Exhibit 99.1

Growing Forward Barclays CEO Energy/Power Conference September 9-10, 2009 Thomas J. Webb Executive Vice President and Chief Financial Officer

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" each found in the MANAGEMENT'S DISCUSSION AND ANALYSIS 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. CMS Energy expects 2009 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.

Consistent financial performance Fair and timely regulation Utility investment Customer value Safe, excellent operations 2

Consumers Energy Diversified investment Affordable to customers Healthy capital structure Attractive earnings growth Investment required or strongly desired Timely recovery Ludington Pumped Storage B C Cobb J H Campbell D E Karn J C Weadock J R Whiting Mio Alcona Cooke Foote Loud 5 Channels Hodenpyl Tippy Rogers Hardy Croton Webber Allegan Electric Gas Combination Zeeland New coal plant Strategy Territory Investment growth balances responsible rate increases and healthy capital structure with attractive earnings growth.

Utility Investment Plan - 2009-2013 base 1 base 2 base 3 Clean Coal Plant AMI Renewables Electric Reliability and Other Gas Compression and Pipeline 2.55 0.436 0.963 0.53 0.62 0.31 0.55 0.34 $6.3 Billion investment program diversified. Base Capital 63% Maintenance 41% Customer Growth 7% Clean Air 15%

Sales Electric Sales (weather adjusted) Sales decline similar to recession in early 1980s; new businesses emerging. GM and New "Green" Initiatives 2009 1975 1986 1997 1975 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 August Plan 22145 23722 24572 25237 25707 24533 24875 23916 24893 26051 26305 26977 27928 29143 29623 29894 30325 30877 31868 33177 34465 34622 35462 36355 37234 37463 37301 37792 37746 38017 37586 38372 38098 37339 36000 Revised Potential 37339 36000 0 Electric Gas Combination (7)% Decline over three years ('79 -'82 recession) 2008 2009 (2)% (3.5)% General Motors Motors Liquidation Company New "Green" Facilities

2009 Electric Sales Outlook (weather-adjusted) Forecasted Sales Y-O-Y Industrial Sales by Quarter We expect the pace of the industrial and commercial sales decline to slow in the Second Half; with residential sales still falling modestly. _ _ _ _ a Includes other First Second Third Fourth Prior Guidance -0.106 -0.15 -0.11 -0.05 Present Guidance -0.106 -0.12 -0.082 -0.041 Full Year (11)% (9) 2009 First Second Full Half Half Year (Gwh) (Gwh) (Gwh) Residential (1)% (1)% (1)% Commercial (4) 0 (2) Industrial (11) (6) (9) Total a (5)% (2)% (3.5)% ? ?

