Table of Contents

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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**June 30, 2003**or

o  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 o

Indicate by check mark whether the registrant is an accelerated filer(as defined in Rule 12b-2 of the Exchange Act).

Yes x   No o

The number of shares outstanding of the registrant's common stock, $5par value, as of July 31, 2003 was 123,291,645 shares.

KINDER MORGAN, INC. AND SUBSIDIARIESFORM 10-QQUARTER ENDED JUNE 30, 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 
7-26  Item 2.
Management's Discussion and Analysis of    Financial
   Condition and Results    of Operations 
27-42  Item 3.
Quantitative and Qualitative    Disclosures About Market Risk 
42  Item 4.
Controls and Procedures 
42  PART II.
OTHER INFORMATION  Item 1.
Legal Proceedings 
43  Item 2.
Changes in Securities and Use of    Proceeds 
43  Item 3.
Defaults Upon Senior Securities 
43  Item 4.
Submission of Matters to a Vote of    Security Holders 
43-44  Item 5.
Other Information 
44  Item 6.
Exhibits and Reports on Form 8-K 
45  SIGNATURE 
46
2
**PART I. - FINANCIAL INFORMATION
*Item 1.  Financial Statements.*
CONSOLIDATED BALANCE SHEETS (Unaudited)Kinder Morgan, Inc. and Subsidiaries****June 30,**December 31,**2003**2002
(In    thousands)**ASSETS:****Current Assets:**Cash and Cash Equivalents 
$    29,932 
$    35,653 Restricted Deposits 
      2,047 
      2,783 Accounts Receivable, Net:   Trade 
     58,496 
     82,258    Related Parties 
      1,324 
     48,054 Inventories 
     27,248 
     62,760 Gas Imbalances 
     50,043 
     32,033 Other 
    143,606 
    157,454 
    312,696 
    420,995    **Investments:**Kinder Morgan Energy Partners 
  2,089,443 
  2,034,160 Goodwill 
    969,443 
    990,878 Other 
    291,180 
    285,883 
  3,350,066 
  3,310,921    **Property, Plant and Equipment**
  6,548,167 
  6,544,418 **Less Accumulated Depreciation and    Amortization**
   (546,409)
   (496,311)
  6,001,758 
  6,048,107 **  ****Deferred Charges and Other Assets**
    298,503 
    322,727   **Total Assets**
$ 9,963,023 
$10,102,750 
=========== 
=========== 
The accompanying notes are an integral part of these statements.

3
**CONSOLIDATED BALANCE SHEETS (Unaudited)Kinder Morgan, Inc. and Subsidiaries****June 30,**December 31,**2003**2002
(In thousands    except shares)**LIABILITIES AND STOCKHOLDERS' EQUITY:****Current Liabilities:**Current Maturities of Long-term Debt 
$         - 
$   501,267 Notes Payable 
    221,500 
          - Accounts Payable:   Trade 
     32,485 
     88,227    Related Parties 
      2,657 
         50 Accrued Interest 
     68,539 
     80,158 Accrued Expenses 
     31,483 
     49,580 Accrued Taxes 
     34,568 
     27,355 Gas Imbalances 
     41,225 
     50,394 Other 
     69,505 
     69,501 
    501,962 
    866,532 **  ****Other Liabilities and Deferred Credits:**Deferred Income Taxes 
  2,485,964 
  2,435,780 Other 
    147,975 
    210,869 
  2,633,939 
  2,646,649   **Long-term Debt:**  Outstanding 
  2,842,440 
  2,852,181   Value of Interest Rate Swaps 
    185,623 
    139,589   
  3,028,063 
  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**
    983,346 
    967,802   **Stockholders' Equity:**Common Stock-  Authorized - 150,000,000    Shares, Par Value $5 Per Share  Outstanding - 130,852,688 and    129,861,650 Shares,    Respectively,    Before Deducting 8,260,375 and 8,168,241    Shares Held in    Treasury 
    654,263 
    649,308 Additional Paid-in Capital 
  1,698,253 
  1,681,042 Retained Earnings 
    654,718 
    486,062 Treasury Stock 
   (410,999)
   (406,630)Deferred Compensation 
     (8,214)
    (10,066)Accumulated Other Comprehensive Loss 
    (47,308)
    (44,719)Total Stockholders' Equity 
  2,540,713 
  2,354,997   **Total Liabilities and Stockholders'    Equity**
$ 9,963,023 
$10,102,750 
=========== 
=========== 
The accompanying notes are an integral part of these statements.

4
**CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited)Kinder Morgan, Inc. and Subsidiaries****Three Months Ended June 30,**Six Months Ended June 30,**2003**2002**2003**2002
(In thousands    except per share amounts)**Operating Revenues:**Natural Gas Transportation and Storage 
$ 162,974 
$ 143,410 
$ 345,827 
$ 296,816 Natural Gas Sales 
   70,490 
   54,291 
  193,489 
  175,067 Other 
   18,401 
   16,033 
   31,417 
   33,252     Total Operating    Revenues 
  251,865 
  213,734 
  570,733 
  505,135   **Operating Costs and Expenses:**Gas Purchases and Other Costs of Sales 
   79,852 
   53,310 
  192,807 
  154,557 Operations and Maintenance 
   31,549 
   33,225 
   61,450 
   62,305 General and Administrative 
   18,786 
   17,108 
   35,194 
   36,658 Depreciation and Amortization 
   29,047 
   25,994 
   58,672 
   51,998 Taxes, Other Than Income Taxes 
    7,383 
    7,226 
   14,557 
   14,391     Total Operating    Costs and Expenses 
  166,617 
  136,863 
  362,680 
  319,909   **Operating Income**
   85,248 
   76,871 
  208,053 
  185,226   **Other Income and (Expenses):**Equity in Earnings of Kinder Morgan Energy    Partners 
  113,732 
   93,394 
  225,227 
  183,485 Equity in Earnings of Other Equity    Investments 
    2,719 
    4,056 
    5,202 
    6,428 Interest Expense, Net 
  (31,314)
  (39,810)
  (71,288)
  (79,358)Minority Interests 
  (15,476)
  (12,824)
  (31,397)
  (25,601)Other, Net 
     (874)
    1,477 
      122 
    5,050     Total Other Income    and (Expenses) 
   68,787 
   46,293 
  127,866 
   90,004   **Income Before Income Taxes**
  154,035 
  123,164 
  335,919 
  275,230 Income Taxes 
   59,841 
   50,712 
  130,655 
  114,390   **Net Income**
$  94,194 
$  72,452 
$ 205,264 
$ 160,840 ========= ========= ========= =========   **Basic Earnings Per Common Share**
$    0.77 
$    0.59 
$    1.68 
$    1.31 ========= ========= ========= =========   Number of Shares Used in Computing Basic    Earnings Per Common    Share 
  122,218 
  122,015 
  122,048 
  122,703 ========= ========= ========= =========   **Diluted Earnings Per Common Share**
$    0.76 
$    0.59 
$    1.66 
$    1.30 ========= ========= ========= =========   Number of Shares Used in Computing Diluted    Earnings Per Common    Share 
  123,474 
  123,230 
  123,285 
  124,026 ========= ========= ========= =========   **Dividends Per Common Share**
$    0.15 
$    0.05 
$    0.30 
$    0.10 ========= ========= ========= ========= 
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****Six Months Ended June 30,**2003**2002
(In    thousands)**Cash Flows From Operating Activities:**Net Income 
$   205,264 
$   160,840 Adjustments to Reconcile Net Income to Net    Cash Flows       from Operating Activities:    Depreciation and    Amortization 
     58,672 
     51,998     Deferred Income    Taxes 
     56,502 
     28,916     Equity in Earnings    of Kinder Morgan Energy Partners 
   (225,227)
   (183,485)    Distributions from    Kinder Morgan Energy Partners 
    177,316 
    148,591     Equity in Earnings    of Other Investments 
     (5,202)
     (6,428)    Minority Interests    in Income of Consolidated Subsidiaries 
     20,441 
     14,645     Deferred Purchased    Gas Costs 
    (11,339)
      3,921     Net (Gains) Losses    on Sales of Assets 
      4,297 
     (2,567)    Gain from    Settlement of Orcom Note 
     (2,917)
          -     Litigation    Settlement and Escrow Deposit 
          - 
    (22,050)    Pension    Contribution in Excess of Expense 
          - 
    (18,772)    Changes in Gas in    Underground Storage 
     66,852 
    (17,503)    Changes in Other    Working Capital Items 
    (64,330)
     27,765     Proceeds from    Termination of Interest Rate Swap 
     28,147 
          -     Other, Net 
    (10,832)
     (4,434)  Net Cash Flows Provided by    Continuing Operations 
    297,644 
    181,437   Net Cash Flows Used in    Discontinued Operations 
       (807)
     (5,136)**Net Cash Flows Provided by Operating    Activities**
    296,837 
    176,301   **Cash Flows From Investing Activities:**Capital Expenditures 
    (47,827)
    (77,720)Investment in Kinder Morgan Energy Partners    
     (1,764)
          - Other Investments 
     (8,677)
   (167,085)Proceeds from Settlement of Orcom Note 
      2,627 
          - Proceeds from Sales of Assets 
      6,421 
      4,941 **Net Cash Flows Used in Investing    Activities**
    (49,220)
   (239,864)  **Cash Flows From Financing Activities:**Short-term Debt, Net 
    221,500 
    230,227 Long-term Debt Retired 
   (511,083)
       (636)Common Stock Issued 
     24,545 
     12,314 Short-term Advances From (To)    Unconsolidated Affiliates 
     49,337 
    (24,727)Orcom Proceeds Payable to Pacificorp 
      2,622 
          - Repurchase of Kinder Morgan Management, LLC    Shares 
       (928)
          - Treasury Stock Acquired 
     (2,478)
   (139,875)Cash Dividends, Common Stock 
    (36,608)
    (12,302)Minority Interests, Net 
       (245)
       (216)**Net Cash Flows (Used in) Provided by    Financing Activities**
   (253,338)
     64,785   Net (Decrease) Increase in Cash and Cash    Equivalents 
     (5,721)
      1,222 Cash and Cash Equivalents at Beginning of    Period 
     35,653 
     16,134 Cash and Cash Equivalents at End of Period 
$    29,932 
$    17,356 
=========== 
=========== 
For supplemental cash flow information, see Note 5.The accompanying notes are an integral part of these statements.

