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FORM 10-Q

**SECURITIES AND EXCHANGE COMMISSION****Washington, DC 20549******

| [X]  QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)    OF THE SECURITIES EXCHANGE ACT OF 1934  
For the quarterly period ended**March 31,    2003  
or
  
[  ]  TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)    OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _____________to_____________Commission File Number 1-6446**Kinder Morgan, Inc.**(Exact Name of Registrant as Specified in Its Charter)

Kansas
  
48-0290000
(State or Other Jurisdiction of    Incorporation or Organization)
  
(I.R.S. Employer    Identification No.)  
500 Dallas Street, Suite    1000, Houston, Texas 77002
(Address of Principal Executive Offices, Including Zip Code)  
(713) 369-9000
(Registrant's Telephone Number, Including Area Code)    
(Former Name, Former Address and Former Fiscal Year, if Changed    Since Last Report)
Indicate by check mark whether the registrant: (1) has filed allreports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934during the preceding 12 months (or for such shorter period that the registrant wasrequired to file such reports), and (2) has been subject to such filing requirements forthe past 90 days.

Yes  X   No ___
Indicate by check mark whether the registrant is an accelerated filer(as defined in Rule 12b-2 of the Exchange Act).

Yes  X   No ___
The number of shares outstanding of the registrant's common stock, $5par value, as of May 1, 2003 was 122,073,674 shares.

KINDER MORGAN, INC. AND SUBSIDIARIESFORM 10-QQUARTER ENDED MARCH 31, 2003Contents
  
Page    NumberPART I.FINANCIAL    INFORMATION  Item 1.Financial    Statements (Unaudited)  
   Consolidated Balance Sheets
3-4
   Consolidated Statements of Operations 
5
   Consolidated Statements of Cash Flows
6
   Notes to Consolidated Financial    Statements
7-19  Item 2.
Management's Discussion and Analysis of    Financial
   Condition and Results of Operations
20-30  Item 3.
Quantitative and    Qualitative Disclosures About Market Risk
30  Item 4.
Controls and Procedures
30  PART II.
OTHER    INFORMATION  Item 1.
Legal Proceedings
31  Item 2.
Changes in    Securities and Use of Proceeds
31  Item    3.
Defaults Upon Senior    Securities
31  Item 4.
Submission    of Matters to a Vote of Security Holders
31  Item 5.
Other Information
31  Item    6.
Exhibits and Reports on Form    8-K
31-32  SIGNATURE
33  CERTIFICATIONS
34-35
2
**PART I. - FINANCAL INFORMATION
*Item 1.  FinancialStatements.*
CONSOLIDATED BALANCE SHEETS(Unaudited)Kinder Morgan, Inc. and Subsidiaries****March 31,**December 31,**2003**2002
(In thousands)**ASSETS:****Current Assets:**Cash and Cash Equivalents 
$    29,465 
$    35,653 Restricted Deposits 
      6,678 
      2,783 Accounts Receivable, Net:   Trade 
     83,749 
     82,258    Related Parties 
      7,835 
     48,054 Inventories 
     25,881 
     62,760 Gas Imbalances 
     29,707 
     32,033 Other 
     97,942 
    157,454 
    281,257 
    420,995    **Investments:**Kinder Morgan Energy Partners 
  2,056,452 
  2,034,160 Goodwill 
    990,878 
    990,878 Other 
    295,525 
    285,883 
  3,342,855 
  3,310,921    **Property, Plant and Equipment**
  6,553,908 
  6,544,418 **Less Accumulated Depreciation and Amortization**
   (522,922)
   (496,311)
  6,030,986 
  6,048,107 **  ****Deferred Charges and Other Assets**
    283,659 
    322,727   **Total Assets**
$ 9,938,757 
$10,102,750 
=========== 
=========== 
The accompanying notes are an integral part of these statements.

3
**CONSOLIDATED BALANCE SHEETS (Unaudited)**Kinder Morgan, Inc. and Subsidiaries**
**March 31,**December 31,**2003**2002
(In thousands)**LIABILITIES AND STOCKHOLDERS' EQUITY:****Current Liabilities:**Current Maturities of Long-term Debt 
$     1,267 
$   501,267 Notes Payable 
    331,900 
          - Accounts Payable:   Trade 
     51,471 
     88,227    Related Parties 
         66 
         50 Accrued Interest 
     33,612 
     80,158 Accrued Expenses 
     39,673 
     49,580 Accrued Taxes 
     40,741 
     27,355 Gas Imbalances 
     33,738 
     50,394 Other 
     63,916 
     69,501 
    596,384 
    866,532 **  ****Other Liabilities and Deferred Credits:**Deferred Income Taxes 
  2,463,818 
  2,435,780 Other 
    197,546 
    210,869 
  2,661,364 
  2,646,649   **Long-term Debt:**  Outstanding 
  2,851,917 
  2,852,181   Interest Rate Swaps 
    126,076 
    139,589   
  2,977,993 
  2,991,770 **Kinder Morgan-Obligated Mandatorily Redeemable Preferred****  Capital Trust Securities of Subsidiary    Trusts Holding****  Solely Debentures of Kinder Morgan**
    275,000 
    275,000   **Minority Interests in Equity of Subsidiaries**
    975,587 
    967,802   **Stockholders' Equity:**Common Stock-  Authorized - 150,000,000 Shares, Par Value $5    Per Share  Outstanding - 130,200,635 and 129,861,650    Shares,    Respectively, Before Deducting    8,234,475 and 8,168,241    Shares Held in Treasury 
    650,999 
    649,308 Additional Paid-in Capital 
  1,688,838 
  1,681,042 Retained Earnings 
    578,843 
    486,062 Treasury Stock 
   (409,722)
   (406,630)Deferred Compensation 
     (9,628)
    (10,066)Accumulated Other Comprehensive Loss 
    (46,901)
    (44,719)Total Stockholders' Equity 
  2,452,429 
  2,354,997   **Total Liabilities and Stockholders' Equity**
$ 9,938,757 
$10,102,750 
=========== 
=========== 
The accompanying notes are an integral part of these statements.

4
**CONSOLIDATED STATEMENTS OFOPERATIONS (Unaudited)**Kinder Morgan, Inc. and Subsidiaries**
**Three Months Ended March    31,**2003**2002
(In thousands except per    share amounts)**Operating Revenues:**Natural Gas Transportation and Storage 
$ 182,853 
$ 153,406 Natural Gas Sales 
  122,999 
  120,776 Other 
   13,016 
   17,219     Total Operating Revenues 
  318,868 
  291,401   **Operating Costs and Expenses:**Gas Purchases and Other Costs of Sales 
  112,955 
  101,247 Operations and Maintenance 
   29,901 
   29,080 General and Administrative 
   16,408 
   19,550 Depreciation and Amortization 
   29,625 
   26,004 Taxes, Other Than Income Taxes 
    7,174 
    7,165     Total Operating Costs and Expenses 
  196,063 
  183,046   **Operating Income**
  122,805 
  108,355   **Other Income and (Expenses):**Equity in Earnings of Kinder Morgan Energy Partners 
  111,495 
   90,091 Equity in Earnings of Other Equity Investments 
    2,483 
    2,372 Interest Expense, Net 
  (39,974)
  (39,548)Minority Interests 
  (15,921)
  (12,777)Other, Net 
      996 
    3,573     Total Other Income and (Expenses) 
   59,079 
   43,711   **Income Before Income Taxes**
  181,884 
  152,066 Income Taxes 
   70,814 
   63,678   **Net Income**
$ 111,070 
$  88,388 
========= 
=========   **Basic Earnings Per Common Share**
$    0.91 
$    0.72 
========= 
=========   Number of Shares Used in Computing Basic    Earnings Per Common Share    (Thousands) 
  121,877 
  123,398 
========= 
=========   **Diluted Earnings Per Common Share**
$    0.90 
$    0.71 
========= 
=========   Number of Shares Used in Computing Diluted    Earnings Per Common Share    (Thousands) 
  123,078 
  124,829 
========= 
=========   **Dividends Per Common Share**
$    0.15 
$    0.05 
========= 
========= 
The accompanying notes are an integral part of these statements.

5
**CONSOLIDATED STATEMENTS OF CASH FLOWS(Unaudited)**Kinder Morgan, Inc. and SubsidiariesIncrease (Decrease) in Cash and Cash Equivalents**
**Three Months Ended March    31,**2003**2002
(In thousands)**Cash Flows From Operating Activities:**Net Income 
$   111,070 
$    88,388 Adjustments to Reconcile Net Income to Net Cash Flows       from Operating Activities:    Depreciation and Amortization 
     29,625 
     26,004     Deferred Income Taxes 
     30,350 
      9,990     Equity in Earnings of Kinder Morgan    Energy Partners 
   (111,495)
    (90,091)    Distributions from Kinder Morgan    Energy Partners 
     86,965 
     70,394     Equity in Earnings of Other    Investments 
     (2,483)
     (2,372)    Minority Interests in Income of    Consolidated Subsidiaries 
     10,443 
      7,299     Deferred Purchased Gas Costs 
     (7,129)
     (3,236)    Net Gains on Sales of Facilities 
          - 
     (2,567)    Changes in Gas in Underground    Storage 
     38,575 
     13,637     Changes in Other Working Capital    Items 
    (56,000)
    (16,258)    Proceeds from Termination of    Interest Rate Swap 
     28,147 
          -     Other, Net 
      1,999 
      2,544   Net Cash Flows Provided by Continuing    Operations 
    160,067 
    103,732   Net Cash Flows Used in Discontinued Operations 
       (366)
     (3,478)**Net Cash Flows Provided by Operating Activities**
    159,701 
    100,254   **Cash Flows From Investing Activities:**Capital Expenditures 
    (19,480)
    (35,885)Other Investments 
     (7,945)
    (29,565)Proceeds from Sales of Other Assets 
      2,629 
      4,385 **Net Cash Flows Used in Investing Activities**
    (24,796)
    (61,065)  **Cash Flows From Financing Activities:**Short-term Debt, Net 
    331,900 
    138,015 Long-term Debt Retired 
   (500,317)
       (320)Common Stock Issued 
      9,538 
      9,728 Short-term Advances (To) From Unconsolidated Affiliates 
     40,235 
    (90,347)Repurchase of Kinder Morgan Management LLC Shares 
       (928)
          - Treasury Stock Acquired 
     (3,092)
    (94,405)Cash Dividends, Common Stock 
    (18,289)
     (6,186)Minority Interests, Net 
       (140)
       (107)**Net Cash Flows Used in Financing Activities**
   (141,093)
    (43,622)  Net Decrease in Cash and Cash Equivalents 
     (6,188)
     (4,433)Cash and Cash Equivalents at Beginning of Period 
     35,653 
     16,134 Cash and Cash Equivalents at End of Period 
$    29,465 
$    11,701 
=========== 
=========== 
For supplemental cash flow information, see Note 4.The accompanying notes are an integral part of these statements.

