	Gas operations expense: $13 Lost & unaccounted for and company use gas: $3
2. Margin		4	Miscellaneous revenues
3. Investment		30	Net plant: $19 Working capital: $(2) Depreciation and property taxes: $10 Taxes, AFUDC and other: $3
4. Cost of Capital		5	Return on equity: $8 (11.00% vs 10.55%) Capital structure and lower debt costs: $(3)
Total	$	55

Ratemaking	Existing			As Filed						After-Tax
Capital Structure	(U-15986)			Percent of Total			Annual Cost			Weighted Costs
Long Term Debt		43.58	%		41.86	%		5.95	%		2.49	%
Short Term Debt		0.59			1.82			3.46			0.06
Preferred Stock		0.46			0.42			4.46			0.02
Common Equity		40.78			40.51	(1)		11.00			4.46
Deferred Taxes		13.30			14.33			0.00			0.00
JDITC/Other		1.29			1.06			6.67			0.07
		100.00	%		100.00	%					7.10	%

Rate Base and Return	Existing
Percentage	(U-15986)			As Filed
Rate Base ($ billions)	$	2.74		$	2.90
Return on Rate Base		7.02	%		7.10	%
Return on Equity		10.55	%		11.00	%

⁽¹⁾ Equivalent to 48.93% on financial basis.

GAS RATE CASE SCHEDULE

Consumers files PA 286 self-implementation rates	January 6, 2011
Staff and Intervenors file direct cases	January 24, 2011
Staff/Intervenor filings on self-implementation	January 26, 2011
Self-Implementation Hearing	January 27, 2011
Rebuttal Testimony and exhibits	February 10, 2011
Motions to Strike Testimony	February 17, 2011
Cross of all witnesses	February 23 through March 4, 2011
Initial Briefs	March 30, 2011
Reply Briefs	April 19, 2011
Proposal for Decision target date	June 2, 2011
Exceptions	June 17, 2011
Replies to Exceptions	June 27, 2011
Commission Order	Not later than August 12, 2011

* Gas Rate Case U-16418 can be accessed at the Michigan Public Service Commission’s website. http://efile.mpsc.cis.state.mi.us/efile/gas.html

Appendix 3

Utility Risk Mitigation . . . . Appendix 4 $6.1 Billion a Sales $5.5 Billion a Cost _ _ _ _ _ a Estimated 2010 .. . . . enhanced with decoupling.

Michigan Public Service Commission (MPSC) Composed of three members appointed by the Governor with the advice and consent of the Senate Appointed to serve staggered six-year terms No more than two Commissioners may represent the same political party One Commissioner is designated as Chairman by the Governor Orjiakor Isiogu, Chairman Appointed: 9/9/07 Term Ends: 7/2/13 Democrat Monica Martinez, Commissioner Appointed: 7/3/05 Term Ends: 7/2/11 Democrat Greg White, Commissioner Appointed: 12/4/09 Term Ends: 7/2/15 Independent Appendix 5

Electric Sales Trend (weather adjusted) . . . . Industrial Sales .. . . . continues to improve in our service territory, led by industrial customers. Total 2009 2010 2011 Year over Year Comparison by Quarter 2009 2010 2011 Forecast 10% 1.5% Forecast Appendix 6

Economic Indicators - U.S. Autos . . . . .. . . . production up substantially from 2009. U.S. Production (October 9 YTD) Days Supply (September) +46% Desired Supply Desired Supply 90 60 Appendix 7

Emission Reductions . . . . Appendix 8 .. . . . reduced NOx 74% and SO2 67%.

Federal Tax Benefits Year-End Estimate 2010 2011 2012 2013 2014 (bils) (bils) (bils) (bils) (bils) Gross NOL carry forwards $ 1.2 $ 0.7 $ 0.2 $ - $ - Net NOL cash benefit at 35% 0.4 0.2 0.1 - - Credit carry forwards 0.3 0.3 0.3 0.2 0.1 Remaining cash benefit $ 0.7 $ 0.5 $ 0.4 $ 0.2 $ 0.1 Appendix 9

2010 Financing Activities 2010 Financing Activities Appendix 10 $300 300

Share Dilution Sensitivity . . . . Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Convertible Notes Convertible Notes Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Before Conversion Before Conversion 2011 Average Annual Stock Price 2.88% (mils) 5.50% (mils) Total (mils) (2011 dilution over 2010) 3.375% Notes (mils) 4.5% Preferred (mils) 2011 Average Annual Stock Price 2.88% (mils) 5.50% (mils) Total (mils) (2011 dilution over 2010) 3.375% Notes (mils) 4.5% Preferred (mils) $16 4 1 5 1% 6 12 18 6 2 8 2 7 13 20 8 3 11 3 7 14 22 9 4 13 4 8 15 24 10 5 15 5 8 16 Outstanding (mils) $288 $173 Conversion price a 13.087 14.463 Trigger Price 15.70 18.80 Appendix 11 .. . . . reduced from calling convertible preferreds and 3.375% convertible notes. _ _ _ _ _ a As of December 2010; will be adjusted for future dividend payments.

Consumers Capital Expenditures Appendix 12

GAAP Reconciliation

CMS Energy
Earnings Reconciliation By Quarter and Year
December 31
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited Quarters
(millions, except per share amounts)	1Q03			2Q03			3Q03			4Q03			FY 2003
Reported net income	$	82		$	(65	)	$	(69	)	$	8		$	(44	)
After-tax items:
Electric and gas utility other											30			30
Enterprises other		5			7			62			37			111
Corporate other		1						19			4			24
Discontinued operations		(31	)		53			(2	)		(43	)		(23	)
Cumulative accounting changes		24												24
Ongoing earnings (non-GAAP)	$	81		$	(5	)	$	10		$	36		$	122
Average shares outstanding, basic		144.1			144.1			152.2			161.1			150.4
Average shares outstanding, diluted		165.0			144.1			152.2			161.1			150.4
Reported earnings per share	$	0.52		$	(0.45	)	$	(0.46	)	$	0.05		$	(0.30	)
After-tax items
Electric and gas utility other											0.19			0.21
Enterprises other		0.03			0.05			0.41			0.23			0.74
Corporate other								0.12			0.02			0.16
Discontinued operations		(0.19	)		0.37			(0.01	)		(0.27	)		(0.16	)
Cumulative accounting changes		0.14												0.16
Ongoing earnings per share (non-GAAP)	$	0.50		$	(0.03	)	$	0.06		$	0.22		$	0.81

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

2003 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited												31-Dec
(millions, except per share amounts)	1Q04*			2Q04			3Q04			4Q04			FY 2004
Reported net income — GAAP	$	(9	)	$	16		$	56		$	47		$	110
After-tax items:
Electric and gas utility other											(67	)		(67	)
Enterprises other		88						(29	)		48			107
Corporate other		(7	)					(1	)		1			(7	)
Discontinued operations		2						(8	)		10			4
Cumulative accounting changes		2												2
Adjusted earnings, including M-T-M	$	76		$	16		$	18		$	39		$	149
Mark-to-market impacts	NM				(13	)		9			9			5
Adjusted earnings, excluding M-T-M	$	76		$	3		$	27		$	48		$	154
Average shares outstanding, basic		161.1			161.2			161.5			190.2			168.6
Average shares outstanding, diluted		161.1			164.2			165.0			194.0			172.1
Reported earnings per share — GAAP	$	(0.06	)	$	0.10		$	0.34		$	0.24		$	0.64
After-tax items
Electric and gas utility other											(0.35	)		(0.39	)
Enterprises other		0.56						(0.17	)		0.25			0.62
Corporate other		(0.05	)					(0.01	)		0.01			(0.03	)
Discontinued operations		0.01						(0.05	)		0.05			0.02
Cumulative accounting changes		0.01												0.01
Adjusted earnings per share, including M-T-M	$	0.47		$	0.10		$	0.11		$	0.20		$	0.87
Mark-to-market impacts	NM				(0.08	)		0.06			0.05			0.03
Adjusted earnings per share, excluding M-T-M	$	0.47		$	0.02		$	0.17		$	0.25		$	0.90

Note: Year-to-date & full-year EPS may not equal sum of quarters due to share count differences.