6
**NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Unaudited)**
1.   Summary of Significant Accounting Policies
Stock-Based Compensation

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 $253,000 and $290,000 for the three months ended June 30,2003 and 2002, respectively and $500,000 and $568,000 for the six months ended June 30,2003 and 2002, respectively, related to the purchase discount offered under the employeestock purchase plan.
**Three Months Ended    June 30,**Six Months Ended    June 30,**2003**2002**2003**2002Net Income, As Reported 
$  94,194 
$  72,452 
$ 205,264 
$ 160,840   Add: Stock-based Employee    Compensation Expense         Included in Reported Net Income, Net of Related Tax        Effects 
      234 
      223 
      474 
      446   Deduct: Total Stock-based    Employee Compensation        Expense Determined under Fair Value Method for         All Awards, Net of Related Tax Effects 
   (3,875)
   (3,703)
   (7,881)
   (7,896)Pro Forma Net Income
$  90,553 
$  68,972 
$ 197,857 
$ 153,390 
========= 
========= 
========= 
=========   **Basic Earnings Per Common Share:**  As Reported 
$    0.77 
$    0.59 
$    1.68 
$    1.31 
========= 
========= 
========= 
=========   Pro Forma 
$    0.74 
$    0.57 
$    1.62 
$    1.25 
========= 
========= 
========= 
=========   **Diluted Earnings Per Common Share:**  As Reported 
$    0.76 
$    0.59 
$    1.66 
$    1.30 
========= 
========= 
========= 
=========   Pro Forma 
$    0.73 
$    0.56 
$    1.60 
$    1.24 
========= 
========= 
========= 
========= 
2.   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. We have both regulated and nonregulated operations. Our business activitiesinclude: (i) storing, transporting and selling natural gas, (ii) providing retail naturalgas distribution services and (iii) operating and, in previous periods, constructing,natural gas-fired electric generation facilities. In addition, we own the general partnerinterest, as well as significant limited partner interests, in Kinder Morgan EnergyPartners, L.P., a publicly traded pipeline master limited partnership, referred to inthese Notes as "Kinder Morgan Energy Partners," and receive a 

7

substantial portion of our earnings from returns on these investments.Our common stock is traded on the New York Stock Exchange under the symbol"KMI."

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.

3.   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 13.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    June 30,**Six Months Ended    June 30,**2003**2002**2003**2002
(In    thousands)Weighted-average Common Shares Outstanding 
 122,218
 122,015
 122,048
 122,703Dilutive Common Stock Options 
   1,256
   1,215
   1,237
   1,323Shares Used to Compute Diluted Earnings Per    Common Share 
 123,474
 123,230
 123,285
 124,026
========
========
========
========
Weighted-average stock options outstanding totaling 2.4 million and 2.6million for the three months ended June 30, 2003 and 2002, respectively and 2.5 millionand 2.5 million for the six months ended June 30, 2003 and 2002, respectively, wereexcluded from the diluted earnings per common share calculation because the effect ofincluding them would have been antidilutive.

4.   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 $0.1 million and $0.5 million forthe three months ended June 30, 2003 and 2002, respectively and $0.4 million and $0.9million for the six months ended June 30, 2003 and 2002, respectively.

8

5.   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**  **Six Months Ended    June 30,**2003**2002
(In    thousands) Accounts Receivable 
$  25,020 
$  58,351 Materials and Supplies Inventory 
     (506)
    6,096 Other Current Assets 
   (5,294)
  (19,659)Accounts Payable 
  (44,913)
  (49,516)Other Current Liabilities 
  (38,637)
   32,493 
$ (64,330)
$  27,765 
========= 
========= **Supplemental Disclosures of Cash Flow Information:  ****Cash Paid During the Period for:**Interest, Net of Amount Capitalized 
$  85,038 
$  79,550 
========= 
========= Distribution on Preferred Capital Trust    Securities 
$  10,956 
$  10,956 
========= 
========= Income Taxes Paid 
$  62,990 
$  61,474 
========= 
========= 
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 7. "Other, Net"as presented in the accompanying interim Consolidated Statements of Cash Flows principallyconsists of other non-cash increases and decreases to earnings, including amortization ofdeferred revenue, amortization of debt discount and expense and amortization of interestrate swap proceeds previously received upon termination of the swap. For the six monthsended June 30, 2003, this line item also includes approximately $4.1 million attributableto a reduction in interest expense associated with the final settlement of a regulatorymatter at Natural Gas Pipeline Company of America.

9

6.   ComprehensiveIncome
Our comprehensive income for the three months and six months ended June30, 2003 and 2002 is as follows:
**Three Months Ended June 30, **Six Months Ended June 30, **2003**2002**2003**2002
(In    thousands)**Net Income**
$  94,194 
$  72,452 
$ 205,264 
$ 160,840 **Other Comprehensive Income (Loss), Net    of Tax:**  Change in Fair Value of    Derivatives Utilized    for Hedging    Purposes, Net of Tax 
   (9,430)
   (2,144)
  (30,534)
  (12,627)  Reclassification of Change in    Fair Value of    Derivatives to Net    Income, Net of Tax 
   11,274 
   (3,051)
   30,005 
    2,181   Equity in Other Comprehensive    Income of    Equity Method    Investees 
   (4,362)
     (718)
   (5,750)
  (19,963)  Minority Interest in Other    Comprehensive    Income of Equity    Method Investees 
    2,111 
      303 
    3,690 
    8,311 **Other Comprehensive Loss**
     (407)
   (5,610)
   (2,589)
  (22,098)**  ****Comprehensive Income**
$  93,787 
$  66,842 
$ 202,675 
$ 138,742 
========= 
========= 
========= 
========= 
The Accumulated Other Comprehensive Loss of $47.3 million at June 30,2003 consisted of (i) $17.7 million associated with recognition of a minimum pensionliability, (ii) $8.1 million representing our pro rata share of the accumulated othercomprehensive loss of Kinder Morgan Energy Partners and (iii) $21.5 million representingunrecognized net losses on derivative activities.