6
**NOTES TOCONSOLIDATED FINANCIAL STATEMENTS (Unaudited)**
1.   General
We are a provider of energy and related services and have operations inthe Rocky Mountain and mid-continent regions of the United States, with principaloperations in Arkansas, Colorado, Illinois, Iowa, Kansas, Nebraska, Oklahoma, Texas andWyoming. Services we offer include: (i) storing, transporting and selling natural gas,(ii) providing retail natural gas distribution services and (iii) natural gas-firedelectric generation facilities. We have both regulated and nonregulated operations. Ourcommon stock is traded on the New York Stock Exchange under the symbol "KMI." Asa result of our October 1999 acquisition of Kinder Morgan (Delaware), Inc., we own thegeneral partner interest, as well as significant limited partner interests, in KinderMorgan Energy Partners, L.P., a publicly traded pipeline master limited partnership,referred to in these Notes as "Kinder Morgan Energy Partners," and receive asubstantial portion of our earnings from returns on these investments.

We have prepared the accompanying unaudited interim consolidatedfinancial statements under the rules and regulations of the Securities and ExchangeCommission. Under such rules and regulations, we have condensed or omitted certaininformation and notes normally included in financial statements prepared in conformitywith accounting principles generally accepted in the United States of America. We believe,however, that our disclosures are adequate to make the information presented notmisleading. The consolidated financial statements reflect all adjustments that are, in theopinion of management, necessary for a fair presentation of our financial results for theinterim periods presented. You should read these interim consolidated financial statementsin conjunction with our consolidated financial statements and related notes included inour Annual Report on Form 10-K for the year ended December 31, 2002 ("2002 Form10-K"). Certain prior period amounts have been reclassified to conform to the currentpresentation. Unless the context requires otherwise, references to "we,""us," "our," or the "Company" are intended to mean KinderMorgan, Inc. and its consolidated subsidiaries.

2.   Earnings Per Share
Basic earnings per common share is computed based on theweighted-average number of common shares outstanding during each period. In recentperiods, we have repurchased a significant number of our outstanding shares, see Note 10.Diluted earnings per common share is computed based on the weighted-average number ofcommon shares outstanding during each period, increased by the assumed exercise orconversion of securities (stock options are currently the only such securitiesoutstanding) convertible into common stock, for which the effect of conversion or exerciseusing the treasury stock method would be dilutive.
**Three Months Ended    March 31,**2003**2002
(In thousands)Weighted-average Common Shares Outstanding 
 121,877
 123,398Dilutive Common Stock Options 
   1,201
   1,431Shares Used to Compute Diluted Earnings Per Common Share 
 123,078
 124,829
========
========
Weighted-average stock options outstanding totaling 2.6 million and 1.4million for the three months ended March 31, 2003 and 2002, respectively, were excludedfrom the diluted earnings per common share calculation because the effect of includingthem would have been antidilutive.

7

3.   InterestExpense, Net
"Interest Expense, Net" as presented in the accompanyinginterim Consolidated Statements of Operations is net of the debt component of theallowance for funds used during construction, which was $0.3 million and $0.4 million forthe three months ended March 31, 2003 and 2002, respectively.

4.   Cash FlowInformation
We consider all highly liquid investments purchased with an originalmaturity of three months or less to be cash equivalents.

**Changes in Other Working Capital Items:(Net of Effects of Acquisitions and Sales)Increase (Decrease) in Cash and Cash Equivalents**
**Three Months Ended    March 31,**   ****2003**2002
(In thousands) Accounts Receivable 
$  (1,418)
$  28,900 Materials and Supplies Inventory 
     (316)
    6,541 Other Current Assets 
   59,150 
   (2,849)Accounts Payable 
  (36,954)
  (56,396)Other Current Liabilities 
  (76,462)
    7,546 
$ (56,000)
$ (16,258)
========= 
=========   **Supplemental Disclosures of    Cash Flow Information:**  **Cash Paid During the Period for:**Interest, Net of Amount Capitalized 
$  75,811 
$  66,625   
========= 
========= Income Taxes Paid (Received) 
$    (281)
$   4,272 
========= 
========= 
Distributions received by our Kinder Morgan Management subsidiary fromits investment in i-units of Kinder Morgan Energy Partners are in the form of additionali-units, while distributions made by Kinder Morgan Management to its shareholders are inthe form of additional Kinder Morgan Management shares, see Note 6.

5.   ComprehensiveIncome
Our comprehensive income for the three months ended March 31, 2003 and2002 is as follows:
**Three Months Ended March 31,**2003**2002
(In thousands)**Net Income:**
$ 111,070 
$  88,388 **Other Comprehensive Income, Net of Tax:**  Change in Fair Value of Derivatives Utilized    for Hedging Purposes, Net of Tax 
  (21,104)
  (10,483)  Reclassification of Change in Fair Value of    Derivatives to Net Income, Net of    Tax 
   18,731 
    5,232   Equity in Other Comprehensive Income of    Equity Method Investees 
   (1,388)
  (19,245)  Minority Interest in Other Comprehensive    Income of Equity Method Investees 
    1,579 
    8,008 **Other Comprehensive Income**
   (2,182)
  (16,488)**  ****Comprehensive Income**
$ 108,888 
$  71,900 
========= 
========= 
8

6.   Kinder Morgan Management, LLC
On February 14, 2003, Kinder Morgan Management paid a sharedistribution of 858,981 of its shares to shareholders of record as of January 31, 2003,based on the $0.625 per common unit distribution declared by Kinder Morgan EnergyPartners. On May 15, 2003, Kinder Morgan Management will make a distribution totaling859,933 of its shares to shareholders of record as of April 30, 2003, based on the $0.64per common unit distribution declared by Kinder Morgan Energy Partners for the firstquarter of 2003. These distributions are paid in the form of additional shares orfractions thereof calculated by dividing the Kinder Morgan Energy Partners' cashdistribution per common unit by the average market price of a Kinder Morgan Managementshare determined for a ten-trading day period ending on the trading day immediately priorto the ex-dividend date for the shares.

7.   SummarizedIncome Statement Information for Kinder Morgan Energy Partners, L.P.
Following is summarized income statement information for Kinder MorganEnergy Partners, a publicly traded master limited partnership in which we own the generalpartner interest. In addition, we own limited partner interests in the form of KinderMorgan Energy Partners common units, i-units (indirectly through Kinder Morgan Management)and Class B limited partner units. This investment, which is accounted for under theequity method of accounting, is described in more detail in our 2002 Form 10-K. Additionalinformation on Kinder Morgan Energy Partners' results of operations and financial positionare contained in its Quarterly Report on Form 10-Q for the quarter ended March 31, 2003and in its Annual Report on Form 10-K for the year ended December 31, 2002.
**Three Months Ended March 31,**2003**2002
(In thousands)Operating Revenues 
$ 1,788,838
$   803,065Operating Expenses 
  1,593,686
    637,209Operating Income 
$   195,152
$   165,856
===========
===========Net Income 
$   170,478
$   141,433
===========
===========
8.   DiscontinuedOperations
During 1999, we adopted and implemented a plan to discontinue a numberof lines of business. During 2000, we essentially completed the disposition of thesediscontinued operations. The cash flows attributable to discontinued operations includedin the accompanying interim Statements of Consolidated Cash Flows under the caption"Net Cash Flows Used in Discontinued Operations" result from cash activityattributable to retained liabilities associated with these discontinued operations. Note 8of Notes to Consolidated Financial Statements included in our 2002 Form 10-K containsadditional information on these matters.

9.   Financing
We have available a $445 million 364-day credit facility dated October15, 2002, and a $355 million three-year revolving credit agreement dated October 15, 2002.These bank facilities can be used for general corporate purposes, including backup for ourcommercial paper program and, as discussed in our 2002 Form 10-K, include covenants thatare common in such arrangements. Under these bank facilities, we are required to pay afacility fee based on the total commitment, whether used or unused, at a rate 

9

that varies based on our senior debt rating. We had no borrowings underour bank facilities at March 31, 2003.

The commercial paper we issue, which is supported by the creditfacilities described above, is comprised of unsecured short-term notes with maturities notto exceed 270 days from the date of issue. Commercial paper outstanding at March 31, 2003was $331.9 million. Our weighted-average interest rate on short-term borrowingsoutstanding at March 31, 2003 was 1.50 percent. Average short-term borrowings outstandingduring the first quarter of 2003 were $115.4 million and the weighted-average interestrate was 1.53 percent.

On March 3, 2003, our $500 million 6.45% Senior Notes matured and wepaid the holders of the notes.

On April 16, 2003, our Board of Directors approved a cash dividend of$0.15 per common share payable on May 15, 2003 to shareholders of record as of April 30,2003.

10.  Common StockRepurchase Plan
On August 14, 2001, we announced a program to repurchase up to $300million of our outstanding common stock, which program was increased to $400 million and$450 million at February 5, 2002 and July 17, 2002, respectively. As of March 31, 2003, wehad repurchased a total of approximately $416.1 million (8,339,300 shares) of ouroutstanding common stock under the program, of which $1.4 million (31,100 shares) wererepurchased in the three months ended March 31, 2003.

11.  Business Segments
In accordance with the manner in which we manage our businesses,including the allocation of capital and evaluation of business segment performance, wereport our operations in the following segments: (1) Natural Gas Pipeline Company ofAmerica and certain affiliates, referred to as Natural Gas Pipeline Company of America, amajor interstate natural gas pipeline and storage system; (2) TransColorado GasTransmission Company, referred to as TransColorado Pipeline, an interstate natural gaspipeline located in western Colorado and northwest New Mexico; (3) Kinder Morgan Retail,the regulated sale and transportation of natural gas to residential, commercial andindustrial customers (including a small distribution system currently being built-out inHermosillo, Mexico) and the non-regulated sales of natural gas to certain utilitycustomers under the Choice Gas Program and (4) Power, the operation and, in previousperiods, construction of natural gas-fired electric generation facilities.

The accounting policies we apply in the generation of business segmentinformation are generally the same as those described in Note 1 of Notes to ConsolidatedFinancial Statements included in our 2002 Form 10-K, except that (i) certain items belowthe "Operating Income" line are either not allocated to business segments or arenot considered by management in its evaluation of business segment performance and (ii)equity in earnings of equity method investees, other than Kinder Morgan Energy Partnersand certain insignificant international investees, are included in segment results. Theseequity method earnings are included in "Other Income and (Expenses)" in ourConsolidated Statements of Operations. In addition, (i) certain items included inoperating income (such as general and administrative expenses) are not allocated toindividual business segments and (ii) gains and losses from incidental sales of assets areincluded in segment earnings. With adjustment for these items, we currently evaluatebusiness segment performance primarily based on operating income in relation to the levelof capital employed. We account for intersegment sales at market prices, while we accountfor asset transfers at either market value or, in some instances, book value.