* Quarterly amounts differ from amounts previously reported due to accelerating the measurement date on our benefit plans by one month and the remeasurement of our post retirement obligation.

NM: Not meaningful.

2004 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited												31-Dec
(millions, except per share amounts)	1Q05			2Q05			3Q05			4Q05			FY 2005
Reported net income — GAAP	$	150		$	27		$	(265	)	$	(6	)	$	(94	)
After-tax items:
Electric and gas utility other
Enterprises other		(2	)		(1	)		(1	)		13			9
Corporate other					1						8			9
Discontinued operations											(14	)		(14	)
Asset impairment								385						385
Adjusted earnings, including M-T-M	$	148		$	27		$	119		$	1		$	295
Mark-to-market impacts		(75	)		19			(75	)		40			(91	)
Adjusted earnings, excluding M-T-M	$	73		$	46		$	44		$	41		$	204
Average shares outstanding, basic		195.3			217.9			219.6			218.5			211.8
Average shares outstanding, diluted		206.3			228.9			219.6			218.5			211.8
Reported earnings per share — GAAP	$	0.74		$	0.12		$	(1.21	)	$	(0.03	)	$	(0.44	)
After-tax items
Electric and gas utility other
Enterprises other		(0.01	)	NM			NM				0.06			0.04
Corporate other				NM							0.03			0.04
Discontinued operations											(0.06	)		(0.07	)
Asset impairment								1.75						1.82
Adjusted earnings per share, including M-T-M	$	0.73		$	0.12		$	0.54		$	0.00		$	1.39
Mark-to-market impacts		(0.36	)		0.08			(0.34	)		0.19			(0.43	)
Adjusted earnings per share, excluding M-T-M	$	0.37		$	0.20		$	0.20		$	0.19		$	0.96

Note: Year-to-date & full-year EPS may not equal sum of quarters due to share count differences.

2005 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with

Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited
	2006												2006
(In millions, except per share amounts)	1Q			2Q			3Q			4Q			Dec YTD
Reported net income — GAAP	$	(27	)	$	72		$	(103	)	$	(32	)	$	(90	)
After-tax items:
Electric and gas utility other		—			—			—			—			—
Enterprises other		—			—			(29	)		25			(4	)
Corporate interest and other		2			(15	)		4			82			73
Discontinued operations (gain)		(1	)		(2	)		(1	)		(2	)		(6	)
Asset impairment charges		—			—			169			—			169
Adjusted earnings, including MTM	$	(26	)	$	55		$	40		$	73		$	142
Mark-to-market impacts		74			21			30			(13	)		112
Adjusted earnings, excluding MTM	$	48		$	76		$	70		$	60		$	254
Average shares outstanding, basic		219.1			219.6			220.1			220.6			219.9
Average shares outstanding, diluted		219.1			229.6			220.1			220.6			219.9
Reported earnings per share — GAAP	$	(0.12	)	$	0.31		$	(0.47	)	$	(0.15	)	$	(0.41	)
After-tax items
Electric and gas utility other		—			—			—			—			—
Enterprises other		—			—			(0.13	)		0.11			(0.02	)
Corporate other		0.01			(0.07	)		0.02			0.38			0.27
Discontinued operations		(0.01	)		(0.01	)		—			(0.01	)		(0.03	)
Asset impairment charges		—			—			0.76			—			0.76
Adjusted earnings per share, including MTM	$	(0.12	)	$	0.23		$	0.18		$	0.33		$	0.57
Mark-to-market impacts		0.34			0.10			0.13			(0.06	)		0.51
Adjusted earnings per share, excluding MTM	$	0.22		$	0.33		$	0.31		$	0.27		$	1.08

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

NM: Not Meaningful.

2006 A-1

CMS Energy Corporation
Earnings By Quarter and Year GAAP Reconciliation
(Unaudited)

	(In millions, except per share amounts)
	2007
	1Q			2Q			3Q			4Q			Dec YTD
Reported net income (loss) — GAAP	$	(215	)	$	33		$	82		$	(127	)	$	(227	)
After-tax items:
Electric and gas utility		4			—			—			—			4
Enterprises		49			19			(10	)		222			280
Corporate interest and other		(81	)		32			9			(38	)		(78	)
Discontinued operations (income) loss		178			(91	)		—			2			89
Asset impairment charges, net		157			25			(49	)		—			133
Adjusted income — non-GAAP	$	92		$	18		$	32		$	59		$	201
Average shares outstanding, basic		221.5			222.6			223.0			223.4			222.6
Average shares outstanding, diluted		221.5			222.6			241.3			223.4			222.6
Reported earnings (loss) per share — GAAP	$	(0.97	)	$	0.15		$	0.34		$	(0.57	)	$	(1.02	)
After-tax items:
Electric and gas utility		0.01			—			—			—			(0.07	)
Enterprises		0.23			0.08			(0.04	)		0.99			1.25
Corporate interest and other		(0.36	)		0.15			0.03			(0.17	)		(0.32	)
Discontinued operations (income) loss		0.80			(0.41	)		—			0.01			0.40
Asset impairment charges, net		0.71			0.11			(0.20	)		—			0.60
Adjusted earnings per share — non-GAAP	$	0.42		$	0.08		$	0.13		$	0.26		$	0.84

(In millions, except per share amounts)	2008
	1Q			2Q			3Q			4Q		Dec YTD
Reported net income — GAAP	$	102		$	44		$	78		$	60	$	284
After-tax items:
Electric and gas utility		—			1			6			5		12
Enterprises		*			(4	)		*			1		(3	)
Corporate interest and other		—			—			(6	)		1		(5	)
Discontinued operations (income) loss		(1	)		1			(1	)		*		(1	)
Adjusted income — non-GAAP	$	101		$	42		$	77		$	67	$	287
Average shares outstanding, basic		225.2			225.4			225.8			226.3		225.7
Average shares outstanding, diluted		237.6			240.6			236.3			228.1		236.2
Reported earnings per share — GAAP	$	0.43		$	0.18		$	0.33		$	0.26	$	1.20
After-tax items:
Electric and gas utility		—			0.01			0.02			0.03		0.05
Enterprises		*			(0.02	)		0.01			0.01		(0.02	)
Corporate interest and other		—			—			(0.03	)		*		(0.02	)
Discontinued operations (income) loss		(*	)		—			(0.01	)		*		(*	)
Adjusted earnings per share — non-GAAP (a)	$	0.43		$	0.17		$	0.32		$	0.30	$	1.21

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

*	Less than $500 thousand or $0.01 per share.
(a)	Excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock, adjusted earnings per share was $0.44, $0.19, $0.33, $0.30, and $1.25, respectively.