7.   Kinder Morgan Management, LLC
On May 15, 2003, Kinder Morgan Management paid a share distribution of859,933 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. On August 14,2003, Kinder Morgan Management will pay a share distribution of 811,878 of its shares toshareholders of record as of July 31, 2003, based on the $0.65 per common unitdistribution declared by Kinder Morgan Energy Partners for the second quarter of 2003.These distributions are paid in the form of additional shares or fractions thereofcalculated by dividing the Kinder Morgan Energy Partners' cash distribution per commonunit by the average market price of a Kinder Morgan Management share determined for aten-trading day period ending on the trading day immediately prior to the ex-dividend datefor the shares. Kinder Morgan Management has paid share distributions totaling 1,718,914shares in the six months ended June 30, 2003.

8.   Investments
In June 2003, Kinder Morgan Energy Partners issued 4.6 million commonunits in a public offering at a price of $39.35 per common unit, receiving total netproceeds (after underwriting discount) of $173.3 million. We did not acquire any of thesecommon units. This transaction reduced our percentage ownership of Kinder Morgan EnergyPartners from approximately 19.28% to approximately 18.86% and had the associated effectsof increasing our investment in the net assets of Kinder Morgan Energy Partners by $14.9million and reducing (i) our equity method goodwill in Kinder Morgan Energy Partners by$21.4 million, (ii) associated accumulated deferred income taxes by $2.5 million and (iii)paid-in capital by $4.0 million. In addition, in June 2003, in order to maintain our onepercent general partner interest in Kinder Morgan Energy Partners' operating partnershipswe made a contribution of approximately $1.8 million.

10

On June 30, 2003, we received $3.8 million from the sale of ourinterest in Igasamex USA Ltd. We recorded a pre-tax loss of $4.3 million ($2.7 millionafter tax) in conjunction with the sale.

On March 6, 2000, we received a promissory note from Orcom Solutions,Inc. as partial consideration for the sale of our **en**•able joint venture, whichnote was carried at nominal value due to concerns as to recoverability. On June 30, 2003,we received $5.2 million in settlement of this note of which $2.6 million was paid toPacifiCorp reflecting its 50% interest in **en**•able. In conjunction with thissettlement, we recorded a pre-tax gain of $2.9 million ($1.8 million after tax).

9.   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 June 30, 2003 andin its Annual Report on Form 10-K for the year ended December 31, 2002.
**Three Months Ended June 30,**Six Months Ended June 30,**2003**2002**2003**2002
(In    thousands)Operating Revenues
$ 1,664,447
$ 1,090,936
$ 3,453,285
$ 1,894,001Operating Expenses
  1,464,885
    918,589
  3,058,571
  1,555,798Operating Income
$   199,562
$   172,347
$   394,714
$   338,203
===========
===========
===========
===========  Net Income
$   168,957
$   144,517
$   339,435
$   285,950
===========
===========
===========
===========
10.  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.

11.  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 that variesbased on our senior debt rating. We had no borrowings under our bank facilities at June30, 2003.

11

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 June 30, 2003was $221.5 million. Our weighted-average interest rate on short-term borrowingsoutstanding at June 30, 2003 was 1.31 percent. Average short-term borrowings outstandingduring the second quarter of 2003 were $269.1 million and the weighted-average interestrate was 1.41 percent. Average short-term borrowings outstanding during the first sixmonths of 2003 were $192.3 million and the weighted-average interest rate was 1.45percent.

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

On July 16, 2003, our Board of Directors approved a cash dividend of$0.40 per common share payable on August 14, 2003 to shareholders of record as of July 31,2003.

12.  Change inCompensation Policies
On July 16, 2003, we announced a change to our compensation policies.Chairman and Chief Executive Officer Richard D. Kinder will continue to receive $1 peryear in salary with no bonuses, stock options, grants of restricted stock or othercompensation. The ten most senior executives (excluding Mr. Kinder) will continue to havetheir base salaries capped at $200,000 per year and will continue to be eligible forannual bonuses when we and Kinder Morgan Energy Partners meet annual earnings per shareand distributions per unit targets. In addition, these senior executives will no longer beeligible for future stock option grants and have received grants of restricted stock whichwill vest 25 percent after three years and the remaining 75 percent after five years. Weexpect that executives will receive no further equity compensation during the five-yearlife of these restrictions. In total, 575,000 restricted shares of our common stock havebeen issued under a shareholder approved plan. As a result, we and Kinder Morgan EnergyPartners will each expense approximately $3.5 million annually related to the grants ofrestricted stock. Other than restricted stock, executives will continue to have only thosebenefits which are available to all other employees. All other employees will be eligiblefor annual grants of stock options which will vest after three years. On July 16, 2003, weissued 656,450 options to purchase our common shares for $53.80 (the closing price of ourcommon shares on that date) to eligible employees. We expect to issue to employees fewerthan 700,000 options to purchase our common shares annually.

The reader is directed to Part II, Item 5 for further informationregarding the retention agreement of C. Park Shaper.

We and Kinder Morgan Energy Partners have, collectively, agreed toguarantee potential borrowings under lines of credit available from Wachovia Bank,National Association, formerly known as First Union National Bank, to Messrs. ThomasBannigan, C. Park Shaper and James Street and Ms. Deborah Macdonald. Each of theseofficers is primarily liable for any borrowing on his or her line of credit, and if we orKinder Morgan Energy Partners makes any payment with respect to an outstanding loan, theofficer on behalf of whom payment is made must surrender a percentage of his or heroptions to purchase our common stock. Our and Kinder Morgan Energy Partners' currentobligations under the guaranties generally do not exceed $1.0 million in respect of anysuch officer individually and such obligations, in the aggregate, do not exceed $1.9million. To date, we and Kinder Morgan Energy Partners have made no payment with respectto these lines of credit. Further, we and Kinder Morgan Energy Partners' involvement inthese lines of credit will expire in October 2003.

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13.  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 June 30, 2003, wehad repurchased a total of approximately $417.2 million (8,361,800 shares) of ouroutstanding common stock under the program, of which $1.1 million (22,500 shares) and $2.5million (53,600 shares) were repurchased in the three months and six months ended June 30,2003, respectively.

14.  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 in Hermosillo, Mexico) and thenon-regulated sales of natural gas to certain utility customers under the Choice GasProgram and (4) Power, the operation and, in previous periods, construction of naturalgas-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 theaccompanying interim Consolidated Statements of Operations. In addition, (i) certain itemsincluded in operating income (such as general and administrative expenses) are notallocated to individual business segments and (ii) gains and losses from incidental salesof assets are included in segment earnings. With adjustment for these items, we currentlyevaluate business segment performance primarily based on operating income in relation tothe level of capital employed. We account for intersegment sales at market prices, whilewe account for asset transfers at either market value or, in some instances, book value.