Normal High Actual High 6/1/2009 75 76 1 6/2/2009 75 62 -13 6/3/2009 75 66 -9 6/4/2009 75 69 -6 6/5/2009 76 75 -1 6/6/2009 76 71 -5 6/7/2009 76 76 0 6/8/2009 77 74 -3 6/9/2009 77 68 -9 6/10/2009 77 74 -3 6/11/2009 77 66 -11 6/12/2009 77 75 -2 6/13/2009 78 69 -9 6/14/2009 78 78 0 6/15/2009 78 79 1 6/16/2009 78 76 -2 6/17/2009 79 70 -9 6/18/2009 79 77 -2 6/19/2009 79 79 0 6/20/2009 79 83 4 6/21/2009 79 81 2 6/22/2009 80 84 4 6/23/2009 80 88 8 6/24/2009 80 93 13 6/25/2009 80 90 10 6/26/2009 80 83 3 6/27/2009 80 82 2 6/28/2009 81 78 -3 6/29/2009 81 73 -8 6/30/2009 81 64 -17 7/1/2009 81 66 -15 7/2/2009 81 65 -16 7/3/2009 81 73 -8 7/4/2009 82 73 -9 7/5/2009 82 82 0 7/6/2009 82 80 -2 7/7/2009 82 74 -8 7/8/2009 82 74 -8 7/9/2009 82 80 -2 7/10/2009 82 81 -1 7/11/2009 82 82 0 7/12/2009 82 78 -4 7/13/2009 82 77 -5 7/14/2009 82 78 -4 7/15/2009 82 82 0 7/16/2009 82 78 -4 7/17/2009 83 70 -13 7/18/2009 83 69 -14 7/19/2009 83 73 -10 7/20/2009 83 80 -3 7/21/2009 83 82 -1 7/22/2009 83 79 -4 7/23/2009 82 78 -4 7/24/2009 82 81 -1 7/25/2009 82 79 -3 7/26/2009 82 75 -7 7/27/2009 82 83 1 7/28/2009 82 84 2 7/29/2009 82 78 -4 7/30/2009 82 78 -4 7/31/2009 82 79 -3 8/1/2009 82 79 -3 8/2/2009 82 75 -7 8/3/2009 82 82 0 8/4/2009 82 84 2 8/5/2009 81 78 -3 8/6/2009 81 79 -2 8/7/2009 81 78 -3 8/8/2009 81 79 -2 8/9/2009 80 91 11 8/10/2009 80 83 3 8/11/2009 80 81 1 8/12/2009 80 80 0 8/13/2009 80 83 3 8/14/2009 80 84 4 8/15/2009 80 85 5 8/16/2009 80 89 9 8/17/2009 80 80 0 8/18/2009 80 81 1 8/19/2009 80 80 0 8/20/2009 80 79 -1 8/21/2009 79 75 -4 8/22/2009 79 66 -13 8/23/2009 78 69 -9 8/24/2009 78 76 -2 8/25/2009 78 81 3 8/26/2009 78 73 -5 8/27/2009 78 67 -11 June-August Temperatures 66 of 88 days at or below normal temperature adding additional pressure to economic sales challenge. Actual High Normal High ^ Cool Michigan Summer

Michigan Energy Legislation Bills balance need for regulatory certainty with customer interests. File and implement ratemaking with forward test year Rate deskewing - over 5 years Cap on choice - 10% of load Certificate of Necessity Renewables - 10% by 2015 Energy efficiency - sales reduction targets

Regulatory Timeline Oct-07 Nov-07 Dec-07 Jan-08 Feb-08 Mar-08 Apr-08 May-08 Jun-08 Jul-08 Aug-08 Sep-08 Oct-08 Nov-08 Dec-08 Jan-09 Feb- 09 Mar-09 November February April May June September November May Electric Rate Case U-15645 Filed Staff and intervenors file Rebuttals Self implemented $179 mil Cross examination PFD Final order New Gas General Rate Case Filed $114 mil Self implement Final Order Renewable Energy Plan (10% by 2015) Filed Final Order Implemented Surcharge $79 mil Energy Optimization Plan Filed Final Order Implemented Surcharge $91 mil (5.5% electric by 2015) (5.5% electric by 2015) (5.5% electric by 2015) (5.5% electric by 2015) (5.5% electric by 2015) 2008 2009 2010 ? ? ? ? Bills balance need for regulatory certainty with customer interests.

Electric Rate Case filed (November 2008) Self Implemented Amount (May 2009) Staff Position + Errors Staff Position (April 2009) 197 179 179 138 138 111 111 18 41 27 Electric Rate Case Revised Staff Position (May 2009) Staff Position + Adjustments Self Implement (May 2009) Millions $ Sales $11 Rate Base/Misc 30 Forestry $19 UA tracker 8

2008 2009 2010 2011 2012 2013 Depreciation 7.851 8.729 8.486 7.922 7.592 7.123 6.597 Maintenance 0.574 1.132 1.644 2.117 2.616 Customer growth 0.077 0.156 0.244 0.337 0.431 Environmental 0.057 0.19 0.341 0.501 0.797 Zeeland plant 0.481 0.481 0.481 0.481 0.481 Gas compression and pipelines 0.064 0.143 0.211 0.279 0.342 Electric reliability and other 0.022 0.077 0.137 0.254 0.444 Renewables 0.005 0.023 0.039 0.122 0.26 AMI 0.006 0.011 0.019 0.095 0.348 Clean coal plant 0.029 0.096 0.238 0.408 0.556 7% Utility Growth Rate Base Bils $ Present Rate Base 2008 2009 2010 2011 2012 2013 Average Rate Base (bils) $9.3 $9.7 $10.5 $11.2 $12.4 New investment based on balancing responsible rate increases, strong capital structure, as well as earnings and cash flow growth. 0 Investment 2009-13 (mils) Base capital $ 3,950 Choices in Plan Clean coal plant $ 530 ? AMI 620 Renewables 310 Electric reliability and other 550 Gas compression and pipelines 340 Total Choices in Plan $ 2,350 Total Capital 2009-13 $ 6,300 Examples of Coal Plant Alternative Plant life extensions/new gas generation $200 Accelerated wind investment 250 Reliability 75 Total $525 ? Investment Plan