2008 A-1

CMS ENERGY CORPORATION
Earnings By Quarter and Year GAAP Reconciliation
(Unaudited)

(In millions, except per share amounts)	2009
	1Q		2Q			3Q		4Q			Dec YTD
Reported net income — GAAP	$	70	$	75		$	67	$	6		$	218
After-tax items:
Electric and gas utility		—		—			—		79			79
Enterprises		*		16			2		4			22
Corporate interest and other		*		1			1		(1	)		1
Discontinued operations (income) loss		1		(25	)		1		3			(20	)
Adjusted income — non-GAAP	$	71	$	67		$	71	$	91		$	300
Average shares outstanding, basic		226.6		226.9			227.3		227.8			227.2
Average shares outstanding, diluted		233.2		234.6			238.5		243.0			237.9
Reported earnings per share — GAAP	$	0.30	$	0.32		$	0.28	$	0.02		$	0.91
After-tax items:
Electric and gas utility		—		—			—		0.33			0.33
Enterprises		*		0.07			0.01		0.02			0.09
Corporate interest and other		*		*			*		(*	)		0.01
Discontinued operations (income) loss		0.01		(0.11	)		0.01		0.01			(0.08	)
Adjusted earnings per share — non-GAAP	$	0.31	$	0.28		$	0.30	$	0.38		$	1.26

(In millions, except per share amounts)	2010
	1Q		2Q			3Q
Reported net income — GAAP	$	85	$	80		$	134
After-tax items:
Electric and gas utility		6		—			—
Enterprises		1		(31	)		(2	)
Corporate interest and other		*		*			—
Discontinued operations loss		1		16			*
Adjusted income — non-GAAP	$	93	$	65		$	132
Average shares outstanding, basic		228.0		228.2			229.0
Average shares outstanding, diluted		246.5		247.6			254.7
Reported earnings per share — GAAP	$	0.34	$	0.32		$	0.53
After-tax items:
Electric and gas utility		0.03		—			—
Enterprises		*		(0.13	)		(0.01	)
Corporate interest and other		*		*			—
Discontinued operations loss		0.01		0.07			*
Adjusted earnings per share — non-GAAP	$	0.38	$	0.26		$	0.52

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

* Less than $500 thousand or $0.01 per share.

2010 A-1

CMS Energy Corporation
Earnings Segment Results GAAP Reconciliation
(Unaudited)

	Three Months Ended
September 30	2010			2009
Electric Utility
Reported	$	0.61		$	0.46
Downsizing Program		—			—
Adjusted	$	0.61		$	0.46
Gas Utility
Reported	$	0.01		$	(0.05	)
Downsizing Program		—			—
Adjusted	$	0.01		$	(0.05	)
Enterprises
Reported	$	0.04		$	0.02
Asset Sales (Gain) Loss and Other		(0.01	)		0.01
Adjusted	$	0.03		$	0.03
Corporate Interest and Other
Reported	$	(0.13	)	$	(0.14	)
Asset Sales Loss and Other		—			*
Adjusted	$	(0.13	)	$	(0.14	)
Discontinued Operations
Reported	$	(*	)	$	(0.01	)
Discontinued Operations Loss (Gain)		*			0.01
Adjusted	$	—		$	—
Totals
Reported	$	0.53		$	0.28
Discontinued Operations Loss (Gain)		*			0.01
Downsizing Program		—			—
Asset Sales (Gain) Loss and Other		(0.01	)		0.01
Adjusted	$	0.52		$	0.30
Average Common Shares Outstanding — Diluted (in millions)		254.7			238.5

2010 A-2

Consumers Energy
2010 Forecasted Cash Flow GAAP Reconciliation (in millions) (unaudited)

				Reclassifications From Sources and Uses to Statement of Cash Flows
Presentation Sources and Uses				Tax			Interest			Pension			Accts/Rec			Capital			Securitization			Preferred			Common			Consolidated Statements of Cash Flows
	non-GAAP			Sharing			Payments			Contribution			Financing			Lease Pymts			Debt Pymts			Dividends			Dividends			GAAP
Description	Amount			Operating			as Operating			as Operating			as Operating			as Financing			as Financing			as Financing			as Financing			Amount			Description
Cash at year end 2009	$	39		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	39		Cash at year end 2009
Sources
Operating	$	1,485		$	(130	)	$	(221	)	$	—		$	—		$	23		$	35		$	—		$	—		$	1,192
Other working capital		(30	)		—			—			(97	)		(50	)		—			—			—			—			(177	)	Net cash provided by operating activities
Sources	$	1,455		$	(130	)	$	(221	)	$	(97	)	$	(50	)	$	23		$	35		$	—		$	—		$	1,015
Uses
Interest and preferred dividends	$	(223	)	$	—		$	221		$	—		$	—		$	—		$	—		$	2		$	—		$	—
Pension Contribution		(97	)		—			—			97			—			—			—			—			—			—
Capital expenditures		(950	)		—			—			—			—			—			—			—			—			(950	)
Dividends/tax sharing to CMS		(490	)		130			—			—			—			—			—			—			360			—		Net cash provided by investing activities
Uses	$	(1,760	)	$	130		$	221		$	97		$	—		$	—		$	—		$	2		$	360		$	(950	)	Cash flow from operating and investing activities
Cash flow	$	(305	)	$	—		$	—		$	—		$	(50	)	$	23		$	35		$	2		$	360		$	65
Financing
Equity	$	250		$	—		$	—		$	—		$	—		$	—		$	—		$	(2	)	$	—		$	248
New Issues		600			—			—			—			—			—			—			—			—			600
Retirements		(446	)		—			—			—			—			(23	)		(35	)		—			(360	)		(864	)
Net short-term financing & other		(53	)		—			—			—			50			—			—			—			—			(3	)	Net cash provided by financing activities
Financing	$	351		$	—		$	—		$	—		$	50		$	(23	)	$	(35	)	$	(2	)	$	(360	)	$	(19	)
Net change in cash	$	46		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	46		Net change in cash
Cash at year end 2010	$	85		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	85		Cash at year end 2010

2010 A-3

CMS Energy Parent
2010 Forecasted Cash Flow GAAP Reconciliation (in millions) (unaudited)

				Reclassifications From Sources and Uses to Statement of Cash Flows
Presentation Sources and Uses				Interest			Overheads &			Other			Preferred			Cash From			Consolidated Statements of Cash Flows
	non-GAAP			Payments			Tax Payments			Uses (a)			Dividends			Consolidated			GAAP
Description	Amount			as Operating			as Operating			as Operating			as Financing			Companies			Amount			Description
Cash at year end 2009	$	23		$	—		$	—		$	—		$	—		$	28		$	51		Cash at year end 2009
Sources
Consumers Energy dividends/tax sharing	$	490		$	(122	)	$	(20	)	$	—		$	—		$	—		$	348
Enterprises		30																		30
Insurance settlement		50			—			—			(8	)		—			10			52		Net cash provided by operating activities
Sources	$	570		$	(122	)	$	(20	)	$	(8	)	$	—		$	10		$	430
Uses
Interest and preferred dividends	$	(130	)	$	122		$	—		$	—		$	8		$	—		$	—
Overhead and Federal tax payments		(20	)		—			20			—			—			—			—
Pension Contributions		(3	)		—			—			—			—			—			(3	)
Equity infusions		(250	)		—			—			8			—			(85	)		(327	)	Net cash provided by investing activities
Uses (a)	$	(415	)	$	122		$	20		$	8		$	8		$	(85	)	$	(342	)
Cash flow	$	155		$	—		$	—		$	—		$	8		$	(75	)	$	88		Cash flow from operating and investing activities
Financing and dividends
New Issues	$	550		$	—		$	—		$	—		$	(8	)	$	105		$	647
Retirements		(314	)		—			—			—			—			(40	)		(354	)
Net short-term financing & other		(23	)		—			—			—			—			—			(23	)
Common dividend		(151	)		—			—			—			—			—			(151	)	Net cash provided by financing activities
Financing	$	62		$	—		$	—		$	—		$	(8	)	$	65		$	119
Net change in cash	$	217		$	—		$	—		$	—		$	—		$	(10	)	$	207		Net change in cash
Cash at year end 2010	$	240		$	—		$	—		$	—		$	—		$	18		$	258		Cash at year end 2010