10

BUSINESS SEGMENT INFORMATION
**Three Months    Ended March 31, 2003**March 31, 2003  **Segment Earnings**Revenues From    External    Customers**Intersegment    Revenues**Depreciation    And    Amortization**Capital    Expenditures**Segment    Assets  
(In    thousands)Natural Gas Pipeline Company       of America 
$  100,076 
$  214,068
$        -
$   22,305 
$   14,808
$5,587,688 TransColorado Pipeline 
     7,260 
     9,499
         -
     1,066 
       409
   243,036 Kinder Morgan Retail 
    31,459 
    88,989
         -
     3,924 
     1,586
   403,842 Power 
     2,920 
     6,312
         -
     2,330 
     2,677
   355,391    Segment Totals 
  141,715 
$  318,868
$        -
$   29,625 
$   19,480
 6,589,957 
==========
==========
========== 
==========Earnings from Investment in      Kinder Morgan Energy       Partners 
   111,495   
    Investment in Kinder Morgan      Energy Partners     Goodwill 
 2,056,452        990,878 General and Administrative      Expenses 
   (16,408)  
    Other1       Consolidated 
   301,470 $9,938,757 Other Income and (Expenses) 
   (54,918)    
  
========== Income Before Income Taxes 
$  181,884     
  
==========     **Three Months Ended March 31, 2002**    **Segment Earnings**Revenues From    External    Customers**Intersegment    Revenues**Depreciation    And    Amortization**Capital    Expenditures**    
(In thousands)Natural Gas Pipeline Company       of America 
$   95,618 
$  183,089
$        -
$   21,764 
$   18,034
  TransColorado Pipeline 
        93 
         -
         -
         - 
         -
  Kinder Morgan Retail 
    24,858 
    97,627
         -
     3,470 
       845
  Power 
     9,740 
    10,685
         -
       770 
    17,006
     Segment Totals 
   130,309 
$  291,401
$        -
$   26,004 
$   35,885
  
==========
==========
========== 
==========
  Earnings from Investment in      Kinder Morgan Energy       Partners 
    90,091 
  General and Administrative      Expenses 
   (19,550)
  Other Income and (Expenses) 
   (48,784)
  Income Before Income Taxes 
$  152,066 
  
========== 
    1
Includes market value of    derivative instruments (including interest rate swaps) and miscellaneous corporate assets    (such as information technology and telecommunications equipment) not allocated to    individual segments.
GEOGRAPHIC INFORMATION

All but an insignificant amount of our assets and operations arelocated in the continental United States of America.

12.  Accounting for AssetRetirement Obligations
We adopted Statement of Financial Accounting Standards("SFAS") No. 143, *Accounting for Asset Retirement Obligations*, effectiveJanuary 1, 2003. This statement changed the financial accounting and reporting forobligations associated with the retirement of tangible long-lived assets and theassociated retirement costs. The statement requires that the fair value of a liability foran asset retirement obligation 

11

be recognized in the period in which it is incurred if a reasonableestimate of fair value can be made. The impact of the adoption of this statement on us isdiscussed below by segment.

In general, Natural Gas Pipeline Company of America's system iscomposed of underground piping, compressor stations and associated facilities, natural gasstorage facilities and certain other facilities and equipment. Except as discussedfollowing, we have no plans to abandon any of these facilities, the majority of which havebeen providing utility service for many years, making it impossible to determine thetiming of any potential retirement expenditures. Notwithstanding our current intentions,in general, if we were to cease utility operations in total or in any particular area, wewould be permitted to abandon the underground piping in place, but would have to removeour surface facilities from land belonging to our customers or others. We would generallyhave no obligations for removal or remediation with respect to equipment and facilities,such as compressor stations, located on land we own.

Natural Gas Pipeline Company of America has various condensate dripstanks located throughout the system, depleted storage wells located within the storagefields, laterals no longer integral to the overall mainline transmission system,compressor stations which are no longer active, and other miscellaneous facilities, all ofwhich have been officially abandoned. For these facilities, it is possible to reasonablyestimate the timing of the payment of obligations associated with their retirement. Therecognition of these obligations has resulted in a liability and associated asset ofapproximately $2.8 million as of January 1, 2003, representing the present value of thosefuture obligations for which we are able to make reasonable estimations of the currentfair value due to, as discussed above, our ability to estimate the timing of theincurrence of the expenditures. The remainder of Natural Gas Pipeline Company of America'sasset retirement obligations have not been recorded due to our inability, as discussedabove, to reasonably estimate when they will be settled in cash. We will recordliabilities for these obligations when we are able to reasonably estimate their fairvalue.

In general, our retail natural gas distribution system is composed oftown border stations, regulator stations, underground piping and delivery meters. Inaddition, we have (i) certain other associated surface equipment, (ii) gas storagefacilities in Colorado and Wyoming and (iii) one producing gas field in Colorado. Exceptas discussed following, we have no plans to abandon any of these facilities, the majorityof which have been providing utility service for many years, making it impossible todetermine the timing of any potential retirement expenditures. Notwithstanding our currentintentions, if we were to cease utility operations in any particular area, we would bepermitted to abandon the underground piping in place, but would have to remove our surfacefacilities at customer delivery points. We would be under no obligation to remove townborder stations, odorization or other miscellaneous facilities located on our property.

In our Kinder Morgan Retail storage field operations we would, uponabandonment, be required to plug and abandon the wells and to remove our surface wellheadequipment and compressors. We currently have two small sites in Wyoming that are no longerbeing used as active storage facilities and estimate that, in 2013, we will incurapproximately $200,000 in costs to conduct these retirement obligations. We have no plansto cease using any of our other storage facilities as they are expected to, for theforeseeable future, provide critical deliverability to our customers in severe coldweather situations. With respect to our small natural gas production field in Colorado, wewill be required, upon cessation of commercial operations, to plug and abandon the naturalgas wells, remove surface equipment and remediate the well sites. We have estimated thatthis process will start in 2005 and continue through 2013 for a total cost of $240,000,with approximately half the total being spent in the final two years. The recognition ofthese obligations has resulted in a liability and associated asset of approximately $0.3million as of January 1, 2003, representing the present value of those future obligationsfor which we are able to make reasonable estimations of the current fair value due to, asdiscussed above, our ability to 

12

estimate the timing of the incurrence of the expenditures. Theremainder of our asset retirement obligations have not been recorded due to our inabilityto reasonably estimate when they will be settled in cash. We will record liabilities forthese obligations when we are able to reasonably estimate their fair value.

The facilities utilized in our power generation activities fall intotwo general categories: those that we own and those that we do not own. With respect tothose facilities that we do not own but either operate or maintain a preferred interestin, principally the Jackson, Michigan and Wrightsville, Arkansas power plants, we have noobligation for any asset retirement obligation that may exist or arise. With respect tothe Colorado power generation assets that we do own, we have no asset retirementobligation with respect to those facilities located on land that we also own, and nodirect responsibility for assets in which we own an interest accounted for under theequity method of accounting. Thus, our power generation activities do not give rise to anyasset retirement obligations.

We have not presented prior period information on a pro forma basis toreflect the implementation of SFAS No. 143 because the impact in total and on eachindividual period is immaterial. 

13.  Accounting forDerivative Instruments and Hedging Activities
Our normal business activities expose us to risks associated withchanges in the market price of natural gas and associated transportation. We engage inderivative transactions for the purpose of mitigating these risks, which transactions areaccounted for in accordance with SFAS No. 133, *Accounting for Derivative Instrumentsand Hedging Activities* and associated amendments. During the three months ended March31, 2003 and 2002, our derivative activities relating to the mitigation of these riskswere designated and qualified as cash flow hedges, and the impact of hedgeineffectiveness, while included in our net income, was immaterial. As the hedged sales andpurchases take place and we record them into earnings, we also reclassify the gains andlosses included in accumulated other comprehensive income into earnings. We expect toreclassify into earnings, during the next twelve months, substantially all of ouraccumulated other comprehensive loss balance related to these derivatives of $23.3million, representing unrecognized net losses on derivative activities at March 31, 2003.During the three months ended March 31, 2003 and 2002, we reclassified no gains or lossesinto earnings as a result of the discontinuance of cash flow hedges due to a determinationthat the forecasted transactions would no longer occur by the end of the originallyspecified time period. In addition, at March 31, 2003, our accumulated other comprehensiveloss included $5.9 million representing our pro rata share of the accumulated othercomprehensive loss of Kinder Morgan Energy Partners.

We have outstanding fixed-to-floating interest rate swap agreementswith a notional principal amount of $1.25 billion at March 31, 2003. These agreementseffectively converted the interest expense associated with our 7.25% Debentures due in2028 and our 6.50% Senior Notes due in 2012 from fixed rates to floating rates based onthe three-month London Interbank Offered Rate ("LIBOR") plus a credit spread.These swaps have been designated as fair value hedges and we have accounted for themutilizing the "shortcut" method prescribed for qualifying fair value hedgesunder SFAS No. 133. Accordingly, the carrying value of the swap is adjusted to its fairvalue as of the end of each reporting period, and an offsetting entry is made to adjustthe carrying value of the debt securities whose fair value is being hedged. The carryingvalue of the swaps at March 31, 2003 was $99.1 million (included in the caption"Deferred Charges and Other Assets" in the accompanying interim ConsolidatedBalance Sheet as of March 31, 2003). We record interest expense equal to the floating ratepayments, which is accrued monthly and paid semi-annually.

13

On March 3, 2003, we terminated the interest rate swap agreementsassociated with our 6.65% Senior Notes due in 2005 and received $28.1 million. We areamortizing this amount (reducing interest expense) over the remaining period the 6.65%Senior Notes are outstanding. The unamortized balance of $27.0 million at March 31, 2003is included in the caption "Interest Rate Swaps" under the heading"Long-term Debt" in the accompanying interim Consolidated Balance Sheet.

14.  Stock-BasedCompensation
SFAS No. 123, *Accounting for Stock-Based Compensation*,encourages, but does not require, entities to adopt the fair value method of accountingfor stock-based compensation plans. As allowed under SFAS No. 123, we continue to applyAccounting Principles Board Opinion No. 25, *Accounting for Stock Issued to Employees*.Accordingly, compensation expense is not recognized for stock options unless the optionsare granted at an exercise price lower than the market price on the grant date. Hadcompensation cost for these plans been determined consistent with SFAS No. 123, net incomeand diluted earnings per share would have been reduced to the pro forma amounts shown inthe table below. Because the SFAS No. 123 method of accounting has not been applied tooptions granted prior to January 1, 1995, the resulting pro forma compensation cost maynot be representative of that to be expected in future years. Additionally, the pro formaamounts include approximately $247,000 and $278,000 related to the purchase discountoffered under the employee stock purchase plan for the three months ended March 31, 2003and 2002, respectively. 
**Three Months Ended March 31, **2003**2002
(In thousands, except    per share amounts)Net Income, As Reported 
$  111,070 
$   88,388   Add: Stock-based Employee Compensation Expense         Included in Reported Net Income, Net of Related Tax Effects 
       240 
       223   Deduct: Total Stock-based Employee Compensation    Expense        Determined under Fair Value Method for All Awards,        Net of Related Tax Effects 
    (4,005)
   (4,192)Pro Forma 
$  107,305 
$   84,419 
========== 
==========   **Earnings Per Basic Share:**  As Reported 
$     0.91 
$     0.72 
========== 
==========   Pro Forma 
$     0.88 
$     0.68 
========== 
==========   **Earnings Per Diluted Share:**  As Reported 
$     0.90 
$     0.71 
========== 
==========   Pro Forma 
$     0.87 
$     0.68 
========== 
========== 
15.  Regulatory Matters
As a part of the settlement of litigation styled, *Jack J. Grynberg,individually and as general partner for the Greater Green River Basin Drilling Program:72-73 v. Rocky Mountain Natural Gas Company and K N Energy, Inc.*, Case No. 90-CV-3686,in early 2002, Mr. Grynberg received $16.825 million from us (including forgiveness of a$10.4 million obligation owing from Mr. Grynberg) and an additional $15.625 million waspaid into escrow. Rocky Mountain Natural Gas Company agreed to seek to recover theseamounts from its customers/rate payers in a proceeding before the Public UtilitiesCommission for the State of Colorado. Rocky Mountain Natural Gas Company and KinderMorgan, Inc. made regulatory filings with the Public Utilities Commission for the State ofColorado on September 30, 2002, proposing recovery of these amounts as part of theirannual Gas Cost Adjustment filing process. We proposed to collect these litigated gascosts, including associated carrying charges, over a 15-year amortization 

14

period. On October 30, 2002, the Public Utilities Commission for theState of Colorado decided, in open meeting, to allow us to place rates in effect and beginrecovery of these costs effective November 1, 2002, subject to refund pending a finaldetermination as to our ability to recover these costs in our rates. Mr. Grynberg willreceive the money in escrow only to the extent rates allowing us to collect this gas costare finally approved. The parties, including the Public Utilities Commission for the Stateof Colorado, are currently engaged in active settlement discussions. On April 25, 2003,the presiding administrative law judge issued an order vacating the existing proceduralschedule and hearing dates to allow more time for settlement discussions and directed thatany settlement agreement reached by the parties be filed on or before May 16, 2003. 