Balanced Energy Plan Summary Extensive analysis of alternatives and risks Diverse and balanced plan Meets 10% renewable portfolio standard by 2015 Meets energy efficiency target of 5.5% by 2015 Includes demand management programs Purchase of Zeeland natural gas plant Build new clean coal facility Renewables (Nominal) Energy Efficiency and Demand Management Clean Coal Gas Combined Cycle 32 31 18 19 New Resources 2008 - 2018 New generation from diversified "fuel" sources.

What Makes CMS Different? State energy legislation provides framework for growth Diversified Utility investment opportunities boost rate base and EPS Timely regulation minimizes recovery lag Diversified customer base mitigates auto exposure Solid liquidity position NOL and AMT credits avoid need for new equity Track record of predictability Dividend yield and relative stock price discount provide attractive investment opportunity.

Appendix

Tax Sharing Year-End Actual Estimate 2008 2009 2010 (bils) (bils) (bils) Gross NOL carry forwards $ 1.3 $ 1.0 $ .5 Net NOL cash benefit at 35% $ .4 $ .3 $ .2 Credit carry forwards .3 .3 .3 Remaining cash benefit $ .7 $ .6 $ .5 Appendix 1

Electric Customer Base Diversified . . . . Hemlock Semiconductor General Motors Delphi Corporation Pfizer Incorporated Meijer Incorporated State of Michigan Quanex Corporation Packaging Corporation of America Dow Corning Corporation Denso International Percent of 2008 electric gross margin is 3% Top Ten Customers Residential Commercial Autos Industrial Other 0.48 0.33 0.03 0.15 0.01 $1.6 Billion . . . . "Autos" only 3% of gross margin. 2008 Electric Gross Margin Appendix 2

Customer Value Coal MCV Gas Nuclear Renewables Pumped Storage Oil Purchases 2008 0.32 0.13 0.23 0.08 0.03 0.1 0.05 0.06 Consumers Energy Coal Gas Nuclear Renewables Pumped Storage Oil Purchases 2006 0.52 0.26 0.08 0.01 0.02 0.06 0.05 9,600 MW MISO 125,000 MW Capacity Fuel Mix -- 2008 Diversified fuel mix minimizes risk and optimizes cost. MCV Appendix 3

Uncollectible Accounts An "auto-wide" bankruptcy would have an incremental "one time write off" impact. "Auto-wide" Bankruptcy Exposure _ _ _ _ a Excluding companies in bankruptcy Utility Uncollectible Accounts Millions $ 2006 2007 2008 2009 Forecast Net Charge-offs 27.4 29.6 41.5 44.5 Bankruptcies 3 2.6 4.1 8.5 GM Bankruptcy 0 0 0 0 5 Pct of Revenue 0.5% 0.5% 0.7% 0.9% $9 Appendix 4

Recent Financing Amount at August 31 (mils) Cash $ 351 Bank Facilities ($1,200) 792 Accounts Receivable Facility ($250) 53 Total liquidity $1,196 2009 2010 2011 2012 2013 East 0 67 213 150 150 West 233 87 Total Liquidity Parent Maturities (Aug vs Jan) Liquidity position strengthened; refinancing risks substantially reduced. $213 $67 Convertible Puts $288 $140 Appendix 5