(a) Includes other and roundings

2010 A-4

Consolidated CMS Energy
2010 Forecasted Consolidation of Consumers Energy and CMS Energy Parent Statements of Cash Flow (in millions) (unaudited)

							Eliminations/Reclassifications to Arrive at the
							Consolidated Statement of Cash Flows
Statements of Cash Flows							Consumers			Equity
	Consumers			CMS Parent			Common Dividend			Infusions to			Consolidated Statements of Cash Flows
Description	Amount			Amount			as Financing			Consumers			Amount			Description
Cash at year end 2009	$	39		$	51		$	—		$	—		$	90		Cash at year end 2009
Net cash provided by operating activities	$	1,015		$	430		$	(360	)	$	—		$	1,085		Net cash provided by operating activities
Net cash provided by investing activities		(950	)		(342	)		—			250			(1,042	)	Net cash provided by investing activities
Cash flow from operating and investing activities	$	65		$	88		$	(360	)	$	250		$	43		Cash flow from operating and investing activities
Net cash provided by financing activities	$	(19	)	$	119		$	360		$	(250	)	$	210		Net cash provided by financing activities
Net change in cash	$	46		$	207		$	—		$	—		$	253		Net change in cash
Cash at year end 2010	$	85		$	258		$	—		$	—		$	343		Cash at year end 2010

2010 A-5

CMS Energy
Reconciliation of 2010 Operating Cash Flow Target to GAAP Operating Activities
(unaudited)

	Amount
	(mils)
Consumers Operating (Consumers PTOI + Depreciation)	$	1,485
Enterprises (Project Cash Flows)		30
Operating Cash Flow	$	1,515		non-GAAP
Other operating activies including taxes, interest payments and working capital		(430	)
Net cash provided by operating activites	$	1,085		GAAP

2010 A-6

EX-99.3

Exhibit 99.3

J. P. Morgan SMid Cap Conference December 3, 2010 Thomas J. Webb Executive Vice President and CFO Growing Forward

1 This presentation contains "forward-looking statements" as defined in Rule 3b-6 of the Securities Exchange Act of 1934, as amended, Rule 175 of the Securities Act of 1933, as amended, and relevant legal decisions. The forward-looking statements are subject to risks and uncertainties. They should be read in conjunction with "FORWARD-LOOKING STATEMENTS AND INFORMATION" and "RISK FACTORS" sections of CMS Energy's and Consumers Energy's Form 10-K for the year ended December 31 and as updated in subsequent 10-Qs. CMS Energy's and Consumers Energy's "FORWARD-LOOKING STATEMENTS AND INFORMATION" and "RISK FACTORS" sections are incorporated herein by reference and discuss important factors that could cause CMS Energy's and Consumers Energy's results to differ materially from those anticipated in such statements. The presentation also includes non-GAAP measures when describing CMS Energy's results of operations and financial performance. A reconciliation of each of these measures to the most directly comparable GAAP measure is included in the appendix and posted on our website at www.cmsenergy.com. CMS Energy expects 2010 reported earnings to be about the same as adjusted earnings. Reported earnings could vary because of several factors. CMS Energy is not providing reported earnings guidance reconciliation because of the uncertainties associated with those factors.

Consumers Energy Fourth largest combination utility in the United States 1.8 million electric and 1.7 million gas customers 9,500 MW of owned and purchased generation capacity Renewable energy 5% of present supply 307 Bcf of gas storage capacity Ludington Pumped Storage B C Cobb J H Campbell D E Karn J C Weadock Mio Alcona Cooke Foote Loud 5 Channels Hodenpyl Tippy Rogers Hardy Croton Webber Allegan Electric Gas Combination Overview Territory Investment growth balances responsible rate increases with attractive earnings growth. Zeeland 2

3 Business Strategy Consistent financial performance Fair and timely regulation Utility investment Customer value Safe, excellent operations Consistent financial performance

Key Takeaways Adjusted EPS (non-GAAP) growth (5% - 7%) Investment (not sales) driven Predictable No need for new equity next five years Risk mitigation through regulatory framework File and implement ratemaking reduces regulatory lag Sales decoupling mitigates revenue volatility Commodity cost recovery mechanism reduces price risk Competitive dividend (5% yield) Projected total shareowner return (10% - 12%) 4

Retirements Some 2010 Highlights . . . . 5 .. . . . while Michigan economy is improving. New Issues Orders

Electric Sales Trend (weather adjusted) . . . . .. . . . improving faster than we expected. Electric Sales Year-to-Year Comparison 0 7% decline 1979 to 1982 6% decline 2007 to 2009 Forecast 6% 6

Michigan Energy Legislation . . . . Self-implement rates six months after filing; final decision within 12 months Customer charge in place for renewable energy and energy optimization plans Sales decoupling Cap on customer choice - 10% of load Natural gas and power supply costs pass through to customers .. . . . provides constructive regulatory framework. 7 Working ? ? ? ? ?

Capital Investment . . . . 2010 2011 2012 2013 2014 2015 Average Rate Base (bils) $10.2 $10.8 $11.6 $12.5 $13.4 0 Rate Base Bils $ Present Rate Base 5%-7% Reliability/Deliverability Renewables Smart Grid Environmental Maintenance Depreciation .. . . . provides earnings growth. Utility Investment $6.4 Billion 2011-2015 8

Renewable Energy Plans . . . . Michigan energy law requires: 10% renewables by 2015 Purchase 50% and build 50% Plan to invest $600 million over next five years, primarily on wind power Lake Winds Energy Park - 100 MW operational in 2012 Cross Winds Energy Park - 150 MW operational in 2014 .. . . increase renewables from 5% to 8% in 2012; and 10% by 2015. ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ ^ Existing Renewable Facilities Proposed Company-owned Wind Facilities New Power Purchase Agreement Contracts ^ Cross Winds Energy Park Lake Winds Energy Park 9

Environmental Expenditures . . . . .. . . . are recovered in customer rates. Pollution Control Equipment Baghouse Dry Scrubber Activated Carbon SCR Boiler Burners $1.5 billion investment 2011-2015 Clean Air Act Clean Water Act Other state and federal regulations Expenditures for environmental equipment for: NOx reduction SO2 reduction Mercury reduction 10

11 Operating Cash Flow Growth . . . . .. . . . driven by investment growth. 2008 2009 2010 2011 2012 2013 2014 2015 CF after Capex -598 39 -22 20 -76 -31 -326 -144 73 160 220 325 479 384 497 271 CF after dividends 756 726 790 676 814 898 1032 987 CF after working capital 81 113 137 166 184 210 230 250 CF after interest 698 44 138 165 82 141 278 452 Operating cash flow 335 362 355 379 400 417 456 505 Amount (bils) $ Operating cash flow a up $0.1 billion per year $1.9 Interest Working capital and taxes Base Investment $1.3 $1.6 $1.7 $1.8 $1.5 $2.0 Cash flow before dividend Investment choices _ _ _ _ _ a Non-GAAP