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BUSINESS SEGMENT INFORMATION
**Three Months Ended June 30, 2003**June 30, 2003**Segment Earnings**Revenues From    External    Customers1**Depreciation    And    Amortization**Capital    Expenditures**Segment    Assets
(In    thousands)Natural Gas Pipeline Company of America 
$   84,3353 
$  188,188
$   23,150 
$   22,133
$5,536,043 TransColorado Pipeline 
     5,297  
     7,615
     1,035 
       172
   239,569 Kinder Morgan Retail 
     6,331  
    43,323
     4,003 
     5,858
   383,006 Power 
    10,778  
    12,739
       859 
       184
   353,129    Segment Totals 
   106,741  
$  251,865
$   29,047 
$   28,347
 6,511,747 
==========
========== 
==========Earnings from Investment in Kinder Morgan      Energy Partners 
   113,732    Investment in Kinder Morgan      Energy Partners 
 2,089,443 General and Administrative Expenses 
   (18,786)   Goodwill 
   969,443 Other Income and (Expenses) 
   (47,652)3  Other2
   392,390 Income Before Income Taxes 
$  154,035       Consolidated 
$9,963,023 
==========  
==========   **Three Months Ended June 30, 2002**Segment Earnings**Revenues From    External    Customers1**Depreciation    And    Amortization**Capital    Expenditures
(In    thousands)Natural Gas Pipeline Company of America 
$   83,984 
$  157,531
$   21,637 
$   31,818TransColorado Pipeline 
     2,091 
         -
         - 
         -Kinder Morgan Retail 
     6,097 
    46,542
     3,583 
     9,924Power 
     5,924 
     9,661
       774 
        93   Segment Totals 
   98,096 
$  213,734
$   25,994 
$   41,835
==========
========== 
==========Earnings from Investment in Kinder Morgan       Energy Partners 
    93,394   General and Administrative Expenses 
   (17,108)  Other Income and (Expenses) 
   (51,218)  Income Before Income Taxes 
$  123,164   
==========   1
There were no intersegment    revenues during the periods presented.2
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.3
Natural Gas Pipeline    Company of America's segment results for the three months ended June 30, 2003 do not    include a reduction of $4.1 million in interest expense attributable to the final    settlement of a regulatory matter, which amount is included in "Other Income and    (Expenses)."
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  **Six Months Ended June 30, 2003**Segment Earnings**Revenues From    External    Customers1**Depreciation    And    Amortization**Capital    Expenditures
(In    thousands)  Natural Gas Pipeline Company of America 
$  184,4112 
$  402,256
$   45,455 
$   36,941TransColorado Pipeline 
    12,557  
    17,114
     2,101 
       581Kinder Morgan Retail 
    37,790  
   132,312
     7,927 
     7,444Power 
    13,698  
    19,051
     3,189 
     2,861   Segment Totals 
   248,456  
$  570,733
$   58,672 
$   47,827
==========
========== 
==========Earnings from Investment in Kinder Morgan       Energy Partners 
   225,227    General and Administrative Expenses 
   (35,194)   Other Income and (Expenses) 
  (102,570)2  Income Before Income Taxes 
$  335,919    
==========    **Six Months Ended June 30, 2002**Segment Earnings**Revenues From    External    Customers1**Depreciation    And    Amortization**Capital    Expenditures
(In    thousands)  Natural Gas Pipeline Company of America 
$  179,602 
$  340,620
$   43,401 
$   49,852TransColorado Pipeline 
     2,184 
         -
         - 
         -Kinder Morgan Retail 
    30,955 
   144,169
     7,053 
    10,769Power 
    15,664 
    20,346
     1,544 
    17,099   Segment Totals 
  228,405 
$  505,135
$   51,998 
$   77,720
==========
========== 
==========Earnings from Investment in Kinder Morgan       Energy Partners 
   183,485   General and Administrative Expenses 
   (36,658)  Other Income and (Expenses) 
  (100,002)  Income Before Income Taxes 
$  275,230   
==========   1
There were no intersegment    revenues during the periods presented.2
Natural Gas Pipeline    Company of America's segment results for the six months ended June 30, 2003 do not include    a reduction of $4.1 million in interest expense attributable to the final settlement of a    regulatory matter, which amount is included in "Other Income and (Expenses)."
GEOGRAPHIC INFORMATION

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

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15.  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 be recognized in the period in which it is incurred if areasonable estimate of fair value can be made. The impact of the adoption of thisstatement on us is discussed 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, storage wells located within the storage fields,laterals no longer integral to the overall mainline transmission system, compressorstations which are no longer active, and other miscellaneous facilities, all of which havebeen officially abandoned. For these facilities, it is possible to reasonably estimate thetiming of the payment of obligations associated with their retirement. The recognition ofthese obligations has resulted in a liability and associated asset of approximately $2.8million 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 estimate the timing of the incurrence of the expenditures.The remainder of Natural Gas Pipeline Company of America's asset retirement obligationshave not been recorded due to our inability, as discussed above, to reasonably estimatewhen they will be settled in cash. We will record liabilities for these obligations whenwe are able to reasonably estimate their fair value.

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 fulfill 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

16

of commercial operations, to plug and abandon the natural gas wells,remove surface equipment and remediate the well sites. We have estimated that this processwill start in 2005 and continue through 2013 for a total cost of $240,000, withapproximately half the total being spent in the final two years. The recognition of theseobligations has resulted in a liability and associated asset of approximately $0.3 millionas of January 1, 2003, representing the present value of those future obligations forwhich we are able to make reasonable estimations of the current fair value due to, asdiscussed above, our ability to estimate the timing of the incurrence of the expenditures.The remainder of our asset retirement obligations have not been recorded due to ourinability 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.

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. 

16.  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 and six monthperiods ended June 30, 2003 and 2002, our derivative activities relating to the mitigationof these risks were 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 $21.5million, representing unrecognized net losses on derivative activities at June 30, 2003.During the three months and six months ended June 30, 2003 and 2002, we reclassified nogains or losses into earnings as a result of the discontinuance of cash flow hedges due toa determination that the forecasted transactions would no longer occur by the end of theoriginally specified time period. In addition, at June 30, 2003, our accumulated othercomprehensive loss included $8.1 million representing our pro rata share of theaccumulated other comprehensive 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 June 30, 2003. These agreementseffectively convert the interest expense associated with our 7.25% Debentures due in 2028and our 6.50% Senior Notes due in 2012 from fixed rates to floating rates based on thethree-month London Interbank Offered Rate ("LIBOR") plus a credit spread. Theseswaps have been designated as fair value hedges and we have accounted for them utilizingthe "shortcut" method prescribed for qualifying fair value hedges under SFAS No.133. Accordingly, the carrying value of the swap is adjusted to its fair value as of theend of each reporting period, and an offsetting entry is made to adjust the carrying valueof the debt securities whose fair value is being

17

hedged. The carrying value of the swaps at June 30, 2003 was $162.2million (included in the caption "Deferred Charges and Other Assets" in theaccompanying interim Consolidated Balance Sheet as of June 30, 2003). We record interestexpense equal to the floating rate payments, which is accrued monthly and paidsemi-annually.

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 $23.5 million at June 30, 2003 isincluded in the caption "Value of Interest Rate Swaps" under the heading"Long-term Debt" in the accompanying interim Consolidated Balance Sheet.

17.  Regulatory Matters
On July 17, 2000, Natural Gas Pipeline Company of America filed itscompliance plan, including pro forma tariff sheets, pursuant to the Federal EnergyRegulatory Commission's ("FERC") Order Nos. 637 and 637-A. The FERC directed allinterstate pipelines to file pro forma tariff sheets to comply with new regulatoryrequirements in the Orders regarding scheduling procedures, capacity segmentation,imbalance management services and penalty credits, or in the alternative, to explain whyno changes to existing tariff provisions are necessary. On November 21, 2002, the FERCissued an order approving much of Natural Gas Pipeline Company of America's Order 637filing, but requiring additional changes. The primary changes related to Natural GasPipeline Company of America's segmentation proposal, the ability of shippers to designateadditional primary points on a segmented release, a shipper's rights to request discountsat alternate points and Natural Gas Pipeline Company of America's unauthorized overruncharges. Natural Gas Pipeline Company of America made its compliance filing on December23, 2002 and filed for rehearing. Other parties have objected to certain aspects ofNatural Gas Pipeline Company of America's compliance filing. On May 14, 2003, the FERCissued an order accepting most of Natural Gas Pipeline Company of America's compliancefiling, but requiring additional changes, particularly regarding the designation ofadditional primary points for a segmented release. This order also established aneffective date for Natural Gas Pipeline Company of America's Order 637 provisions ofDecember 1, 2003. Natural Gas Pipeline Company of America made its further compliancefiling on June 13, 2003. Limited protests have been filed. That compliance filing ispending FERC action and the resulting tariff sheets are expected to be effective onDecember 1, 2003.