MATURITY SCHEDULE OF CMS AND CECO LONG-TERM DEBT & PREFERRED SECURITIES
AS OF 07/31/2009

		Maturity	Amount
F/V	S/U	or Call Date	(000’s)			DEBT/ CO
SHORT-TERM DEBT:
F	S	08/15/09	$	150,000		4.4% Series K FMBs (CECo)
F	S	05/15/10		250,000		4% $250MM FMBs (CECo)
F	S	06/15/10		30,000		3.375% Fixed PCRBs (CECo)
F	S	06/15/10		27,900		4.25% PCRBs (CECo)
			$	457,900
LONG-TERM DEBT:
F	U	08/01/10	$	67,291		7.75% Sr Unsec Notes (CMS)
			$	67,291
F	U	04/15/11	$	213,653		8.5% Sr Notes (CMS)
F	U	12/01/11		287,500		*2.875% Convertible Sr Unsec Notes Put Date (CMS)
			$	501,153
F	U	02/01/12	$	150,000		6.3% Senior Notes (CMS)
F	S	02/15/12		300,000		5% Series L FMBs (CECo)
			$	450,000
V	U	01/15/13	$	150,000		Floating Rate Sr Notes (CMS)
F	S	04/15/13		375,000		5.375% Series B FMBs (CECo)
F	U	07/15/13		140,000		*3.375% Convertible Sr Notes Put Date (CMS)
			$	665,000
F	S	02/15/14	$	200,000		6% FMBs (CECo)
F	U	06/15/14		172,500		5.5% Convertible Sr Notes Put Date (CMS)
F	S	03/15/15		225,000		5% FMBs Series N (CECo)
F	U	12/15/15		125,000		6.875% Sr Notes (CMS)
F	S	08/15/16		350,000		5.5% Series M FMBs (CECo)
F	S	02/15/17		250,000		5.15% FMBs (CECo)
F	U	07/17/17		250,000		6.55% Sr Notes (CMS)
F	S	03/01/18		180,000		6.875% Sr Notes (CECo)
V	S	04/15/18		67,700		VRDBs to replace PCRBs (CECo)
F	S	09/15/18		250,000		5.65% FMBs (CECo)
F	S	03/15/19		350,000		6.125% FMBs (CECo)
F	U	06/15/19		300,000		8.75% Sr Notes (CMS)
F	S	09/15/19		500,000		6.70% FMBs (CECo)
F	S	04/15/20		300,000		5.65% FMBs (CECo)
F	U	07/15/27		34,002		QUIPS 7.75%(CMS) Pref Sec **
V	S	04/01/35		35,000		PCRBs (CECo)
F	S	04/15/35		139,266		5.65% FMBs IQ Notes (CECo)
F	S	09/15/35		175,000		5.80% FMBs (CECo)
			$	3,903,468
			$	6,044,812		TOTAL
			$	6,010,810		TOTAL EXCLUDING PREFERRED SECURITIES
		Various Maturity Dates/No Maturity Date Available:
			$	252,817		CECo Securitization Bonds (Long-Term & Short-Term) after 07/20/09 payment
				218,789		CECo Capital lease rental commitments (Long-Term & Short-Term) as of 06/30/09
				667		CMS Enterprises (Genesee) Capital lease rental commitments (Long-Term & Short-Term) as of 06/30/09
				162,706		CECo DOE Liability as of 07/31/09
				160,319		EnerBank (Long-Term & Short-Term) Discount Brokered CDs as of 06/30/09 (CMS)
				(43,935	)	CMS Net unamortized discount as of 06/30/09
				(5,416	)	CECo Net unamortized discount as of 06/30/09
				71,541		CMS Enterprises Debt as of 06/30/09
			$	6,862,299		TOTAL INCLUDING CMS ENERGY, CONSUMERS & OTHER CMS
						ENTERPRISES SUBSIDIARIES, INCLUDING PREFERRED SECURITIES

*—	Date that issue can be put to the Company is used instead of maturity date
**—	Includes subordinated notes amounts associated with preferred securities. Principal amount of QUIPS: $28.6665MM
	Status Codes: F-Fixed rate; V-Variable rate; S-Secured; U-Unsecured