Mitigating EPS Volatility . . . . .. . . . through decoupling, and strong performance. Old Opportunities Old Risks Decouple Decouple Cost Performance Reinvest 12

Earnings Per Share (adjusted non-GAAP) . . . . 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 History 0.81 0.9 0.96 1.08 0.84 1.21 1.26 2009 Plan 1.35 1.43 1.5 1.58 1.68 1.77 5% - 7% (2010-15) .. . . . growth track record continues to support 10% - 12% TSR growth. 2003 - 2009 8% Growth Dividend Annual ¢/share _ _ _ _ _ a $1.25 excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock b Pre increase b 13 Uniqueness Investment (vs sales) driven Investment pull (vs push) NOLs no equity need (or dilution) Risk mitigation strong Energy law Solid regulation Cost discipline Customer driven

Earnings Per Share (adjusted non-GAAP) . . . . 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 History 0.81 0.9 0.96 1.08 0.84 1.21 1.26 2009 Plan 1.35 1.43 1.5 1.58 1.68 1.77 5% - 7% (2010-15) .. . . . growth track record continues to support 10% - 12% TSR growth. 2003 - 2009 8% Growth Dividend Annual ¢/share _ _ _ _ _ a $1.25 excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock b Pre increase b 14 Uniqueness Investment (vs sales) driven Investment pull (vs push) NOLs no equity need (or dilution) Risk mitigation strong Energy law Solid regulation Cost discipline Customer driven

Appendix

"Cushion" Regulatory Timeline . . . . .. . . . well into second year under new, comprehensive Michigan energy law. .. . . . well into second year under new, comprehensive Michigan energy law. Appendix 1

FINAL ELECTRIC RATE CASE U-16191*

On November 4, 2010, the Michigan Public Service Commission (MPSC) authorized Consumers Energy to increase its base electric rates by $146 million annually with an authorized ROE of 10.7%. The Order approved guidelines for cost recovery of Smart Grid expenditures, required the pre-1983 Department of Energy liability funds to be placed into an external trust within six months, made no changes to the current electric revenue decoupling mechanism, and terminated the uncollectibles expense tracker as of Nov. 30^th, and the forestry tracker immediately. In July, the Company self implemented a $150 million annual rate increase. As a result of the final order, the $4 million reduction from the annual self implemented rates will be refunded to customers in early 2011 after final refund amounts are determined and authorized by Commission order. Overall, customer rates will increase 4.2% versus rates set in the last electric case (U-15645).

					MPSC
	Consumers		MPSC		Final
	Self		Final		Order
	Implemented		Order		B/(W)
Item	(Mils)		(Mils)		(Mils)			Remarks
1. O&M	$	21	$	25	$	4		Final order O&M level greater than amount self-implemented: $4
2. Gross Margin		5		19		14		Recovery of Rate E-1 economic development discount on higher sales: $11 Misc. revenue: $3
3. Investment		106		102		(4	)	Net plant: $(6) Working capital: $(6) Taxes: $2 AFUDC: $6
4. Cost of Capital		18		0		(18	)	Lower return on equity of 10.7% vs. 11%: $(12) Cost rates & capital structure: $(6)
Total	$	150	$	146	$	(4	)

				Consumers
Ratemaking	Existing			Self			MPSC
Capital Structure %	(U-15645)			Implemented			Final Order
Long Term Debt		44.80	%		41.77	%		40.62	%
Short Term Debt		0.78			1.51			1.51
Preferred Stock		0.48			0.44			0.44
Common Equity		40.51	(1)		41.49	(2)		41.59	(3)
Deferred FIT		12.80			14.26			15.30
JDITC/Other		0.63			0.53			0.54
		100.00	%		100.00	%		100.00	%

				Consumers
Rate Base and Return	Existing			Self			MPSC
Percentage	(U-15645)			Implemented			Final Order
Rate Base — Jurisdictional ($ billions)	$	6.16		$	6.97		$	6.87
Return on Rate Base		6.98	%		7.16	%		6.98	%
Return on Equity		10.70	%		11.00	%		10.70	%

(1)	Equivalent to 47.23% on a financial basis
(2)	Equivalent to 49.57% on a financial basis
(3)	Equivalent to 50.32% on a financial basis

*Electric Rate Case U-16191 can be accessed at the Michigan Public Service Commission’s website.
http://efile.mpsc.cis.state.mi.us/efile/electric.html

Appendix 2

GAS RATE CASE U-16418*

On August 13, 2010, Consumers Energy filed an application with the Michigan Public Service Commission seeking an increase in its gas delivery and transportation rates based on a 2011 test year. The Company requests an authorized ROE of 11%, and proposes a full decoupling mechanism, including weather. If approved, this request would add about $2.95 per month, or about 3.4%, to the typical residential customer’s average monthly bill. The $55 million revenue deficiency is detailed below.

Item	$ Millions		Explanation
1. O&M	$	16	Gas operations expense: $13 Lost & unaccounted for and company use gas: $3
2. Margin 4			Miscellaneous revenues
3. Investment 3		0	Net plant:$19 Working capital: $(2) Depreciation and property taxes: $10 Taxes, AFUDC and other: $3
4. Cost of Capital		5	Return on equity: $8 (11.00% vs 10.55%) Capital structure and lower debt costs: $(3)
Total	$	55

Ratemaking	Existing			As Filed						After-Tax
Capital Structure	(U-15986)			Percent of Total			Annual Cost			Weighted Costs
Long Term Debt		43.58	%		41.86	%		5.95	%		2.49	%
Short Term Debt		0.59			1.82			3.46			0.06
Preferred Stock		0.46			0.42			4.46			0.02
Common Equity		40.78			40.51	(1)		11.00			4.46
Deferred Taxes		13.30			14.33			0.00			0.00
JDITC/Other		1.29			1.06			6.67			0.07
		100.00	%		100.00	%					7.10	%

	Existing
Rate Base and Return Percentage	(U-15986)			As Filed
Rate Base ($ billions)	$	2.74		$	2.90
Return on Rate Base		7.02	%		7.10	%
Return on Equity		10.55	%		11.00	%

⁽¹⁾ Equivalent to 48.93% on financial basis.

GAS RATE CASE SCHEDULE

Consumers files PA 286 self-implementation rates	January 6, 2011
Staff and Intervenors file direct cases	January 24, 2011
Staff/Intervenor filings on self-implementation	January 26, 2011
Self-Implementation Hearing	January 27, 2011
Rebuttal Testimony and exhibits	February 10, 2011
Motions to Strike Testimony	February 17, 2011
Cross of all witnesses	February 23 through March 4, 2011
Initial Briefs	March 30, 2011
Reply Briefs	April 19, 2011
Proposal for Decision target date	June 2, 2011
Exceptions	June 17, 2011
Replies to Exceptions	June 27, 2011
Commission Order	Not later than August 12, 2011

*Gas Rate Case U-16418 can be accessed at the Michigan Public Service Commission’s website.
http://efile.mpsc.cis.state.mi.us/efile/gas.html

Appendix 3

Utility Risk Mitigation . . . . Appendix 4 $6.1 Billion a Sales $5.5 Billion a Cost _ _ _ _ _ a Estimated 2010 .. . . . enhanced with decoupling.