The Wyoming Choice Gas program, under which our customers are permittedto select their own supplier of natural gas, was reviewed by the Wyoming Public ServiceCommission to determine whether the existing program should continue and whether anyprogram modifications should be made. A hearing was conducted in February 2003 and adecision was issued on March 11, 2003, authorizing the Choice Gas program to continue withseveral modifications. The traditional regulated pass-on rate must continue to be offeredby us along with the Choice Gas program. Customers who do not return a Choice Gasselection form will default to the pass-on tariff rate. The $1 per month Choice Gascustomer charge will not be applied to pass-on tariff customers.

See Note 9 of Notes to Consolidated Financial Statements included inour 2002 Form 10-K for additional information regarding regulatory matters.

Currently, there are no material proceedings challenging the base rateson any of our pipeline systems. Nonetheless, shippers on our pipelines do have rights tochallenge the rates we charge under certain circumstances prescribed by applicablestatutes and regulations. There can be no assurance that we will not face challenges tothe rates we receive for services on our pipeline systems in the future. In addition,since many of our assets are subject to regulation, we are subject to potential futurechanges in applicable rules and regulations that may have an adverse effect on ourbusiness, cash flows, financial position or results of operations.

16.  Environmental andLegal Matters
(A)    Environmental Matters

We are subject to a variety of federal, state and local laws thatregulate permitted activities relating to air and water quality, waste disposal, and otherenvironmental matters. Additionally, we have established reserves to address knownenvironmental remediation sites. After consideration of reserves established, we believethat costs for environmental remediation and ongoing compliance with these regulationswill not have a material adverse effect on our cash flows, financial position or resultsof operations or diminish our ability to operate our businesses. However, there can be noassurances that future events, such as changes in existing laws, the promulgation of newlaws, or the development of new facts or conditions will not cause us to incur significantcosts.

See Note 10(A) of Notes to Consolidated Financial Statements includedin our 2002 Form 10-K for additional information regarding environmental matters.

(B)    Litigation Matters
*United States of America, ex rel., Jack J. Grynberg v. K N Energy, CivilAction No. 97-D-1233, filed in the U.S. District Court, District of Colorado. This actionwas filed on June 9, 1997 pursuant to the 

15

federal False Claims Act and involves allegations of mismeasurement ofnatural gas produced from federal and Indian lands. The Department of Justice has decidednot to intervene in support of the action. The complaint is part of a larger series ofsimilar complaints filed by Mr. Grynberg against 77 natural gas pipelines (approximately330 other defendants). An earlier single action making substantially similar allegationsagainst the pipeline industry was dismissed by Judge Hogan of the U.S. District Court forthe District of Columbia on grounds of improper joinder and lack of jurisdiction. As aresult, Mr. Grynberg filed individual complaints in various courts throughout the country.In 1999, these cases were consolidated by the Judicial Panel for Multidistrict Litigation,and transferred to the District of Wyoming. The MDL case is called *In Re Natural GasRoyalties Qui Tam Litigation*, Docket No. 1293. Motions to dismiss were filed and anoral argument on the motion to dismiss occurred on March 17, 2000. On July 20, 2000, theUnited States of America filed a motion to dismiss those claims by Grynberg that deal withthe manner in which defendants valued gas produced from federal leases (referred to asvaluation claims). Judge Downes denied the defendant's motion to dismiss on May 18, 2001.The United States' motion to dismiss most of the plaintiff's valuation claims has beengranted by the Court. Mr. Grynberg has appealed that dismissal to the 10thCircuit, which has requested briefing regarding its jurisdiction over that appeal.Discovery is now underway to determine issues related to the Court's subject matterjurisdiction, arising out of the False Claims Act.
*Will Price, et al. v. Gas Pipelines, et al., (*f/k/a QuinqueOperating Company et al. v. Gas Pipelines, et al.*), Stevens County, Kansas DistrictCourt, Case No. 99 C 30. In May 1999, three plaintiffs, Quinque Operating Company, TomBoles and Robert Ditto, filed a purported nationwide class action in the Stevens County,Kansas District Court against some 250 natural gas pipelines and many of their affiliates.The petition (recently amended) alleges a conspiracy to underpay royalties, taxes andproducer payments by the defendants' undermeasurement of the volume and heating content ofnatural gas produced from nonfederal lands for more than 25 years. The named plaintiffspurport to adequately represent the interests of unnamed plaintiffs in this action who arecomprised of the nation's gas producers, state taxing agencies and royalty, working andoverriding interest owners. The plaintiffs seek compensatory damages, along with statutorypenalties, treble damages, interest, costs and fees from the defendants, jointly andseverally. This action was originally filed on May 28, 1999 in Kansas State Court inStevens County, Kansas as a class action against approximately 245 pipeline companies andtheir affiliates, including certain Kinder Morgan entities. Subsequently, one of thedefendants removed the action to Kansas Federal District Court and the case was styled as *QuinqueOperating Company, et al. v. Gas Pipelines, et al.*, Case No. 99-1390-CM, United StatesDistrict Court for the District of Kansas. Thereafter, we filed a motion with the JudicialPanel for Multidistrict Litigation to consolidate this action for pretrial purposes withthe Grynberg False Claims Act cases, because of common factual questions. On April 10,2000, the MDL Panel ordered that this case be consolidated with the Grynberg False ClaimsAct cases. On January 12, 2001, the Federal District Court of Wyoming issued an oralruling remanding the case back to the State Court in Stevens County, Kansas. Thedefendants filed a motion to dismiss on grounds other than personal jurisdiction, whichwas denied by the Court in August 2002. The motion to dismiss for lack of personaljurisdiction of the nonresident defendants has been briefed and is awaiting decision.Merits discovery has been stayed. The current named plaintiffs are Will Price, Tom Boles,Cooper Clark Foundation and Stixon Petroleum, Inc. Quinque Operating Company has beendropped from the action as a named plaintiff. On April 10, 2003, the Court issued itsdecision denying plaintiffs' motion for class certification. Plaintiffs have indicatedthey will move the Court for permission to amend the complaint because of this ruling.
*K N Energy, Inc., et al. v. James P. Rode and Patrick R. McDonald,Case No. 99CV1239, filed in the District Court, Jefferson County, Division 8, Colorado.The case was filed on May 21, 1999. Defendants counterclaimed and filed third party claimsagainst several of our former officers and/or directors. Messrs. Rode and McDonald areformer principal shareholders of Interenergy Corporation. We acquired 

16

Interenergy on December 19, 1997 pursuant to a merger agreement datedAugust 25, 1997. Rode and McDonald allege that K N Energy committed securities fraud,common law fraud and negligent misrepresentation as well as breach of contract. Rode andMcDonald are seeking an unspecified amount of compensatory damages, greater than $2million, plus unspecified exemplary or punitive damages, attorney's fees and their costs.We filed a motion to dismiss, and on April 21, 2000, the Jefferson County District CourtJudge dismissed the case against the individuals and us with prejudice. On April 6, 2001,the Colorado Court of Appeals affirmed the dismissal. Rode and McDonald also filed afederal securities fraud action in the United States District Court for the District ofColorado on January 27, 2000 titled *James P. Rode and Patrick R. McDonald v. K NEnergy, Inc., et al*., Civil Action No. 00-N-190. This case initially raised theidentical state law claims contained in the counterclaim and third party complaint instate court. Rode and McDonald filed an amended complaint, which dropped the state-lawclaims. On June 20, 2000, the federal district court dismissed this complaint withprejudice. The district court's dismissal was subsequently affirmed by the Tenth CircuitCourt of Appeals on April 23, 2002. A third related class action case styled, *Adams vs.Kinder Morgan, Inc., et al*., Civil Action No. 00-M-516, in the United States DistrictCourt for the District of Colorado was served on us on April 10, 2000. As of this date noclass has been certified. On February 23, 2001, the federal district court dismissedseveral claims raised by the plaintiff, with prejudice, and dismissed the remainingclaims, without prejudice. On April 27, 2001, the Adams plaintiffs filed their secondamended complaint. On March 29, 2002, the court dismissed the Adams plaintiffs' secondamended complaint with prejudice. On May 2, 2002, the Adams plaintiffs appealed thedismissal. Briefing at the Tenth Circuit Court of Appeals is complete and oral argument onthe appeal was heard on January 13, 2003.
*Darrell Sargent d/b/a Double D Production v. Parker & Parsley GasProcessing Co., American Processing, L.P. and Cesell B. Cheatham, et al., Cause No.878, filed in the 100th Judicial District Court, Carson County, Texas. The plaintiff fileda purported class action suit in 1999 and amended its petition in late 2002 to assertclaims on behalf of over 1,000 producers who process gas through as many as ten gasprocessing plants formerly owned by American Processing, L.P. ("AmericanProcessing"), a former wholly owned subsidiary of Kinder Morgan, Inc. in Carson andGray counties and other surrounding Texas counties. Plaintiff claims that AmericanProcessing (and subsequently, ONEOK, which purchased American Processing  from us in2000) improperly allocated liquids and gas proceeds to the producers. In particular, amongother claims, the plaintiff challenges the accuracy of a computer model used at the plantsto allocate liquid and gas proceeds among the producers and processors. The petitionasserts claims for breach of contract and Natural Resources Code violations relating tothe period from 1994 to the present. To date, the plaintiff has not made a specificmonetary demand nor produced a specific calculation of alleged damages. Plaintiff hasalleged generally in the petition that damages are "not to exceed $200 million"plus attorney's fees, costs and interest. The defendants have filed a counterclaim foroverpayments made to producers.