Appendix-6

GAS RATE CASE U-15986*

On May 22, 2009, Consumers Energy filed an application with the Michigan Public Service Commission seeking an increase in its gas delivery and transportation rates based on a 12 month ending September 30, 2010 test year. Due to the uncertainty related to the length and depth of the declining Michigan economy, the request seeks authorization to implement an uncollectible accounts expense tracker, pension tracker, as well as a revenue decoupling proposal. The proposed capital structure includes an 11.00% authorized return on equity. If approved, the request would add about $4.50 per month, or about 5.0%, to the typical residential customer’s average monthly bill. The $114 million revenue deficiency is detailed below. If the Commission has not acted on the application within 180 days of the filing, the company may implement up to the amount of the rate request.

Item	$ Millions		Explanation
1. O&M	$	25	Uncollectible accounts expense: $17 Pension and health care: $7 Other: $1
2. Sales		41	Lower throughput and customer mix reflecting MI economy: $40 (272 Bcf vs. 305 Bcf) Miscellaneous revenues: $1
3. Investment		40	Net plant: $40 (improved deliverability, regulatory compliance, AMI) Depreciation and property taxes: $7 Working capital: ($2) Taxes and other: ($5)
4. Cost of Capital		8	Return on Equity: $8 (11.00% vs 10.55%) Higher debt costs: $3 Lower capitalization: ($3)(lower equity ratio; increased deferred income taxes)
Total	$	114

Ratemaking	Existing			As Filed						After-Tax
Capital Structure	(U-15506)			Percent of Total			Annual Cost			Weighted Costs
Long Term Debt		42.71	%		43.43	%		5.97	%		2.59	%
Short Term Debt		0.66			0.58			8.83			0.05
Preferred Stock		0.49			0.46			4.46			0.02
Common Equity		41.78			41.07	(1)		11.00			4.52
Deferred Taxes		12.94			13.17			0.00			0.00
JDITC/Other		1.42			1.29						0.10
		100.00	%		100.00	%					7.28	%(2)

Rate Base and Return	Existing
Percentage	(U-15506)			As Filed
Rate Base	$2.52 billion			$2.90 billion
Return on Rate Base		7.03	%		7.28	%
Return on Equity		10.55			11.00

GAS RATE CASE SCHEDULE — UPDATED AS OF JULY 1, 2009

Staff & Intervenors File Testimony	October 22, 2009
Rebuttal Testimony	November 16, 2009
Self Implementation Under PA 286	November 19, 2009
Motions to Strike Testimony	December 4, 2009
Cross of all Witnesses	December 14-18, 2009 and January 5-7, 2010
Initial Briefs	January 27, 2010
Reply Briefs	February 10, 2010
PFD Target Date	March 24, 2010
Exceptions	April 7, 2010
Replies to Exceptions	April 21, 2010
Commission Order	May 21, 2010

(1)	Equivalent to 48.34% on financial basis.
(2)	Equivalent to 10.19% pre-tax basis.
*	Gas Rate Case U-15986 can be accessed at the Michigan Public Service Commission’s website.
	http://efile.mpsc.cis.state.mi.us/efile/gas.html

Appendix-7

Consumers Electric Utility Financial & Operating Statistics CMS Energy Investor Relations One Energy Plaza, Jackson, MI 49201 Tel. 517-788-2590 http://www.cmsenergy.com Appendix-8

Consumers Electric Utility Supplemental Operating Statistics CMS Energy Investor Relations One Energy Plaza, Jackson, MI 49201 Tel. 517-788-2590 http://www.cmsenergy.com Appendix-9

Consumers Gas Utility Financial & Operating Statistics CMS Energy Investor Relations One Energy Plaza, Jackson, MI 49201 Tel. 517-788-2590 http://www.cmsenergy.com Appendix-10

Independent Power Production Asset List CMS Energy Investor Relations One Energy Plaza, Jackson, MI 49201 Tel. 517-788-2590 http://www.cmsenergy.com Honey Lake Craven Exeter Filer City Michigan Power - Kalamazoo River Michigan Power - Livingston Grayling Genesee DIG Renewables - 975 Gross MWs Other - 224 Gross MWs Appendix-11