Michigan Public Service Commission (MPSC) Composed of three members appointed by the Governor with the advice and consent of the Senate Appointed to serve staggered six-year terms No more than two Commissioners may represent the same political party One Commissioner is designated as Chairman by the Governor Orjiakor Isiogu, Chairman Appointed: 9/9/07 Term Ends: 7/2/13 Democrat Monica Martinez, Commissioner Appointed: 7/3/05 Term Ends: 7/2/11 Democrat Greg White, Commissioner Appointed: 12/4/09 Term Ends: 7/2/15 Independent Appendix 5

Electric Sales Trend (weather adjusted) . . . . Industrial Sales .. . . . continues to improve in our service territory, led by industrial customers. Total 2009 2010 2011 Year over Year Comparison by Quarter 2009 2010 2011 Forecast 10% 1.5% Forecast Appendix 6

Economic Indicators - U.S. Autos . . . . .. . . . production up substantially from 2009. U.S. Production (October 9 YTD) Days Supply (September) +46% Desired Supply Desired Supply 90 60 Appendix 7

Emission Reductions . . . . Appendix 8 .. . . . reduced NOx 74% and SO2 67%.

Federal Tax Benefits Year-End Estimate 2010 2011 2012 2013 2014 (bils) (bils) (bils) (bils) (bils) Gross NOL carry forwards $ 1.2 $ 0.7 $ 0.2 $ - $ - Net NOL cash benefit at 35% 0.4 0.2 0.1 - - Credit carry forwards 0.3 0.3 0.3 0.2 0.1 Remaining cash benefit $ 0.7 $ 0.5 $ 0.4 $ 0.2 $ 0.1 Appendix 9

2010 Financing Activities 2010 Financing Activities Appendix 10 $300 300

Share Dilution Sensitivity . . . . Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Convertible Notes Convertible Notes Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Share Dilution Exposed to Stock Price Changes After Preferred/Debt Conversion Before Conversion Before Conversion 2011 Average Annual Stock Price 2.88% (mils) 5.50% (mils) Total (mils) (2011 dilution over 2010) 3.375% Notes (mils) 4.5% Preferred (mils) 2011 Average Annual Stock Price 2.88% (mils) 5.50% (mils) Total (mils) (2011 dilution over 2010) 3.375% Notes (mils) 4.5% Preferred (mils) $16 4 1 5 1% 6 12 18 6 2 8 2 7 13 20 8 3 11 3 7 14 22 9 4 13 4 8 15 24 10 5 15 5 8 16 Outstanding (mils) $288 $173 Conversion price a 13.087 14.463 Trigger Price 15.70 18.80 Appendix 11 .. . . . reduced from calling convertible preferreds and 3.375% convertible notes. _ _ _ _ _ a As of December 2010; will be adjusted for future dividend payments.

Consumers Capital Expenditures Appendix 12

GAAP Reconciliation

CMS Energy
Earnings Reconciliation By Quarter and Year
December 31
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited Quarters
(millions, except per share amounts)	1Q03			2Q03			3Q03			4Q03			FY 2003
Reported net income	$	82		$	(65	)	$	(69	)	$	8		$	(44	)
After-tax items:
Electric and gas utility other											30			30
Enterprises other		5			7			62			37			111
Corporate other		1						19			4			24
Discontinued operations		(31	)		53			(2	)		(43	)		(23	)
Cumulative accounting changes		24												24
Ongoing earnings (non-GAAP)	$	81		$	(5	)	$	10		$	36		$	122
Average shares outstanding, basic		144.1			144.1			152.2			161.1			150.4
Average shares outstanding, diluted		165.0			144.1			152.2			161.1			150.4
Reported earnings per share	$	0.52		$	(0.45	)	$	(0.46	)	$	0.05		$	(0.30	)
After-tax items
Electric and gas utility other											0.19			0.21
Enterprises other		0.03			0.05			0.41			0.23			0.74
Corporate other								0.12			0.02			0.16
Discontinued operations		(0.19	)		0.37			(0.01	)		(0.27	)		(0.16	)
Cumulative accounting changes		0.14												0.16
Ongoing earnings per share (non-GAAP)	$	0.50		$	(0.03	)	$	0.06		$	0.22		$	0.81

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

2003 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited												31-Dec
(millions, except per share amounts)	1Q04*			2Q04			3Q04			4Q04			FY 2004
Reported net income — GAAP	$	(9	)	$	16		$	56		$	47		$	110
After-tax items:
Electric and gas utility other											(67	)		(67	)
Enterprises other		88						(29	)		48			107
Corporate other		(7	)					(1	)		1			(7	)
Discontinued operations		2						(8	)		10			4
Cumulative accounting changes		2												2
Adjusted earnings, including M-T-M	$	76		$	16		$	18		$	39		$	149
Mark-to-market impacts	NM				(13	)		9			9			5
Adjusted earnings, excluding M-T-M	$	76		$	3		$	27		$	48		$	154
Average shares outstanding, basic		161.1			161.2			161.5			190.2			168.6
Average shares outstanding, diluted		161.1			164.2			165.0			194.0			172.1
Reported earnings per share — GAAP	$	(0.06	)	$	0.10		$	0.34		$	0.24		$	0.64
After-tax items
Electric and gas utility other											(0.35	)		(0.39	)
Enterprises other		0.56						(0.17	)		0.25			0.62
Corporate other		(0.05	)					(0.01	)		0.01			(0.03	)
Discontinued operations		0.01						(0.05	)		0.05			0.02
Cumulative accounting changes		0.01												0.01
Adjusted earnings per share, including M-T-M	$	0.47		$	0.10		$	0.11		$	0.20		$	0.87
Mark-to-market impacts	NM				(0.08	)		0.06			0.05			0.03
Adjusted earnings per share, excluding M-T-M	$	0.47		$	0.02		$	0.17		$	0.25		$	0.90

Note: Year-to-date & full-year EPS may not equal sum of quarters due to share count differences.

* Quarterly amounts differ from amounts previously reported due to accelerating the measurement date on our benefit plans by one month and the remeasurement of our post retirement obligation.

NM: Not meaningful.

2004 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with
Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited												31-Dec
(millions, except per share amounts)	1Q05			2Q05			3Q05			4Q05			FY 2005
Reported net income — GAAP	$	150		$	27		$	(265	)	$	(6	)	$	(94	)
After-tax items:
Electric and gas utility other
Enterprises other		(2	)		(1	)		(1	)		13			9
Corporate other					1						8			9
Discontinued operations											(14	)		(14	)
Asset impairment								385						385
Adjusted earnings, including M-T-M	$	148		$	27		$	119		$	1		$	295
Mark-to-market impacts		(75	)		19			(75	)		40			(91	)
Adjusted earnings, excluding M-T-M	$	73		$	46		$	44		$	41		$	204
Average shares outstanding, basic		195.3			217.9			219.6			218.5			211.8
Average shares outstanding, diluted		206.3			228.9			219.6			218.5			211.8
Reported earnings per share — GAAP	$	0.74		$	0.12		$	(1.21	)	$	(0.03	)	$	(0.44	)
After-tax items
Electric and gas utility other
Enterprises other		(0.01	)	NM			NM				0.06			0.04
Corporate other				NM							0.03			0.04
Discontinued operations											(0.06	)		(0.07	)
Asset impairment								1.75						1.82
Adjusted earnings per share, including M-T-M	$	0.73		$	0.12		$	0.54		$	0.00		$	1.39
Mark-to-market impacts		(0.36	)		0.08			(0.34	)		0.19			(0.43	)
Adjusted earnings per share, excluding M-T-M	$	0.37		$	0.20		$	0.20		$	0.19		$	0.96

Note: Year-to-date & full-year EPS may not equal sum of quarters due to share count differences.