The FERC, in a Notice of Proposed Rulemaking in RM02-14-000, hasproposed new regulation of cash management practices, including establishing limits on theamount of funds that can be swept from a regulated subsidiary to a non-regulated parentcompany. Natural Gas Pipeline Company of America filed comments on August 28, 2002. OnJune 26, 2003, the FERC issued an interim rule to be effective in August 2003, under whichregulated companies are required to document cash management arrangements andtransactions. The FERC eliminated the proposal that, as a prerequisite to participation incash management programs, regulated companies must maintain a 30 percent equity balanceand investment grade credit rating. The FERC seeks additional comment on whether it shouldrequire filing of cash management agreements and notification if a regulated company'sproprietary capital ratio falls below 30 percent.

On July 25, 2003, the FERC issued a Modification to Policy Statementstating that FERC regulated natural gas pipelines will, on a prospective basis, no longerbe permitted to use gas basis differentials to price negotiated rate transactions.Effectively, we will no longer be permitted to use commodity price indices to structuretransactions on our FERC regulated natural gas pipelines. Negotiated rates based oncommodity price indices in existing contracts will be permitted to remain in effect untilthe end of the contract period for which such rates were negotiated. Price indexedcontracts currently constitute an 

18

insignificant portion of our negotiated contracts on our FERC regulatednatural gas pipelines; consequently, we do not believe that this Modification to PolicyStatement will have a material impact on our operations, financial results or cash flows.

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 (the "CPUC"). Rocky Mountain Natural GasCompany and Kinder Morgan, Inc. made regulatory filings with the CPUC on September 30,2002, proposing recovery of these amounts as part of their annual Gas Cost Adjustmentfiling process. We proposed to collect these litigated gas costs, including associatedcarrying charges, over a 15-year amortization period. On October 30, 2002, the CPUCdecided, in open meeting, to allow us to place rates in effect and begin recovery of thesecosts effective November 1, 2002, subject to refund pending a final determination as toour ability to recover these costs in our rates. Mr. Grynberg will receive the money inescrow only to the extent rates allowing us to collect this gas cost are finally approved.An uncontested Stipulation and Settlement Agreement was filed with the CPUC on June 20,2003, providing for full rate recovery by Rocky Mountain Natural Gas Company and KinderMorgan, Inc. of $30,173,472 of gas cost payments to Mr. Grynberg. It also provided for$14,451,528 of allowable interest recovery to Rocky Mountain Natural Gas Company andKinder Morgan, Inc. The total settlement amount of $44,625,000 will be recovered through aspecial rate rider over a fifteen year period which commenced on November 1, 2002. Ahearing was held before the presiding administrative law judge on July 14, 2003, todetermine whether the Stipulation and Settlement Agreement should be approved. At theconclusion of the hearing, the judge stated from the bench that she would issue a writtendecision recommending approval of the Stipulation and Settlement Agreement. Issuance ofthe written decision is pending. If no exceptions are filed and no stay or extension isissued by the CPUC within twenty days after issuance of the recommended decision, it willbecome the decision of the CPUC by operation of law. 

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 offeredwith the Choice Gas program. Customers who do not return a Choice Gas selection form willbe assigned to the pass-on tariff rate. The $1 per month Choice Gas customer charge willnot be applied to pass-on tariff customers.

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.

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

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18.  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 federal False Claims Act and involvesallegations of mismeasurement of natural gas produced from federal and Indian lands. TheDepartment of Justice has decided not to intervene in support of the action. The complaintis part of a larger series of similar complaints filed by Mr. Grynberg against 77 naturalgas pipelines (approximately 330 other defendants). An earlier single action makingsubstantially similar allegations against the pipeline industry was dismissed by JudgeHogan of the U.S. District Court for the District of Columbia on grounds of improperjoinder and lack of jurisdiction. As a result, Mr. Grynberg filed individual complaints invarious courts throughout the country. In 1999, these cases were consolidated by theJudicial Panel for Multidistrict Litigation, and transferred to the District of Wyoming.The MDL case is called *In Re Natural Gas Royalties Qui Tam Litigation*, Docket No.1293. Motions to dismiss were filed and an oral argument on the motion to dismiss occurredon March 17, 2000. On July 20, 2000, the United States of America filed a motion todismiss those claims by Grynberg that deal with the manner in which defendants valued gasproduced from federal leases (referred to as valuation claims). Judge Downes denied thedefendant's motion to dismiss on May 18, 2001. The United States' motion to dismiss mostof the plaintiff's valuation claims has been granted by the Court. Mr. Grynberg hasappealed that dismissal to the 10th Circuit, which has requested briefingregarding its jurisdiction over that appeal. Discovery is now underway to determine issuesrelated to the Court's subject matter jurisdiction, arising out of the False Claims Act.On May 7, 2003, Grynberg sought leave to file a Third Amended Complaint, which addsallegations of undermeasurement related to CO2 production. Defendants havefiled briefs opposing leave to amend.

*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 

20
*defendants, jointly and severally. This action was originally filedon May 28, 1999 in Kansas State Court in Stevens County, Kansas as a class action againstapproximately 245 pipeline companies and their affiliates, including certain Kinder Morganentities. Subsequently, one of the defendants removed the action to Kansas FederalDistrict Court and the case was styled as *Quinque Operating Company, et al. v. GasPipelines, et al.*, Case No. 99-1390-CM, United States District Court for the Districtof Kansas. Thereafter, we filed a motion with the Judicial Panel for MultidistrictLitigation to consolidate this action for pretrial purposes with the Grynberg False ClaimsAct cases, because of common factual questions. On April 10, 2000, the MDL Panel orderedthat this case be consolidated with the Grynberg False Claims Act cases. On January 12,2001, the Federal District Court of Wyoming issued an oral ruling remanding the case backto the State Court in Stevens County, Kansas. The defendants filed a motion to dismiss ongrounds other than personal jurisdiction, which was denied by the Court in August 2002.The motion to dismiss for lack of personal jurisdiction of the nonresident defendants hasbeen briefed and is awaiting decision. Merits discovery has been stayed. The current namedplaintiffs are Will Price, Tom Boles, Cooper Clark Foundation and Stixon Petroleum, Inc.Quinque Operating Company has been dropped from the action as a named plaintiff. On April10, 2003, the Court issued its decision denying plaintiffs' motion for classcertification. The plaintiffs moved the Court for permission to amend the complaint. OnJuly 8, 2003, a hearing was held on the motion to amend. On July 28, 2003, the Courtgranted leave to amend the complaint. The amended complaint does not list us or any of ouraffiliates as defendants. Additionally, a new complaint was filed but that complaint doesnot list us or any of our affiliates as defendants. We will continue to monitor thesematters.
*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 Interenergy onDecember 19, 1997 pursuant to a merger agreement dated August 25, 1997. Rode and McDonaldallege that K N Energy committed securities fraud, common law fraud and negligentmisrepresentation as well as breach of contract. Rode and McDonald are seeking anunspecified amount of compensatory damages, greater than $2 million, plus unspecifiedexemplary or punitive damages, attorney's fees and their costs. We filed a motion todismiss, and on April 21, 2000, the Jefferson County District Court Judge dismissed thecase against the individuals and us with prejudice. On April 6, 2001, the Colorado Courtof Appeals affirmed the dismissal. Rode and McDonald also filed a federal securities fraudaction in the United States District Court for the District of Colorado on January 27,2000 titled *James P. Rode and Patrick R. McDonald v. K N Energy, Inc., et al*.,Civil Action No. 00-N-190. This case initially raised the identical state law claimscontained in the counterclaim and third party complaint in state court. Rode and McDonaldfiled an amended complaint, which dropped the state-law claims. On June 20, 2000, thefederal district court dismissed this complaint with prejudice. The district court'sdismissal was subsequently affirmed by the Tenth Circuit Court 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 District Court for the District ofColorado was served on us on April 10, 2000. As of this date no class has been certified.On February 23, 2001, the federal district court dismissed several claims raised by theplaintiff, with prejudice, and dismissed the remaining claims, without prejudice. On April27, 2001, the Adams plaintiffs filed their second amended complaint. On March 29, 2002,the court dismissed the Adams plaintiffs' second amended complaint with prejudice. On May2, 2002, the Adams plaintiffs appealed the dismissal. Briefing at the Tenth Circuit Courtof Appeals is complete and oral argument on the 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 

21

petition in late 2002 to assert claims on behalf of over 1,000producers who process gas through as many as ten gas processing plants formerly owned byAmerican Processing, L.P. ("American Processing"), a former wholly ownedsubsidiary of Kinder Morgan, Inc. in Carson and Gray counties and other surrounding Texascounties. The plaintiff claims that American Processing (and subsequently, ONEOK, Inc.("ONEOK"), which purchased American Processing from us in 2000) improperlyallocated liquids and gas proceeds to the producers. In particular, among other claims,the plaintiff challenges the accuracy of a computer model used at the plants to allocateliquids and gas proceeds among the producers and processors. The petition asserts claimsfor breach of contract and Natural Resources Code violations relating to the period from1994 to the present. To date, the plaintiff has not made a specific monetary demand norproduced a specific calculation of alleged damages. The plaintiff has alleged generally inthe petition that damages are "not to exceed $200 million" plus attorney's fees,costs and interest. The defendants have filed a counterclaim for overpayments made toproducers. 