Pioneer Natural Resources USA, Inc., formerly known as Parker &Parsley Gas Processing Company ("Parker & Parsley"), is a co-defendant.Parker & Parsley has claimed indemnity from American Processing based on its sale ofassets to American Processing on October 4, 1995. We have accepted indemnity and defensesubject to a reservation of rights pending resolution of the suit. The plaintiff has alsonamed ONEOK as a defendant. We and ONEOK are defending the case pursuant to an agreementwhereby ONEOK is responsible for any damages that may be attributable to the periodfollowing ONEOK's acquisition of American Processing from us in 2000.

The purported class has not been certified. The plaintiff filed amotion for pre-trial conference on class certification issues and sought to establish aschedule for class discovery. The defendants filed a motion to deny class certificationbecause of the plaintiff's delay in proceeding with the class action. On March 11, 2003,the Court ordered that the defendants' motion to deny class certification was premature.The 

17
*Court allowed class discovery to proceed. The defendants expect toassert additional objections to class certification. 

*Manna Petroleum Services, L.P., et al v. American Processing, L.P.and Cesell B. Cheatham, et al.,*Cause No. 31,485, filed in the 223rd Judicial DistrictCourt of Gray County, Texas. The plaintiff filed suit in late 1999 and alleges thatAmerican Processing (and subsequently ONEOK) improperly allocated liquids and gasproceeds. This suit, which was filed by the same attorney who represents the purportedclass in the *Sargent* case discussed above, involves similar allegations as thosepresented in *Sargent* except this suit is not styled as a class action. See thediscussion of *Sargent* above for further details. The defendants have filed acounterclaim for overpayments to the plaintiff. The parties are presently engaged in factdiscovery, with expert discovery and trial presently scheduled to occur in 2003.
*Energas Company, a Division of Atmos Energy Company v. ONEOK EnergyMarketing and Trading Company, L.P., et al., Cause No. 2001-516,386, filed in the 72ndDistrict Court of Lubbock County, Texas. The plaintiff is suing several ONEOK entities foralleged overcharges in connection with gas sales, transportation, and other services, andalleged misallocations and meter errors, in and around Lubbock, under three different gascontracts. While the petition is vague, it is broad enough to include claims for theperiod before and after March 1, 2000 when the assets in question were conveyed by us toONEOK. We and ONEOK are defending the case pursuant to an agreement whereby ONEOK isresponsible for any damages that may be attributable to the period following ONEOK'sacquisition of the assets in question. In an amended petition filed in mid-2002, theplaintiff alleged damages in excess of $12 million. The defendants have filed acounterclaim for offsetting damages and accounting corrections under the contracts withthe plaintiff. The parties are currently engaged in an informal dispute resolution processin an attempt to resolve their accounting and other differences. In the event this processdoes not resolve the claims, a scheduling order will be established for completion of factdiscovery and trial. We believe that the resolution of the plaintiff's claims will be foramounts substantially less than the amounts sought.

We believe that we have meritorious defenses to all lawsuits and legalproceedings in which we are defendants and will vigorously defend against them. Based onour evaluation of the above matters, and after consideration of reserves established, webelieve that the resolution of such matters will not have a material adverse effect on ourbusinesses, cash flows, financial position or results of operations.

In addition, we are a defendant in various lawsuits arising from theday-to-day operations of our businesses. Although no assurance can be given, we believe,based on our experiences to date, that the ultimate resolution of such items will not havea material adverse impact on our business, financial position or results of operations.

17.  Recent Accounting Pronouncements
In January 2003, The FASB issued Interpretation No. 46, *Consolidationof Variable Interest Entities*. This interpretation of Accounting Research Bulletin No.51, *Consolidated Financial Statements*, addresses consolidation by businessenterprises of variable interest entities (some, but not all, of which have been referredto as "special purpose entities") with certain defined characteristics. Oneprovision of the interpretation increases the minimum amount of third-party investmentrequired to support non-consolidation from 3% to 10%. Certain of the disclosure provisionscontained in the interpretation are effective for financial statements issued afterJanuary 31, 2003, all of the provisions are immediately applicable to variable interestentities created after January 31, 2003 and public entities with variable interests inentities created before February 1, 2003 are required to apply the provisions (other thanthe transition disclosure provisions) to that entity no later than the beginning of thefirst interim or annual 

18

reporting period beginning after June 15, 2003. The principal impact ofthis interpretation on us is that, upon implementation, we expect to begin consolidationof Triton Power Company LLC and its wholly owned subsidiary, Triton Power Michigan LLC,the lessee of the Jackson, Michigan power generation facility. We operate and have apreferred interest in Triton Power Company LLC, in which the common interest is owned byothers. Neither entity has debt but, as a result of this consolidation, we will includethe lease obligation on the Jackson plant in our consolidated financial statements. Weexpect to apply the provisions of the statement beginning with the third quarter of 2003and, at that time, the total remaining lease payments will be $553.5 million and will be$21.7 million, $20.3 million, $20.3 million, $20.4 million and $20.6 million for 2004through 2008, respectively. The difference between the earnings impact under consolidationand under the currently-applied cost method is not expected to be material. 

On April 30, 2003, the FASB issued SFAS No. 149, *Amendment ofStatement 133 on Derivative Instruments and Hedging Activities*. This Statement amendsand clarifies accounting for derivative instruments, including certain derivativeinstruments embedded in other contracts, and for hedging activities under SFAS No. 133.

The new guidance amends SFAS No. 133 for decisions made:
•
as part of the Derivatives Implementation    Group process that effectively required amendments to SFAS No. 133;
  •
in connection with other FASB projects    dealing with financial instruments; and
  •
regarding implementation issues raised in    relation to the application of the definition of a derivative, particularly regarding the    meaning of "underlying" and the characteristics of a derivative that contains    financing components.
The amendments set forth in SFAS No. 149 improve financial reporting byrequiring that contracts with comparable characteristics be accounted for similarly. Inparticular, this statement clarifies under what circumstances a contract with an initialnet investment meets the characteristic of a derivative as discussed in SFAS No. 133. Inaddition, it clarifies when a derivative contains a financing component that warrantsspecial reporting in the statement of cash flows. SFAS No. 149 amends certain otherexisting pronouncements. Those changes will result in more consistent reporting ofcontracts that are derivatives in their entirety or that contain embedded derivatives thatwarrant separate accounting. 

The statement is effective for contracts entered into or modified afterJune 30, 2003, except as stated below and for hedging relationships designated after June30, 2003. We will apply this guidance prospectively. We have not yet quantified theimpacts of adopting this statement on our financial position or results of operations.

The provisions of this statement that relate to SFAS No. 133implementation issues that have been effective for fiscal quarters that began prior toJune 15, 2003, should continue to be applied in accordance with their respective effectivedates. In addition, certain provisions relating to forward purchases or sales of"when-issued" securities or other securities that do not yet exist, should beapplied to existing contracts as well as new contracts entered into after June 30, 2003. 

19
***Item 2.  Management'sDiscussion and Analysis of Financial Condition and Results of Operations.*
General**
The following discussion should be read in conjunction with (i) theaccompanying interim Consolidated Financial Statements and related Notes and (ii) theConsolidated Financial Statements, related Notes and Management's Discussion and Analysisof Financial Condition and Results of Operations included in our 2002 Form 10-K. Due tothe seasonal variation in energy demand, among other factors, the following interimresults may not be indicative of the results to be expected over the course of an entireyear. In this report Kinder Morgan Energy Partners, L.P., a publicly traded pipelinemaster limited partnership in which we own the general partner interest and significantlimited partner interests, is referred to as "Kinder Morgan Energy Partners."
**Consolidated Financial Results****Three Months Ended March 31,**Increase**2003**2002**(Decrease)
(In thousands except per    share amounts)  Operating Revenues 
$  318,868 
$  291,401 
$   27,467 
========== 
========== 
========== Gross Margin1
$  205,913 
$  190,154 
$   15,759 
========== 
========== 
========== General and Administrative Expenses 
$   16,408 
$   19,550 
$   (3,142)
========== 
========== 
========== Operating Income 
$  122,805 
$  108,355 
$   14,450 Other Income and (Expenses) 
    59,079 
    43,711 
    15,368 Income Taxes 
    70,814 
    63,678 
     7,136 Net Income 
$  111,070 
$   88,388 
$   22,682 
========== 
========== 
==========   Diluted Earnings Per Common Share 
$     0.90 
$     0.71 
$     0.19 
========== 
========== 
========== 
1 Gross margin equals total operating revenues less gas purchasesand other costs of sales.

Net income increased from $88.4 million in the first quarter of 2002 to$111.1 million in the first quarter of 2003, an increase of $22.7 million (25.7%). Totaldiluted earnings per common share increased from $0.71 in the first quarter of 2002 to$0.90 in the first quarter of 2003, an increase of $0.19 (27%). Income was positivelyaffected in the first quarter of 2003, relative to 2002, primarily by (i) increased equityin earnings of Kinder Morgan Energy Partners due, in part, to the strong performance fromthe assets owned and/or operated by Kinder Morgan Energy Partners, (ii) increased earningsfrom our Natural Gas Pipeline Company of America and Kinder Morgan Retail businesssegments, (iii) increased earnings from our TransColorado business segment, which we beganoperating as 100% owner as of October 1, 2002, (iv) lower general and administrative costsdue, in part, to reduced legal expenses in the first quarter of 2003 and (v) a lowereffective tax rate in 2003. These positive impacts were partially offset by (i) decreasedearnings from our Power business segment and (ii) increased income tax expense due to theincreased pre-tax income. Please refer to the individual headings under "Results ofOperations" following for additional details regarding these matters. The number ofshares used to calculate diluted earnings per common share was approximately 1.8 million(1.4%) lower in the first quarter of 2003 than in the first quarter of 2002. The number ofshares used to calculate diluted earnings per common share was affected by, among otherthings, shares acquired under our share repurchase program, totaling 3.0 million shares in2002 and an additional 31,100 shares in the first three months of 2003. In addition,fluctuations in the market price of our stock affect the dilutive impact of ouroutstanding common stock options, which totaled approximately 1.2 million shares and 1.4million shares in the first quarters of 2003 and 2002, respectively.

20
**Results of Operations**
The following comparative discussion of our results of operations is bysegment for factors affecting segment earnings, and on a consolidated basis for otherfactors.

We manage our various businesses by, among other things, allocatingcapital and monitoring operating performance. This management process includes dividingthe company into business segments so that performance can be effectively monitored andreported for a limited number of discrete businesses. Currently, we manage and report ouroperations in the following business segments:
**Business Segment****Business Conducted****Referred to As:**  Natural Gas Pipeline Company of  America and certain affiliates The ownership and operation of a major interstate natural gas    pipeline and storage system      Natural Gas Pipeline Company of AmericaTransColorado Gas Transmission         Company The ownership and operation of an interstate natural gas    pipeline system in Colorado and New Mexico      TransColorado PipelineRetail Natural Gas Distribution The regulated sale and transportation of natural gas to    residential, commercial and industrial customers (including a small distribution system    currently being built-out in Hermosillo, Mexico) and the non-regulated sales of natural    gas to certain utility customers under the Choice Gas program      Kinder Morgan RetailPower Generation The operation and, in previous periods, construction of    natural gas-fired electric generation facilitiesPower
The accounting policies we apply in the generation of business segmentinformation are generally the same as those described in Note 1 of Notes to ConsolidatedFinancial Statements included in our 2002 Form 10-K, except that (i) certain items belowthe "Operating Income" line are either not allocated to business segments or arenot considered by management in its evaluation of business segment performance and (ii)equity in earnings of equity method investees, other than Kinder Morgan Energy Partnersand certain insignificant international investees, are included in segment results. Theseequity method earnings are included in "Other Income and (Expenses)" in ourConsolidated Statements of Operations. In addition, (i) certain items included inoperating income (such as general and administrative expenses) are not allocated toindividual business segments and (ii) gains and losses from incidental sales of assets areincluded in segment earnings. With adjustment for these items, we currently evaluatebusiness segment performance primarily based on operating income in relation to the levelof capital employed. We account for intersegment sales at market prices, while we accountfor asset transfers at either market value or, in some instances, book value.