2005 A-1

CMS Energy
Earnings Reconciliation By Quarter and Year
Reconciliation of reported measures prepared in accordance with

Generally Accepted Accounting Principles (GAAP) versus non-GAAP measures

	Unaudited
	2006												2006
(In millions, except per share amounts)	1Q			2Q			3Q			4Q			Dec YTD
Reported net income — GAAP	$	(27	)	$	72		$	(103	)	$	(32	)	$	(90	)
After-tax items:
Electric and gas utility other		—			—			—			—			—
Enterprises other		—			—			(29	)		25			(4	)
Corporate interest and other		2			(15	)		4			82			73
Discontinued operations (gain)		(1	)		(2	)		(1	)		(2	)		(6	)
Asset impairment charges		—			—			169			—			169
Adjusted earnings, including MTM	$	(26	)	$	55		$	40		$	73		$	142
Mark-to-market impacts		74			21			30			(13	)		112
Adjusted earnings, excluding MTM	$	48		$	76		$	70		$	60		$	254
Average shares outstanding, basic		219.1			219.6			220.1			220.6			219.9
Average shares outstanding, diluted		219.1			229.6			220.1			220.6			219.9
Reported earnings per share — GAAP	$	(0.12	)	$	0.31		$	(0.47	)	$	(0.15	)	$	(0.41	)
After-tax items
Electric and gas utility other		—			—			—			—			—
Enterprises other		—			—			(0.13	)		0.11			(0.02	)
Corporate other		0.01			(0.07	)		0.02			0.38			0.27
Discontinued operations		(0.01	)		(0.01	)		—			(0.01	)		(0.03	)
Asset impairment charges		—			—			0.76			—			0.76
Adjusted earnings per share, including MTM	$	(0.12	)	$	0.23		$	0.18		$	0.33		$	0.57
Mark-to-market impacts		0.34			0.10			0.13			(0.06	)		0.51
Adjusted earnings per share, excluding MTM	$	0.22		$	0.33		$	0.31		$	0.27		$	1.08

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

NM: Not Meaningful.

2006 A-1

CMS Energy Corporation
Earnings By Quarter and Year GAAP Reconciliation
(Unaudited)

	(In millions, except per share amounts)
	2007
	1Q			2Q			3Q			4Q			Dec YTD
Reported net income (loss) — GAAP	$	(215	)	$	33		$	82		$	(127	)	$	(227	)
After-tax items:
Electric and gas utility		4			—			—			—			4
Enterprises		49			19			(10	)		222			280
Corporate interest and other		(81	)		32			9			(38	)		(78	)
Discontinued operations (income) loss		178			(91	)		—			2			89
Asset impairment charges, net		157			25			(49	)		—			133
Adjusted income — non-GAAP	$	92		$	18		$	32		$	59		$	201
Average shares outstanding, basic		221.5			222.6			223.0			223.4			222.6
Average shares outstanding, diluted		221.5			222.6			241.3			223.4			222.6
Reported earnings (loss) per share — GAAP	$	(0.97	)	$	0.15		$	0.34		$	(0.57	)	$	(1.02	)
After-tax items:
Electric and gas utility		0.01			—			—			—			(0.07	)
Enterprises		0.23			0.08			(0.04	)		0.99			1.25
Corporate interest and other		(0.36	)		0.15			0.03			(0.17	)		(0.32	)
Discontinued operations (income) loss		0.80			(0.41	)		—			0.01			0.40
Asset impairment charges, net		0.71			0.11			(0.20	)		—			0.60
Adjusted earnings per share — non-GAAP	$	0.42		$	0.08		$	0.13		$	0.26		$	0.84

(In millions, except per share amounts)	2008
	1Q			2Q			3Q			4Q		Dec YTD
Reported net income — GAAP	$	102		$	44		$	78		$	60	$	284
After-tax items:
Electric and gas utility		—			1			6			5		12
Enterprises		*			(4	)		*			1		(3	)
Corporate interest and other		—			—			(6	)		1		(5	)
Discontinued operations (income) loss		(1	)		1			(1	)		*		(1	)
Adjusted income — non-GAAP	$	101		$	42		$	77		$	67	$	287
Average shares outstanding, basic		225.2			225.4			225.8			226.3		225.7
Average shares outstanding, diluted		237.6			240.6			236.3			228.1		236.2
Reported earnings per share — GAAP	$	0.43		$	0.18		$	0.33		$	0.26	$	1.20
After-tax items:
Electric and gas utility		—			0.01			0.02			0.03		0.05
Enterprises		*			(0.02	)		0.01			0.01		(0.02	)
Corporate interest and other		—			—			(0.03	)		*		(0.02	)
Discontinued operations (income) loss		(*	)		—			(0.01	)		*		(*	)
Adjusted earnings per share — non-GAAP (a)	$	0.43		$	0.17		$	0.32		$	0.30	$	1.21

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

*	Less than $500 thousand or $0.01 per share.
(a)	Excluding discontinued Exeter operations and accounting changes related to convertible debt and restricted stock, adjusted earnings per share was $0.44, $0.19, $0.33, $0.30, and $1.25, respectively.

2008 A-1

CMS ENERGY CORPORATION
Earnings By Quarter and Year GAAP Reconciliation
(Unaudited)

(In millions, except per share amounts)	2009
	1Q		2Q			3Q		4Q			Dec YTD
Reported net income — GAAP	$	70	$	75		$	67	$	6		$	218
After-tax items:
Electric and gas utility		—		—			—		79			79
Enterprises		*		16			2		4			22
Corporate interest and other		*		1			1		(1	)		1
Discontinued operations (income) loss		1		(25	)		1		3			(20	)
Adjusted income — non-GAAP	$	71	$	67		$	71	$	91		$	300
Average shares outstanding, basic		226.6		226.9			227.3		227.8			227.2
Average shares outstanding, diluted		233.2		234.6			238.5		243.0			237.9
Reported earnings per share — GAAP	$	0.30	$	0.32		$	0.28	$	0.02		$	0.91
After-tax items:
Electric and gas utility		—		—			—		0.33			0.33
Enterprises		*		0.07			0.01		0.02			0.09
Corporate interest and other		*		*			*		(*	)		0.01
Discontinued operations (income) loss		0.01		(0.11	)		0.01		0.01			(0.08	)
Adjusted earnings per share — non-GAAP	$	0.31	$	0.28		$	0.30	$	0.38		$	1.26

(In millions, except per share amounts)	2010
	1Q		2Q			3Q
Reported net income — GAAP	$	85	$	80		$	134
After-tax items:
Electric and gas utility		6		—			—
Enterprises		1		(31	)		(2	)
Corporate interest and other		*		*			—
Discontinued operations loss		1		16			*
Adjusted income — non-GAAP	$	93	$	65		$	132
Average shares outstanding, basic		228.0		228.2			229.0
Average shares outstanding, diluted		246.5		247.6			254.7
Reported earnings per share — GAAP	$	0.34	$	0.32		$	0.53
After-tax items:
Electric and gas utility		0.03		—			—
Enterprises		*		(0.13	)		(0.01	)
Corporate interest and other		*		*			—
Discontinued operations loss		0.01		0.07			*
Adjusted earnings per share — non-GAAP	$	0.38	$	0.26		$	0.52

Note: Year-to-date (YTD) EPS may not equal sum of quarters due to share count differences.

* Less than $500 thousand or $0.01 per share.