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 Court allowed class discovery to proceed. The defendants expect to assert additionalobjections to class certification. 
*Manna Petroleum Services, L.P., et al. v. American Processing, L.P. andCesell 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 fact

22

discovery and trial. We believe that the resolution of the plaintiff'sclaims will be for amounts 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 ourbusiness, 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 investigation and experience to date, that the ultimate resolution of suchitems will not have a material adverse impact on our business, cash flows, financialposition or results of operations.

19.  Recent Accounting Pronouncements
FASB Interpretation No. 46, *Consolidation of Variable InterestEntities*
In January 2003, the Financial Accounting Standards Board("FASB") issued Interpretation No. 46, *Consolidation of Variable InterestEntities*. This interpretation of Accounting Research Bulletin No. 51, *ConsolidatedFinancial Statements*, addresses consolidation by business enterprises of variableinterest entities (some, but not all, of which have been referred to as "specialpurpose entities") with certain defined characteristics. One provision of theinterpretation increases the minimum amount of third-party investment required to supportnon-consolidation from 3% to 10%. Certain of the disclosure provisions contained in theinterpretation are effective for financial statements issued after January 31, 2003, allof the provisions are immediately applicable to variable interest entities created afterJanuary 31, 2003 and public entities with variable interests in entities created beforeFebruary 1, 2003 are required to apply the provisions (other than the transitiondisclosure provisions) to that entity no later than the beginning of the first interim orannual reporting period beginning after June 15, 2003.

The principal impact of this interpretation on us is that, uponimplementation, we expect to begin consolidation of Triton Power Company LLC and itswholly owned subsidiary, Triton Power Michigan LLC, the lessee of the Jackson, Michiganpower generation facility. We operate the Jackson facility and have a preferred interestin Triton Power Company LLC, in which the common interest is owned by others. Neitherentity has debt but, as a result of this consolidation, we will include the leaseobligation on the Jackson plant in our consolidated financial statements. We expect toapply the provisions of the statement beginning with the third quarter of 2003 and, atthat time, the total remaining lease payments will be $553.5 million and will be $21.7million, $20.3 million, $20.3 million, $20.4 million and $20.6 million for 2004 through2008, respectively. The difference between the earnings impact under consolidation andunder the currently-applied cost method is not expected to be material.

In addition, a preliminary conclusion has been reached that the trustswhich are our wholly owned subsidiaries that issued our trust preferred trust securitiesare variable interest entities for purposes of applying this statement and, further, thatupon application of this statement these trusts would no longer be consolidated. Assumingthat this conclusion is not changed, we expect that, upon application of the statement,(i) an amount equal to the carrying value of the trust preferred securities will bereported as part of long-term debt in our consolidated balance sheet and (ii) we willclassify future payments made by us in conjunction with the trust preferred securities asinterest expense, rather than minority interest.

23

Statement of Financial Accounting Standards No. 149, *Amendment ofStatement 133 on Derivative Instruments and Hedging Activities*
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 require that contracts withcomparable characteristics be accounted for similarly. In particular, this statementclarifies under what circumstances a contract with an initial net investment meets thecharacteristic of a derivative as discussed in SFAS No. 133. In addition, it clarifieswhen a derivative contains a financing component that warrants special reporting in thestatement of cash flows. SFAS No. 149 amends certain other existing pronouncements. Thosechanges will result in more consistent reporting of contracts that are derivatives intheir entirety or that contain embedded derivatives that warrant 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 do not expect the impacts ofadopting this statement on our financial position or results of operations to be material.

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. 

24

Statement of Financial Accounting Standards No. 150, *Accounting forCertain Financial Instruments with Characteristics of Both Liabilities and Equity*.

In May 2003, the FASB issued SFAS No. 150, *Accounting for CertainFinancial Instruments with Characteristics of Both Liabilities and Equity*. Thisstatement establishes standards for how an issuer classifies and measures certainfinancial instruments with characteristics of both liabilities and equity. It requiresthat an issuer classify a financial instrument that is within its scope as a liability (oran asset in some circumstances). Many of those instruments were previously classified asequity.

SFAS No. 150 requires an issuer to classify the following instrumentsas liabilities (or assets in some circumstances):
•
a financial instrument issued in the form    of shares that is mandatorily redeemable - that embodies an unconditional obligation    requiring the issuer to redeem it by transferring its assets at a specified or    determinable date (or dates) or upon an event that is certain to occur;
  •
a financial instrument, other than an    outstanding share, that, at inception, embodies an obligation to repurchase the issuer's    equity shares, or is indexed to such an obligation, and that requires or may require the    issuer to settle the obligation by transferring assets (for example, a forward purchase    contract or written put option on the issuer's equity shares that is to be physically    settled or net cash settled); and
  •
a financial instrument that embodies an    unconditional obligation, or a financial instrument other than an outstanding share that    embodies a conditional obligation, that the issuer must or may settle by issuing a    variable number of its equity shares, if, at inception, the monetary value of the    obligation is based solely or predominantly on any of the following:
    •
a fixed monetary amount known at    inception, for example, a payable settleable with a variable number of the issuer's equity    shares;    •
variations in something other than the    fair value of the issuer's equity shares, for example, a financial instrument indexed to    the Standard & Poor's 500 and settleable with a variable number of the issuer's equity    shares; or  •
variations inversely related to changes in    the fair value of the issuer's equity shares, for example, a written put option that could    be net share settled.
The requirements of this statement apply to issuers' classification andmeasurement of freestanding financial instruments, including those that comprise more thanone option or forward contract. This statement does not apply to features that areembedded in a financial instrument that is not a derivative in its entirety. It also doesnot affect the classification or measurement of convertible bonds, puttable stock, orother outstanding shares that are conditionally redeemable. This statement also does notaddress certain financial instruments indexed partly to the issuer's equity shares andpartly, but not predominantly, to something else.

This statement is effective for financial instruments entered into ormodified after May 31, 2003, and otherwise is effective at the beginning of the firstinterim period beginning after June 15, 2003, except for mandatorily redeemable financialinstruments of nonpublic entities. It is to be implemented by reporting the cumulativeeffect of a change in accounting principle for financial instruments created before theissuance date of the statement and still existing at the beginning of the interim periodof adoption. Restatement is not permitted. In the event that, under the provisions of FASBInterpretation No. 46, our wholly-owned subsidiary trusts which issued our preferred trustsecurities are determined 

25

not to be variable interest entities or if they are determined to bevariable interest entities but continued consolidation is determined to be appropriate, weexpect that the provisions of this statement will, upon implementation, result in (i) thereclassification of our trust preferred securities to the debt portion of our balancesheet and (ii) the classification of future payments made by us in conjunction with thetrust preferred securities as interest expense, rather than minority interest.