21

Following are operating results by individual business segment (beforeintersegment eliminations), including explanations of significant variances between theperiods presented.
**Natural Gas Pipeline Company of America****Three Months Ended March 31,**2003**2002**Increase
(In thousands except systems    throughput)  Operating Revenues 
$214,068 
$183,089 
$ 30,979 
======== 
======== 
========   Gross Margin 
$144,511 
$139,977 
$  4,534 
======== 
======== 
========   Segment Earnings 
$100,076 
$ 95,618 
$  4,458 
======== 
======== 
========     Systems Throughput (Trillion Btus) 
   451.1 
   397.9 
    53.2 
======== 
======== 
======== 
Natural Gas Pipeline Company of America's segment earnings increased by$4.5 million (4.7%) from the first quarter of 2002 to the first quarter of 2003. Increasedgross margin was responsible for the increase as the first quarter of 2003 was positivelyaffected, relative to the first quarter of 2002 by (i)  the impact of expansion andextension projects coming on line since the end of the first quarter of last year asdiscussed below and (ii) increased 2003 operational sales of natural gas. Results belowthe gross margin level were affected by the largely offsetting impacts of (i) increasedexpenses related to the operations and maintenance of natural gas storage facilities and(ii) decreased taxes other than income. Although system throughput increased by 53.2trillion Btus or 13.4% from the first quarter of 2002 to the first quarter of 2003 due, inpart, to weather that was 3% colder than normal in this segment's market area, thisincrease did not have any significant direct impact on revenues due to the fact thattransportation revenues are derived primarily from "demand" contracts in whichshippers pay a fee to reserve a set amount of system capacity for their use.

Horizon Pipeline Company, a joint venture with Nicor Inc., whichprovides natural gas transportation capacity to the growing northern Illinois market,began service in the second quarter of 2002. Natural Gas Pipeline Company of America'slateral extension into the eastern portion of the St. Louis metropolitan area beganservice in the third quarter of 2002. During April 2003, Natural Gas Pipeline Company ofAmerica began construction of 10.7 Bcf of no-notice storage service expansion at theexisting North Lansing storage facility in east Texas, all of which is fully subscribedunder long-term contracts. Although construction on the $35.6 million project won't betotally completed until early 2004, the service is available at this time. Please refer toour 2002 Form 10-K for additional information regarding Natural Gas Pipeline Company ofAmerica.

22
**TransColorado Pipeline****Three Months Ended March 31,**2003**2002**Increase
(In thousands    except systems throughput)Total Operating Revenues1
$  9,499 
$      - 
$  9,499 
======== 
======== 
========   Gross Margin1
$  9,499 
$      - 
$  9,499 
======== 
======== 
========   Segment Earnings1
$  7,260 
$     93 
$  7,167 
======== 
======== 
========     Systems Throughput (Trillion Btus)2
    46.5 
    32.7 
    13.8 
======== 
======== 
======== 
1 Equity method in 2002, fully consolidated in 2003, see the textualdiscussion following.2 Representing 100% of pipeline throughput in each period.

TransColorado Pipeline's segment earnings increased from $93,000 in thefirst quarter of 2002 (representing a 50% equity method interest in earnings) to $7.3million in the first quarter of 2003 (representing fully consolidated results at the 100%ownership level). During the first quarter of 2002, TransColorado Pipeline was a jointventure in which we shared ownership equally with an affiliate of Questar Corp. Weacquired full ownership through a purchase of Questar's interest effective October 2002.Throughput on the system increased 13.8 Bcf or 42.2% from the first quarter of 2002 to thefirst quarter of 2003 as winter certificated capacity was sold out for the first time. Inaddition, these results reflect the favorable impact of wide basis differentials oncertain transportation contracts, which differentials may not remain as wide throughoutthe year. Looking forward, long-haul transportation capacity is fully subscribed into2004. Please refer to our 2002 Form 10-K for additional information regardingTransColorado Pipeline, including our previously announced plan for expansion of thesystem.
**Kinder Morgan Retail****Three Months Ended March 31,**Increase**2003**2002**(Decrease)
(In thousands except systems    throughput)  Total Operating Revenues 
$ 88,989 
$ 97,627 
$ (8,638)
======== 
======== 
========   Gross Margin 
$ 46,581 
$ 40,580 
$  6,001 
======== 
======== 
========   Segment Earnings 
$ 31,459 
$ 24,858 
$  6,601 
======== 
======== 
========     Systems Throughput (Trillion Btus)1
    17.4 
    13.5 
     3.9 
======== 
======== 
======== 
1 Excludes transport volumes of intrastate pipelines.

Kinder Morgan Retail's segment earnings increased from $24.9 million inthe first quarter of 2002 to $31.5 million in the first quarter of 2003, an increase of$6.6 million or 26.6 percent. Approximately $6.0 million of this increase came at thegross margin level as a result of (i) lower costs and higher margins in unregulatedbusinesses and customer growth in Colorado and (ii) a shift in timing of certain itemsaffecting gross margin between the first and fourth quarters of 2003, with each factoraccounting for approximately half of the quarter over quarter increase. System throughputincreased by 3.9 trillion 

23

Btus or 28.9 percent from the first quarter of 2002 to the firstquarter of 2003 largely due to the Colorado customer growth mentioned above and to colder2003 weather. Our weather hedging program continued to contribute to stability in ourearnings pattern.

Kinder Morgan Retail has two expansion projects underway in westernColorado that are expected to be drivers of future earnings growth. Please refer to our2002 Form 10-K for additional information regarding Kinder Morgan Retail.
**Power****Three Months Ended March 31,**2003**2002**(Decrease)
(In thousands)  Total Operating Revenues 
$  6,312 
$ 10,685 
$ (4,373)
======== 
======== 
========   Gross Margin 
$  5,322 
$  9,597 
$ (4,275)
======== 
======== 
========   Segment Earnings 
$  2,920 
$  9,740 
$ (6,820)
======== 
======== 
======== 
Power's segment earnings decreased from $9.7 million in the firstquarter of 2002 to $2.9 million in the first quarter of 2003, a decrease of $6.8 millionor 70.0 percent, principally resulting from a decline in fees from development of naturalgas-fired electric plants. This decrease was significant, but expected, as it reflects ourpreviously announced and implemented decision to exit the power plant developmentbusiness. We currently retain interests in five natural gas-fired power plants. Pleaserefer to our 2002 Form 10-K for additional information regarding Power.
**Other Income and (Expenses)****Three Months Ended March 31,**Earnings**2003**2002**Increase    (Decrease)
(In thousands)  Interest Expense, Net 
$(39,974)
$(39,548)
$   (426)Equity in Earnings of Kinder Morgan Energy Partners 
 111,495 
  90,091 
  21,404 Equity in Earnings of Power Segment1
   2,173 
   2,311 
    (138)Equity in Earnings of Horizon Pipeline2
     329 
       - 
     329 Equity in Earnings of TransColorado Pipeline3
       - 
      93 
     (93)Equity in Losses of Other Equity Investments 
     (19)
     (32)
      13 Minority Interests 
 (15,921)
 (12,777)
  (3,144)Other, Net 
     996 
   3,573 
  (2,577)    
$ 59,079 
$ 43,711 
$ 15,368 
======== 
======== 
========   1 Included in Power segment earnings.2 Included in Natural Gas Pipeline Company of America segment earnings.3 Included in TransColorado Pipeline segment earnings.
"Other Income and (Expenses)" was a net increase to earningsof $59.1 million and $43.7 million in the first quarter of 2003 and 2002, respectively.This positive variance of $15.4 million is principally due to an increase of $21.4 millionin equity in earnings of Kinder Morgan Energy Partners. This increase was partially offsetby (i) an increase of $3.1 million in expense due to minority interest in the firstquarter of 2003, due principally to additional minority interest in Kinder MorganManagement, LLC, and (ii) a 

24
**decrease of $2.6 million in other income, principally due tothe inclusion, in first quarter 2002 results, of a $2.6 million gain on the sale ofcertain assets.****
**Income Taxes**

The increase of $7.1 million in the income tax provision for the firstquarter of 2003, relative to the first quarter of 2002, consisted of an increase of $12.5million resulting from an increase in pretax income, partially offset by a decrease of$5.4 million reflecting a reduction in the effective tax rate, largely due to a reducedprovision for state income taxes.
**Discontinued Operations**
During 1999, we adopted and implemented a plan to discontinue a numberof lines of business. During 2000, we essentially completed the disposition of thesediscontinued operations. The cash flow impacts associated with discontinued operations arediscussed under "Cash Flows" following. Note 8 of the accompanying Notes toConsolidated Financial Statements contains additional information on these matters.
**Liquidity and Capital Resources**
The following table gives the sources of our invested capital. Thebalances at December 31, 2001 reflect the May 2001 sale of shares of Kinder MorganManagement, LLC in its initial public offering. The balances at December 31, 2002 alsoreflect the impact of Kinder Morgan Management's August 2002 public sale of its shares. Inaddition to our results of operations, which affect the amount of cash we generateinternally, financing activities such as (i) retirement of debt securities, (ii) theNovember 2001 maturity of our premium equity participating security units and (iii)reacquisition of our common stock under our stock repurchase program impact these balancesin various periods. Additional information on these matters is contained under "CashFlows" following and in Note 10 of the accompanying Notes to Consolidated FinancialStatements.

The discussion under the heading "Liquidity and CapitalResources" in Management's Discussion and Analysis of Financial Condition and Resultsof Operations included in our 2002 Form 10-K includes a comprehensive discussion of (i)our investments in and obligations to unconsolidated entities, (ii) our contractualobligations and (iii) our contingent liabilities. These disclosures, which reflectedbalances and contractual arrangements existing as of December 31, 2002, also reflectcurrent balances and contractual arrangements except for changes discussed following.Changes in our long-term debt and commercial paper are discussed under "Net CashFlows from Financing Activities" following and in Note 9 of the accompanying Notes toConsolidated Financial Statements.