2010 A-1

CMS Energy Corporation
Earnings Segment Results GAAP Reconciliation
(Unaudited)

	Three Months Ended
September 30	2010			2009
Electric Utility
Reported	$	0.61		$	0.46
Downsizing Program		—			—
Adjusted	$	0.61		$	0.46
Gas Utility
Reported	$	0.01		$	(0.05	)
Downsizing Program		—			—
Adjusted	$	0.01		$	(0.05	)
Enterprises
Reported	$	0.04		$	0.02
Asset Sales (Gain) Loss and Other		(0.01	)		0.01
Adjusted	$	0.03		$	0.03
Corporate Interest and Other
Reported	$	(0.13	)	$	(0.14	)
Asset Sales Loss and Other		—			*
Adjusted	$	(0.13	)	$	(0.14	)
Discontinued Operations
Reported	$	(*	)	$	(0.01	)
Discontinued Operations Loss (Gain)		*			0.01
Adjusted	$	—		$	—
Totals
Reported	$	0.53		$	0.28
Discontinued Operations Loss (Gain)		*			0.01
Downsizing Program		—			—
Asset Sales (Gain) Loss and Other		(0.01	)		0.01
Adjusted	$	0.52		$	0.30
Average Common Shares Outstanding — Diluted (in millions)		254.7			238.5

2010 A-2

Consumers Energy
2010 Forecasted Cash Flow GAAP Reconciliation (in millions) (unaudited)

				Reclassifications From Sources and Uses to Statement of Cash Flows
Presentation Sources and Uses				Tax			Interest			Pension			Accts/Rec			Capital			Securitization			Preferred			Common			Consolidated Statements of Cash Flows
	non-GAAP			Sharing			Payments			Contribution			Financing			Lease Pymts			Debt Pymts			Dividends			Dividends			GAAP
Description	Amount			Operating			as Operating			as Operating			as Operating			as Financing			as Financing			as Financing			as Financing			Amount			Description
Cash at year end 2009	$	39		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	39		Cash at year end 2009
Sources
Operating	$	1,485		$	(130	)	$	(221	)	$	—		$	—		$	23		$	35		$	—		$	—		$	1,192
Other working capital		(30	)		—			—			(97	)		(50	)		—			—			—			—			(177	)	Net cash provided by operating activities
Sources	$	1,455		$	(130	)	$	(221	)	$	(97	)	$	(50	)	$	23		$	35		$	—		$	—		$	1,015
Uses
Interest and preferred dividends	$	(223	)	$	—		$	221		$	—		$	—		$	—		$	—		$	2		$	—		$	—
Pension Contribution		(97	)		—			—			97			—			—			—			—			—			—
Capital expenditures		(950	)		—			—			—			—			—			—			—			—			(950	)
Dividends/tax sharing to CMS		(490	)		130			—			—			—			—			—			—			360			—		Net cash provided by investing activities
Uses	$	(1,760	)	$	130		$	221		$	97		$	—		$	—		$	—		$	2		$	360		$	(950	)	Cash flow from operating and investing activities
Cash flow	$	(305	)	$	—		$	—		$	—		$	(50	)	$	23		$	35		$	2		$	360		$	65
Financing
Equity	$	250		$	—		$	—		$	—		$	—		$	—		$	—		$	(2	)	$	—		$	248
New Issues		600			—			—			—			—			—			—			—			—			600
Retirements		(446	)		—			—			—			—			(23	)		(35	)		—			(360	)		(864	)
Net short-term financing & other		(53	)		—			—			—			50			—			—			—			—			(3	)	Net cash provided by financing activities
Financing	$	351		$	—		$	—		$	—		$	50		$	(23	)	$	(35	)	$	(2	)	$	(360	)	$	(19	)
Net change in cash	$	46		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	46		Net change in cash
Cash at year end 2010	$	85		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	—		$	85		Cash at year end 2010

2010 A-3

CMS Energy Parent
2010 Forecasted Cash Flow GAAP Reconciliation (in millions) (unaudited)

				Reclassifications From Sources and Uses to Statement of Cash Flows
Presentation Sources and Uses				Interest			Overheads &			Other			Preferred			Cash From			Consolidated Statements of Cash Flows
	non-GAAP			Payments			Tax Payments			Uses (a)			Dividends			Consolidated			GAAP
Description	Amount			as Operating			as Operating			as Operating			as Financing			Companies			Amount			Description
Cash at year end 2009	$	23		$	—		$	—		$	—		$	—		$	28		$	51		Cash at year end 2009
Sources
Consumers Energy dividends/tax sharing	$	490		$	(122	)	$	(20	)	$	—		$	—		$	—		$	348
Enterprises		30																		30
Insurance settlement		50			—			—			(8	)		—			10			52		Net cash provided by operating activities
Sources	$	570		$	(122	)	$	(20	)	$	(8	)	$	—		$	10		$	430
Uses
Interest and preferred dividends	$	(130	)	$	122		$	—		$	—		$	8		$	—		$	—
Overhead and Federal tax payments		(20	)		—			20			—			—			—			—
Pension Contributions		(3	)		—			—			—			—			—			(3	)
Equity infusions		(250	)		—			—			8			—			(85	)		(327	)	Net cash provided by investing activities
Uses (a)	$	(415	)	$	122		$	20		$	8		$	8		$	(85	)	$	(342	)
Cash flow	$	155		$	—		$	—		$	—		$	8		$	(75	)	$	88		Cash flow from operating and investing activities
Financing and dividends
New Issues	$	550		$	—		$	—		$	—		$	(8	)	$	105		$	647
Retirements		(314	)		—			—			—			—			(40	)		(354	)
Net short-term financing & other		(23	)		—			—			—			—			—			(23	)
Common dividend		(151	)		—			—			—			—			—			(151	)	Net cash provided by financing activities
Financing	$	62		$	—		$	—		$	—		$	(8	)	$	65		$	119
Net change in cash	$	217		$	—		$	—		$	—		$	—		$	(10	)	$	207		Net change in cash
Cash at year end 2010	$	240		$	—		$	—		$	—		$	—		$	18		$	258		Cash at year end 2010

(a) Includes other and roundings

2010 A-4

Consolidated CMS Energy
2010 Forecasted Consolidation of Consumers Energy and CMS Energy Parent Statements of Cash Flow (in millions) (unaudited)

							Eliminations/Reclassifications to Arrive at the
							Consolidated Statement of Cash Flows
Statements of Cash Flows							Consumers			Equity
	Consumers			CMS Parent			Common Dividend			Infusions to			Consolidated Statements of Cash Flows
Description	Amount			Amount			as Financing			Consumers			Amount			Description
Cash at year end 2009	$	39		$	51		$	—		$	—		$	90		Cash at year end 2009
Net cash provided by operating activities	$	1,015		$	430		$	(360	)	$	—		$	1,085		Net cash provided by operating activities
Net cash provided by investing activities		(950	)		(342	)		—			250			(1,042	)	Net cash provided by investing activities
Cash flow from operating and investing activities	$	65		$	88		$	(360	)	$	250		$	43		Cash flow from operating and investing activities
Net cash provided by financing activities	$	(19	)	$	119		$	360		$	(250	)	$	210		Net cash provided by financing activities
Net change in cash	$	46		$	207		$	—		$	—		$	253		Net change in cash
Cash at year end 2010	$	85		$	258		$	—		$	—		$	343		Cash at year end 2010

2010 A-5

CMS Energy
Reconciliation of 2010 Operating Cash Flow Target to GAAP Operating Activities
(unaudited)

	Amount
	(mils)
Consumers Operating (Consumers PTOI + Depreciation)	$	1,485
Enterprises (Project Cash Flows)		30
Operating Cash Flow	$	1,515		non-GAAP
Other operating activies including taxes, interest payments and working capital		(430	)
Net cash provided by operating activites	$	1,085		GAAP

2010 A-6