 
***26***Item 2.  Management's Discussion and Analysis of Financial Condition andResults 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 June 30,**Earnings    Increase**2003**2002**(Decrease)
(In thousands    except per share amounts)Operating Revenues 
$  251,865 
$  213,734 
$   38,131 Gas Purchases and Other Costs of Sales 
   (79,852)
   (53,310)
   (26,542)General and Administrative Expenses 
   (18,786)
   (17,108)
    (1,678)Other Operating Expenses 
   (67,979)
   (66,445)
    (1,534)Operating Income 
    85,248 
    76,871 
     8,377 Other Income and (Expenses) 
    68,787 
    46,293 
    22,494 Income Taxes 
   (59,841)
   (50,712)
    (9,129)Net Income 
$   94,194 
$   72,452 
$   21,742 
========== 
========== 
========== Diluted Earnings Per Common Share 
$     0.76 
$     0.59 
$     0.17 
========== 
========== 
========== Number of Shares Used in Computing Diluted   Earnings per    Common Share 
   123,474 
   123,230 
       244 
========== 
========== 
==========   **Six Months Ended June 30,**Earnings    Increase**2003**2002**(Decrease)
(In thousands    except per share amounts)Operating Revenues 
$  570,733 
$  505,135 
$   65,598 Gas Purchases and Other Costs of Sales 
  (192,807)
  (154,557)
   (38,250)General and Administrative Expenses 
   (35,194)
   (36,658)
     1,464 Other Operating Expenses 
  (134,679)
  (128,694)
    (5,985)Operating Income 
   208,053 
   185,226 
    22,827 Other Income and (Expenses) 
   127,866 
    90,004 
    37,862 Income Taxes 
  (130,655)
  (114,390)
   (16,265)Net Income 
$  205,264 
$  160,840 
$   44,424 
========== 
========== 
========== Diluted Earnings Per Common Share 
$     1.66 
$     1.30 
$     0.36 
========== 
========== 
========== Number of Shares Used in Computing Diluted   Earnings per    Common Share 
   123,285 
   124,026 
      (741)
========== 
========== 
========== 
Net income increased from $72.5 million in the second quarter of 2002to $94.2 million in the second quarter of 2003, an increase of $21.7 million (30%). Totaldiluted earnings per common share increased from $0.59 in the second quarter of 2002 to$0.76 in the second quarter of 2003, an increase of 

27

$0.17 (29%). Income was positively affected in the second quarter of2003, relative to 2002, primarily by (i) increased equity in earnings of Kinder MorganEnergy Partners due, in part, to the strong performance from the assets owned and/oroperated by Kinder Morgan Energy Partners, (ii) increased earnings from each of ourbusiness segments, as discussed in more detail in the individual business segmentdiscussions following, (iii) reduced interest expense as a result of lower outstandingdebt, lower interest rates and a $4.1 million reduction as a result of the finalsettlement of a regulatory matter at Natural Gas Pipeline Company of America, (iv) a lowereffective tax rate in 2003 and (v) a $2.9 million pre-tax gain ($1.8 million after tax)from recovery of loan principal in excess of our carrying value (see Note 8 of theaccompanying Notes to Consolidated Financial Statements). These positive impacts werepartially offset by (i) increased income tax expense due to the increased pre-tax income,(ii) a $4.3 million pre-tax loss ($2.7 million after tax) due to the sale of our interestin the Igasamex joint venture and (iii) increased general and administrative expenses dueprincipally to higher costs for employee benefits. The number of shares used to calculatediluted earnings per common share was approximately 0.2 million higher in the secondquarter of 2003 than in the second quarter of 2002, principally due to incremental sharesissued under the employee stock purchase plan and for stock options that were exercised,partially offset by the impact of share repurchases.

Net income increased from $160.8 million in the first six months of2002 to $205.3 million in the first six months of 2003, an increase of approximately $44.5million (28%). Total diluted earnings per common share increased from $1.30 in the firstsix months of 2002 to $1.66 in the first six months of 2003, an increase of $0.36 (28%).Income was affected in the first six months of 2003, relative to 2002, principally by thesame factors as previously discussed for the second quarter, except that, on ayear-to-date basis, (i) general and administrative expenses were lower in 2003 due, inpart, to lower legal costs and (ii) earnings from the Power business segment were lower in2003 (see the Power segment discussion following). The number of shares used to calculatediluted earnings per common share was approximately 0.7 million lower in the first sixmonths of 2003 than in the first six months of 2002, principally due to the impact ofshare repurchases.
**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 Pipeline
28
  Retail Natural Gas Distribution The regulated sale and transportation of natural gas to    residential, commercial and industrial customers (including a small distribution system 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.

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    June 30,**Increase**Six Months Ended    June 30,**2003**2002**(Decrease)**2003**2002**Increase
(In    thousands except systems throughput)Operating Revenues 
$188,188 
$157,531 
$ 30,657 
$402,256 
$340,620 
$ 61,636 
======== 
======== 
======== 
======== 
======== 
========   Segment Earnings 
$ 84,335 
$ 83,984 
$    351 
$184,411 
$179,602 
$  4,809 
======== 
======== 
======== 
======== 
======== 
========     Systems Throughput (Trillion       Btus) 
   340.9 
   353.1 
   (12.2)
   792.0 
   751.0 
    41.0 
======== 
======== 
======== 
======== 
======== 
======== 
Natural Gas Pipeline Company of America's segment earnings increased by$0.4 million (0.4%) from the second quarter of 2002 to the second quarter of 2003. Theincrease in operating revenues, which was largely offset by a corresponding increase incost of sales, was principally due to increased 2003 operational natural gas sales and, toa lesser extent, increased transportation and storage revenues, largely due toexpansions/extensions as discussed following. Business segment earnings for the secondquarter of 2003 were positively impacted, relative to 2002, by (i) increased margin fromtransportation and storage services resulting from expansion and extension projects comingon line since the end of the second quarter of last year as discussed below and (ii)increased 2003 operational sales of natural gas. 

29

Results were also affected by increased depreciation expense related tothe expansion and extension projects, partially offset by decreased operations andmaintenance expenses for storage operations, compressor power and right-of-way costs.System throughput decreased by 12.2 trillion Btus (3.5%) from the second quarter of 2002to the second quarter of 2003 due, in part, to the fact that 2002, as a result ofweather-related factors, was an abnormally high year in terms of system throughput. Systemthroughput in the second quarter of 2003 exceeded the average second quarter throughputfor the last four years. The decrease in system throughput in 2003 did not have asignificant direct impact on revenues due to the fact that transportation revenues arederived primarily from "demand" contracts in which shippers pay a fee to reservea set amount of system capacity for their use. Natural Gas Pipeline Company of America'ssegment results for the second quarter and the six months ended June 30, 2003 do notinclude a reduction of $4.1 million in interest expense attributable to the finalsettlement of a regulatory matter, which amount is included in "Interest Expense,Net" as discussed elsewhere herein.

Natural Gas Pipeline Company of America's segment earnings increased by$4.8 million (2.7%) from the first six months of 2002 to the first six months of 2003. Theincrease in operating revenues, which was largely offset by a corresponding increase incost of sales, was principally due to increased 2003 operational natural gas sales and, toa lesser extent, increased revenues from transportation and storage revenues. Businesssegment earnings for the first six months of 2003 were impacted, relative to 2002,principally by the same factors affecting the first quarter, as discussed previously,except that, on a year-to-date basis, (i) taxes other than income taxes were lower in 2003due, principally, to a state refund received in 2003 and (ii) operations and maintenanceexpenses were nearly unchanged in 2003. System throughput increased by 41.0 trillion Btus(5.5%) from the first six months of 2002 to the first six months of 2003 due, in part, tocolder than normal weather in this segment's principal market areas during the firstquarter of 2003. This increase did not have a significant direct impact on revenues due tothe "demand" structure of transportation contracts as discussed previously.