25
  **March 31,**December 31,**2003**2002**2001**2000
(Dollars in thousands)Long-term Debt:     Outstanding 
$2,851,917 
$2,852,181 
$2,409,798 
$2,478,983      Interest Rate Swaps1
   126,076 
   139,589 
    (4,831)
         - 
2,977,993 
2,991,770 
2,404,967 
2,478,983 Minority Interests 
   975,587 
   967,802 
   817,513 
     4,910 Common Equity 
 2,452,429 
 2,354,997 
 2,259,997 
 1,777,624 Capital Securities 
   275,000 
   275,000 
   275,000 
   275,000 
 6,681,009 
 6,589,569 
 5,757,477 
 4,536,517 Less Interest Rate Swaps 
  (126,076)
  (139,589)
     4,831 
         -      Capitalization 
 6,554,933 
 6,449,980 
 5,762,308 
 4,536,517 Short-term Debt, Less Cash and Cash Equivalents2
   303,702 
   465,614 
   613,918 
   766,244      Invested Capital 
$6,858,635 
$6,915,594 
$6,376,226 
$5,302,761 
========== 
========== 
========== 
==========   Capitalization:     Outstanding Long-term Debt 
43.5%
44.2%
41.8%
54.6%     Minority Interests 
14.9%
15.0%
14.2%
 0.1%     Common Equity 
37.4%
36.5%
39.2%
39.2%     Capital Securities 
 4.2%
 4.3%
 4.8%
 6.1%  Invested Capital:     Total Debt (Excluding    Interest Rate Swaps) 
46.0%
48.0%
47.4%
61.2%     Equity, Including Capital    Securities and Minority           Interests 
54.0%
52.0%
52.6%
38.8%    1See Note 13 of the accompanying Notes to Consolidated    Financial Statements.2
Cash and cash equivalents netted against    short-term debt were $29,465, $35,653, $16,134 and $141,923 for March 31, 2003 and    December 31, 2002, 2001 and 2000, respectively.
A number of our customers are experiencing severe financial problemsthat have had a significant impact on their creditworthiness. We are working to implement,to the extent allowable under applicable laws and regulations, prepayments and othersecurity requirements such as letters of credit to enhance our credit position relating toamounts owed from these customers. We cannot assure that one or more of our financiallydistressed customers will not default on their obligations to us or that such a default ordefaults will not have a material adverse effect on our business.

On August 14, 2001, we announced a program to repurchase up to $300million of our outstanding common stock, which program was increased to $400 million and$450 million at February 5, 2002 and July 17, 2002, respectively. As of March 31, 2003, wehad repurchased a total of approximately $416.1 million (8,339,300 shares) of ouroutstanding common stock under the program, of which $1.4 million (31,100 shares) wererepurchased in the three months ended March 31, 2003.

On February 14, 2003, Kinder Morgan Management paid a sharedistribution of 858,981 of its shares to shareholders of record as of January 31, 2003,based on the $0.625 per common unit distribution declared by Kinder Morgan EnergyPartners. On May 15, 2003, Kinder Morgan Management will make a distribution totaling859,933 of its shares to shareholders of record as of April 30, 2003, based on the $0.64per common unit distribution declared by Kinder Morgan Energy Partners. Thesedistributions are paid in the form of additional shares or fractions thereof calculated bydividing the Kinder Morgan Energy Partners' cash distribution per common unit by theaverage market price of a Kinder Morgan 

26

Management share determined for a ten-trading day period ending on thetrading day immediately prior to the ex-dividend date for the shares.

CASH FLOWS

The following discussion of cash flows should be read in conjunctionwith the accompanying interim Consolidated Statements of Cash Flows and relatedsupplemental disclosures, and the Consolidated Statements of Cash Flows and relatedsupplemental disclosures included in our 2002 Form 10-K.

Net Cash Flows from Operating Activities

"Net Cash Flows Provided by Operating Activities" increasedfrom $100.3 million in the first quarter 2002 to $159.7 million in the first quarter 2003,an increase of $59.4 million (59.3%). This positive variance is principally due to (i) a$16.6 million increase in cash distributions received in 2003 attributable to our interestin Kinder Morgan Energy Partners, (ii) $28.1 million of cash proceeds received fromtermination of an interest rate swap (See Note 13 of the accompanying Notes toConsolidated Financial Statements for further information regarding this transaction) and(iii) an increase of $24.9 million in cash inflows for gas in underground storage during2003. Significant period-to-period variations in cash used or generated from gas instorage transactions are due to changes in injection and withdrawal volumes as well asfluctuations in natural gas prices. These positive impacts were partially offset by anincrease of $9.2 million for interest payments during 2003.

Net Cash Flows from Investing Activities

"Net Cash Flows Used in Investing Activities" decreased from$61.1 million in the first quarter 2002 to $24.8 million in the first quarter 2003, adecrease of $36.3 million (59.4%). This decreased use of cash is principally due to thefact that the first quarter of 2002 included (i) $6.8 million in capital expenditures forthe Natural Gas Pipeline Company of America pipeline extension to East St. Louis, Illinoisand (ii) a $23.9 million cash outflow for incremental investments in power plantfacilities. 

Net Cash Flows from Financing Activities

"Net Cash Flows Used in Financing Activities" increased from$43.6 million in the first quarter 2002 to $141.1 million in the first quarter 2003, anincrease of $97.5 million. This increase is principally due to $500 million of cash usedin the first quarter of 2003 to retire our $500 million 6.45% Senior Notes and an increaseof $12.1 million paid in 2003 for dividends, principally due to the increased dividendsdeclared per share. Partially offsetting these factors were (i) an increase in netshort-term borrowings during 2003 of $193.9 million, (ii) a $91.3 decrease of cash usedduring 2003 to repurchase shares and (iii) a $130.6 million increased source of cash fromshort-term advances to unconsolidated affiliates during 2003.

Our principal sources of short-term liquidity are the commercial papermarket and our $800 million of revolving bank facilities, which replaced $900 million ofrevolving bank facilities on October 15, 2002. At March 31, 2003, we had $331.9 million ofcommercial paper (which is backed by the bank facilities) issued and outstanding. At May1, 2003, we had $269.6 million of commercial paper issued and outstanding. After inclusionof applicable letters of credit, the remaining available borrowing capacity under the bankfacilities was $414.4 million and $474.1 million at March 31, 2003 and May 1, 2003,respectively. For additional information on utilization of these facilities, see Note 9 ofthe accompanying Notes to Consolidated Financial Statements.

27

On March 3, 2003, our $500 million 6.45% Senior Notes matured and wepaid the holders of the notes.

Apart from our current maturities of long-term debt and commercialpaper outstanding, our current assets exceeded our current liabilities by approximately$18.0 million at March 31, 2003. 

As further described in Note 13 of the accompanying Notes toConsolidated Financial Statements, we have outstanding fixed-to-floating interest rateswap agreements with a notional principal amount of $1.25 billion and a fair market valueof approximately $99.1 million at March 31, 2003. These swaps are accounted for as hedgesunder Statement of Financial Accounting Standards ("SFAS") No. 133, *Accountingfor Derivative Instruments and Hedging Activities*.
**Recent Accounting Pronouncements**
In January 2003, The FASB issued Interpretation No. 46, *Consolidationof Variable Interest Entities*. This interpretation of Accounting Research Bulletin No.51, *Consolidated Financial Statements*, addresses consolidation by businessenterprises of variable interest entities (some, but not all, of which have been referredto as "special purpose entities") with certain defined characteristics. Oneprovision of the interpretation increases the minimum amount of third-party investmentrequired to support non-consolidation from 3% to 10%. Certain of the disclosure provisionscontained in the interpretation are effective for financial statements issued afterJanuary 31, 2003, all of the provisions are immediately applicable to variable interestentities created after January 31, 2003 and public entities with variable interests inentities created before February 1, 2003 are required to apply the provisions (other thanthe transition disclosure provisions) to that entity no later than the beginning of thefirst interim or annual reporting period beginning after June 15, 2003. The principalimpact of this interpretation on us is that, upon implementation, we expect to beginconsolidation of Triton Power Company LLC and its wholly owned subsidiary, Triton PowerMichigan LLC, the lessee of the Jackson, Michigan power generation facility. We operateand have a preferred interest in Triton Power Company LLC, in which the common interest isowned by others. Neither entity has debt but, as a result of this consolidation, we willinclude the lease obligation on the Jackson plant in our consolidated financialstatements. We expect to apply the provisions of the statement beginning with the thirdquarter of 2003 and, at that time, the total remaining lease payments will be $553.5million and will be $21.7 million, $20.3 million, $20.3 million, $20.4 million and $20.6million for 2004 through 2008, respectively. The difference between the earnings impactunder consolidation and under the currently-applied cost method is not expected to bematerial. 

On April 30, 2003, the FASB issued SFAS No. 149, *Amendment ofStatement 133 on Derivative Instruments and Hedging Activities*. This Statement amendsand clarifies accounting for derivative instruments, including certain derivativeinstruments embedded in other contracts, and for hedging activities under SFAS No. 133.

The new guidance amends SFAS No. 133 for decisions made:
•
as part of the Derivatives Implementation    Group process that effectively required amendments to SFAS No. 133;
  •
in connection with other FASB projects    dealing with financial instruments; and
  •
regarding implementation issues raised in    relation to the application of the definition of a derivative, particularly regarding the    meaning of "underlying" and the characteristics of a derivative that contains    financing components.
28

The amendments set forth in SFAS No. 149 improve financial reporting byrequiring that contracts with comparable characteristics be accounted for similarly. Inparticular, this statement clarifies under what circumstances a contract with an initialnet investment meets the characteristic of a derivative as discussed in SFAS No. 133. Inaddition, it clarifies when a derivative contains a financing component that warrantsspecial reporting in the statement of cash flows. SFAS No. 149 amends certain otherexisting pronouncements. Those changes will result in more consistent reporting ofcontracts that are derivatives in their entirety or that contain embedded derivatives thatwarrant separate accounting. 

The statement is effective for contracts entered into or modified afterJune 30, 2003, except as stated below and for hedging relationships designated after June30, 2003. We will apply this guidance prospectively. We have not yet quantified theimpacts of adopting this statement on our financial position or results of operations.

The provisions of this statement that relate to SFAS No. 133implementation issues that have been effective for fiscal quarters that began prior toJune 15, 2003, should continue to be applied in accordance with their respective effectivedates. In addition, certain provisions relating to forward purchases or sales of"when-issued" securities or other securities that do not yet exist, should beapplied to existing contracts as well as new contracts entered into after June 30, 2003. 
**Information Regarding Forward-looking Statements**
This filing includes forward-looking statements within the meaning ofSection 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Actof 1934. These forward-looking statements are identified as any statement that does notrelate strictly to historical or current facts. They use words such as"anticipate," "believe," "intend," "plan,""projection," "forecast," "strategy," "position,""continue," "estimate," "expect," "may,""will," or the negative of those terms or other variations of them or bycomparable terminology. In particular, statements, express or implied, concerning futureactions, conditions or events, operating results or the ability to generate sales, incomeor cash flow or to pay dividends are forward-looking statements. Forward-lookingstatements are not guarantees of performance. They involve risks, uncertainties andassumptions. Future actions, conditions or events and future results of operations maydiffer materially from those expressed in these forward-looking statements. Many of thefactors that will determine these results are beyond our ability to control or predict.Specific factors which could cause actual results to differ from those in theforward-looking statements include but are not limited to the following:
    •
price trends, stability and    overall demand for natural gas and electricity in the United States;       •
economic activity, weather,    alternative energy sources, conservation and technological advances that may affect price    trends and demand;      •
changes in our tariff rates    or those of Kinder Morgan Energy Partners implemented by the FERC or another regulatory    agency or, with respect to Kinder Morgan Energy Partners, the California Public Utilities    Commission;      •
Kinder Morgan Energy    Partners' ability to integrate any acquired operations into its existing operations;      •
Kinder Morgan Energy    Partners' ability and our ability to acquire new businesses and assets and to make    expansions to our respective facilities;  
29

        •
difficulties or delays    experienced by railroads, barges, trucks, ships or pipelines in delivering products to    Kinder Morgan Energy Partners' bulk terminals;
        •
Kinder Morgan Energy Partners'    ability and our ability to successfully identify and close acquisitions and make    cost-saving changes in operations;
        •
shut-downs or cutbacks at    major refineries, petrochemical or chemical plants, utilities, military bases or other    businesses that use or supply our services;
        •
changes in laws or    regulations, third party relations and approvals, decisions of courts, regulators and    governmental bodies may adversely affect our business or our ability to compete;
        •
our ability to offer and sell    equity securities and debt securities or obtain debt financing in sufficient amounts to    implement that portion of our business plan that contemplates growth through acquisitions    of operating businesses and assets and expansions of our facilities;
      •
our indebtedness could make us    vulnerable to general adverse economic and industry conditions, limit our ability to    borrow additional funds and/or place us at competitive disadvantages compared to our    competitors that have less debt or have other adverse consequences;
      •
interruptions of electric    power supply to facilities due to natural disasters, power shortages, strikes, riots,    terrorism, war or other causes;
      •
acts of nature, sabotage,    terrorism or other similar acts causing damage greater than our insurance coverage limits;
      •
the condition of the capital    markets and equity markets in the United States;
      •
the political and economic    stability of the oil producing nations of the world;      •
national, international,    regional and local economic, competitive and regulatory conditions and developments;
        •
the ability to achieve cost    savings and revenue growth;      •
rates of inflation;
        •
interest rates;
      •
the pace of deregulation of retail natural    gas and electricity;
        •
the timing and extent of changes in    commodity prices for oil, natural gas, electricity and certain agricultural products; and
      •the timing and success of business development efforts.
  
You should not put undue reliance on any forward-looking statements.

See Items 1 and 2 "Business and Properties - Risk Factors" ofour annual report filed on Form 10-K for the year ended December 31, 2002, for a moredetailed description of these and other factors that may affect the forward-lookingstatements. When considering forward-looking statements, one should keep in mind the riskfactors described in our 2002 Form 10-K report. The risk factors could cause our actual

30

results to differ materially from those contained in anyforward-looking statement. We disclaim any obligation to update the above list or toannounce publicly the result of any revisions to any of the forward-looking statements toreflect future events or developments. Our future results also could be adversely impactedby unfavorable results of litigation and the coming to fruition of contingenciesreferred to in Notes 15 and 16 of the accompanying Notes to Consolidated FinancialStatements.
***Item3.  Quantitative and Qualitative Disclosures about Market Risk.***
There have been no material changes in market risk exposures that wouldaffect the quantitative and qualitative disclosures presented as of December 31, 2002, inthe "Risk Management" section of Management's Discussion and Analysis ofFinancial Condition and Results of Operations contained in our 2002 Form 10-K. See alsoNote 13 of the accompanying Notes to Consolidated Financial Statements.
***Item4.  Controls and Procedures.***
Within the 90-day period prior to the filing of this report, we carriedout an evaluation under the supervision and with the participation of our management,including our Chief Executive Officer and Chief Financial Officer, of the effectiveness ofthe design and operation of our disclosure controls and procedures pursuant to Rule13a-14(c) under the Securities Exchange Act of 1934. Based upon that evaluation, our ChiefExecutive Officer and Chief Financial Officer concluded that the design and operation ofour disclosure controls and procedures were effective. No significant changes were made inour internal controls or in other factors that could significantly affect these disclosurecontrols and procedures subsequent to the date of their evaluation.

31
**PART II - OTHER INFORMATION
*Item 1.  Legal Proceedings.***
The reader is directed to Note 16 of the accompanying Notes toConsolidated Financial Statements in Part I, Item 1, which is incorporated herein byreference.***Item2.  Changes in Securities and Use of Proceeds.***
During the quarter ended March 31, 2003, we did not sell any equitysecurities that were not registered under the Securities Act of 1933, as amended.
***Item3.  Defaults Upon Senior Securities.***
None.
***Item4.  Submission of Matters to a Vote of Security Holders.***
None.
***Item 5.  Other Information.***
None.
***Item6.  Exhibits and Reports on Form 8-K.*****  ****(A)     Exhibits.      99.1          99.2       Certification of Chief Executive Officer          Certification of Chief Financial Officer**  ****  ****(B)     Reports on Form 8-K.****  ****  ****(1)**Current Report on Form 8-K dated    January 15, 2003 was furnished as of January 16, 2003 pursuant to Item 7. and Item 9. of    that form.**  ****  
Pursuant to Item 9. of that form, we disclosed that on    January 15, 2003 we issued a press release.    Pursuant to Item 7. of that form, we filed our press release issued January 15, 2003 as an    exhibit.**  ****  ****(2)**Current Report on Form 8-K dated    January 21, 2003 was furnished as of January 21, 2003 pursuant to Item 9. of that form.**  ****  
We announced our intention to make presentations on    January 22, 2003 at the Kinder Morgan 2003 Analyst Conference to investors, analysts and    others to address the fiscal year 2002 results, the fiscal year 2003 outlook and other    business information about us, Kinder Morgan Energy Partners, L.P. and Kinder Morgan    Management, LLC, and the availability of materials to be presented at the meetings on our    website and the ability of interested parties to access the presentations by audio    webcast, both live and on-demand.
32
**  ****  ****(3)**Current Report on Form 8-K dated April    1, 2003 was furnished as of April 1, 2003 pursuant to Item 9. of that form.**  ****  
We announced our intention to make presentations on    April 1, 2003 at the 31st Annual Howard Weil Energy Conference to address our    strategy and philosophy, the fiscal year 2003 budget and other business information about    us, Kinder Morgan Energy Partners, L.P. and Kinder Morgan Management, LLC, and the    availability of materials to be presented at the meetings on our website.**  ****  ****(4)**Current Report on Form 8-K dated April    16, 2003 was furnished as of April 23, 2003 pursuant to Item 7., Item 9. and Item 12. of    that form.**  ****  
Pursuant to Item 9. of that form (information provided    under Item 12.), we disclosed that on April 16, 2003 we issued a press release regarding    our financial results for the quarter ended March 31, 2003 and held a webcast conference    call discussing those results.

Pursuant to Item 7. of that form, we filed our press release issued    April 16, 2003 and an unedited transcript of the webcast conference call, prepared by an    outside vendor, as exhibits.
33
**SIGNATURE**
Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant hasduly caused this report to be signed on its behalf by the undersigned thereunto dulyauthorized.  
  KINDER MORGAN, INC.    (Registrant)            May 14, 2003/s/ C. Park ShaperC. Park Shaper    Vice President, Treasurer and Chief Financial Officer    (Principal Financial and Accounting Officer)
 

34

**CERTIFICATIONS**I, Richard D. Kinder, certify    that:      1.      I have reviewed this quarterly report on Form 10-Q of Kinder Morgan, Inc.;      2.
      Based on my knowledge, this quarterly report does not contain any untrue statement of a    material fact or omit to state a material fact necessary to make the statements made, in    light of the circumstances under which such statements were made, not misleading with    respect to the period covered by this quarterly report;      3.
      Based on my knowledge, the financial statements, and other financial information included    in this quarterly report, fairly present in all material respects the financial condition,    results of operations and cash flows of the registrant as of, and for, the periods    presented in this quarterly report;      4.
      The registrant's other certifying officer and I are responsible for establishing and    maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14    and 15d-14) for the registrant and we have:    a)
designed such disclosure    controls and procedures to ensure that material information relating to the registrant,    including its consolidated subsidiaries, is made known to us by others within those    entities, particularly during the period in which this quarterly report is being prepared;        b)
      evaluated the effectiveness of the registrant's disclosure controls and procedures as of a    date within 90 days prior to the filing date of this quarterly report (the    "Evaluation Date"); and        c)
      presented in this quarterly report our conclusions about the effectiveness of the    disclosure controls and procedures based on our evaluation as of the Evaluation Date;  5.
The registrant's other    certifying officer and I have disclosed, based on our most recent evaluation, to the    registrant's auditors and the audit committee of registrant's board of directors (or    persons performing the equivalent function):    a)
all significant    deficiencies in the design or operation of internal controls which could adversely affect    the registrant's ability to record, process, summarize and report financial data and have    identified for the registrant's auditors any material weaknesses in internal controls; and        b)
      any fraud, whether or not material, that involves management or other employees who have a    significant role in the registrant's internal controls; and  6.
The registrant's other certifying    officer and I have indicated in this quarterly report whether or not there were    significant changes in internal controls or in other factors that could significantly    affect internal controls subsequent to the date of our most recent evaluation, including    any corrective actions with regard to significant deficiencies and material weaknesses.
  
/s/ Richard D.    KinderRichard D. Kinder    Chairman and Chief Executive Officer
Date:  May 14, 2003
35
I, C. Park Shaper, certify that:      1.      I have reviewed this quarterly report on Form 10-Q of Kinder Morgan, Inc.;      2.
      Based on my knowledge, this quarterly report does not contain any untrue statement of a    material fact or omit to state a material fact necessary to make the statements made, in    light of the circumstances under which such statements were made, not misleading with    respect to the period covered by this quarterly report;      3.
      Based on my knowledge, the financial statements, and other financial information included    in this quarterly report, fairly present in all material respects the financial condition,    results of operations and cash flows of the registrant as of, and for, the periods    presented in this quarterly report;      4.
      The registrant's other certifying officer and I are responsible for establishing and    maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14    and 15d-14) for the registrant and we have:    a)
designed such disclosure    controls and procedures to ensure that material information relating to the registrant,    including its consolidated subsidiaries, is made known to us by others within those    entities, particularly during the period in which this quarterly report is being prepared;        b)
      evaluated the effectiveness of the registrant's disclosure controls and procedures as of a    date within 90 days prior to the filing date of this quarterly report (the    "Evaluation Date"); and        c)
      presented in this quarterly report our conclusions about the effectiveness of the    disclosure controls and procedures based on our evaluation as of the Evaluation Date;  5.
The registrant's other    certifying officer and I have disclosed, based on our most recent evaluation, to the    registrant's auditors and the audit committee of registrant's board of directors (or    persons performing the equivalent function):  a)
all significant    deficiencies in the design or operation of internal controls which could adversely affect    the registrant's ability to record, process, summarize and report financial data and have    identified for the registrant's auditors any material weaknesses in internal controls; and      b)
      any fraud, whether or not material, that involves management or other employees who have a    significant role in the registrant's internal controls; and  6.
The registrant's other    certifying officer and I have indicated in this quarterly report whether or not there were    significant changes in internal controls or in other factors that could significantly    affect internal controls subsequent to the date of our most recent evaluation, including    any corrective actions with regard to significant deficiencies and material weaknesses.  /s/ C. Park    ShaperC. Park Shaper    Vice President, Treasurer and Chief Financial Officer
Date:  May 14, 2003
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