Horizon Pipeline Company, which provides natural gas transportationcapacity to the growing northern Illinois market, began service in the second quarter of2002. Horizon Pipeline Company is a joint venture with Nicor Inc. Natural Gas PipelineCompany of America's lateral extension into the eastern portion of the St. Louismetropolitan area began service in the third quarter of 2002. During April 2003, NaturalGas Pipeline Company of America began construction of 10.7 Bcf of storage serviceexpansion at the existing North Lansing storage facility in east Texas, all of which isfully subscribed under long-term contracts. Although construction on the $35.6 millionproject won't be totally completed until early 2004, the service is available at thistime. Please refer to our 2002 Form 10-K for additional information regarding Natural GasPipeline Company of America.
**TransColorado Pipeline****Three Months Ended    June 30,**Six Months Ended    June 30,**2003**2002**Increase**2003**2002**Increase
(In    thousands except systems throughput)Operating Revenues1
$  7,615 
$      - 
$  7,615 
$ 17,114 
$      - 
$ 17,114 
======== 
======== 
======== 
======== 
======== 
========   Segment Earnings1
$  5,297 
$  2,091 
$  3,206 
$ 12,557 
$  2,184 
$ 10,373   
======== 
======== 
======== 
======== 
======== 
========   Systems Throughput (Trillion       Btus) 2
    42.2 
    39.5 
     2.7 
    88.7 
    72.2 
    16.5 
======== 
======== 
======== 
======== 
======== 
======== 
1 Equity method in 2002, fullyconsolidated in 2003, see the textual discussion following.2 Representing 100% ofpipeline throughput in each period.
30

TransColorado Pipeline's segment earnings increased from $2.1 millionin the second quarter of 2002 (representing a 50% equity method interest in earnings) to$5.3 million in the second quarter of 2003 (representing fully consolidated results at the100% ownership level). During the second quarter of 2002, TransColorado Pipeline was ajoint venture 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 2.7 trillion Btus (6.8%) from the second quarter of2002 to the second quarter of 2003 as long-haul capacity on TransColorado is now fullysubscribed into 2004. In addition, these results reflect the favorable impact of widebasis differentials on certain transportation contracts, which differentials may notremain as wide throughout the year. 

TransColorado Pipeline's segment earnings increased from $2.2 millionin the first six months of 2002 (representing a 50% equity method interest in earnings) to$12.6 million in the first six months of 2003 (representing fully consolidated results atthe 100% ownership level). Results for the first six months of 2003, relative to 2002,were affected by the same factors affecting second quarter results, as discussed above,with the exception that, on a year-to-date basis, system throughput has increased 16.5trillion Btus (22.9%). Please refer to our 2002 Form 10-K for additional informationregarding TransColorado Pipeline, including our previously announced exploration of apotential expansion of the system.
**Kinder Morgan Retail****Three Months Ended    June 30,**Increase**Six Months Ended    June 30,**Increase**2003**2002**(Decrease)**2003**2002**(Decrease)
(In    thousands except systems throughput)Operating Revenues 
$ 43,323 
$ 46,542 
$ (3,219)
$132,312 
$144,169 
$(11,857)
======== 
======== 
======== 
======== 
======== 
========   Segment Earnings 
$  6,331 
$  6,097 
$    234 
$ 37,790 
$ 30,955 
$  6,835 
======== 
======== 
======== 
======== 
======== 
========     Systems Throughput (Trillion       Btus)1
     5.9 
     6.6 
    (0.7)
    23.3 
    20.1 
     3.2 
======== 
======== 
======== 
======== 
======== 
======== 
1Excludes transport volumes ofintrastate pipelines.
Kinder Morgan Retail's segment earnings increased by $0.2 million(3.3%) from $6.1 million in the second quarter of 2002 to $6.3 million in the secondquarter of 2003. Segment results were positively impacted in 2003, relative to 2002, by(i) lower costs and higher per-unit margins in unregulated businesses and (ii) customergrowth in Colorado. These positive impacts were partially offset by (i) increaseddepreciation expenses resulting from asset additions and (ii) a reduction in systemthroughput volumes of 0.7 trillion Btus (10.6%), principally due to reduced irrigationdemand resulting from increased precipitation during the second quarter of 2003. Ourweather hedging program continued to reduce the impact of these weather-related demandfluctuations, thereby contributing to stability in our earnings pattern. Our hedgingstrategy is discussed in detail in our 2002 Form 10-K.

Kinder Morgan Retail's segment earnings increased by $6.8 million(21.9%) from $31.0 million in the first six months of 2002 to $37.8 million in the firstsix months of 2003. Segment results were impacted in 2003, relative to 2002, principallyby the same factors affecting second quarter results as discussed previously except that(i) on a year-to-date basis, segment results were positively affected in 2003 by a shiftin timing of certain items affecting margin by approximately $3 million between the firstand fourth quarters of 2003 and (ii) on a year-to-date basis, system throughput increased3.2 trillion Btus (15.9%) due to increased throughput in the first quarter resulting fromincreased space-heating demand caused by 

31

colder weather in 2003, partially offset by lower irrigation volumes inthe second quarter as discussed above.

Kinder Morgan Retail has undertaken two expansion projects in westernColorado that are expected to be drivers of future earnings growth. A mainline projectfrom Gypsum to Dotsero has been completed and is in service. A mainline from near Montroseto Ouray is in progress with completion expected by mid-2004. Please refer to our 2002Form 10-K for additional information regarding Kinder Morgan Retail.
**Power****Three Months Ended    June 30,**Six Months Ended    June 30,**2003**2002**Increase**2003**2002**Decrease
(In    thousands)Operating Revenues 
$ 12,739 
$  9,661 
$  3,078 
$ 19,051 
$ 20,346 
$ (1,295)
======== 
======== 
======== 
======== 
======== 
========   Segment Earnings 
$ 10,778 
$  5,924 
$  4,854 
$ 13,698 
$ 15,664 
$ (1,966)
======== 
======== 
======== 
======== 
======== 
======== 
Power's segment earnings increased by $4.9 million (83.1%) from $5.9million in the second quarter of 2002 to $10.8 million in the second quarter of 2003.Segment results were positively impacted in the second quarter of 2003, relative to 2002,by (i) an increase of $2.8 million in net power plant development fees, (ii) an increaseof $1.0 million attributable to net operating fees from the Jackson, Michigan plant, whichcommenced commercial operations in July 2002, and increased earnings from ThermoCogeneration Partnership, primarily resulting from lower 2003 turbine maintenance and(iii) reduced labor costs. As previously announced, we have ceased power plant developmentactivities. Consequently, we do not anticipate any revenues from power plant developmentfees after the second quarter of 2003. We currently retain interests in five naturalgas-fired power plants.

Power's segment earnings decreased by $2.0 million (12.7%) from $15.7million in the first six months of 2002 to $13.7 million in the first six months of 2003.Segment results were negatively impacted in the first six months of 2003, relative to2002, by (i) a decrease of $4.1 million in net power plant development fees and (ii) $1.5million in depreciation expense in 2003 related to the retirement of gas turbinecomponents that were replaced. These negative impacts were partially offset by (i) anincrease of $2.0 million attributable to net operating fees from the Jackson, Michiganplant, which was placed in service in July 2002, (ii) increased earnings from ThermoCogeneration Partnership and (iii) reduced labor costs. Please refer to our 2002 Form 10-Kfor additional information regarding Power. 

32
**Other Income and (Expenses)****Three Months Ended    June 30,**Earnings Increase**2003**2002**(Decrease)
(In    thousands)Interest Expense, Net 
$ (31,314)
$ (39,810)
$   8,496 Equity in Earnings of Kinder Morgan Energy    Partners:    General Partner    Interest 
   82,243 
   66,700 
   15,543     Limited Partner    Units 
    8,803 
   11,824 
   (3,021)    Limited Partner    i-units1
   22,686 
   14,870 
    7,816 Equity in Earnings of Power Segment2
    2,305 
    1,611 
      694 Equity in Earnings of Horizon Pipeline    Company3
      402 
      415 
      (13)Equity in Earnings of TransColorado    Pipeline4
        - 
    2,091 
   (2,091)Other Equity in Earnings (Losses) 
       12 
      (61)
       73 Minority Interests:    Trust Preferred    Securities 
   (5,478)
   (5,478)
        -     Kinder Morgan    Management, LLC 
   (9,895)
   (7,237)
   (2,658)    Other 
   (103)
   (109)
    6 Other, Net 
     (874)
    1,477 
   (2,351)    
$  68,787 
$  46,293 
$  22,494 
========= 
========= 
=========   **Six Months Ended    June 30,**Earnings Increase**2003**2002**(Decrease)
(In    thousands)Interest Expense, Net 
$ (71,288)
$ (79,358)
$   8,070 Equity in Earnings of Kinder Morgan Energy    Partners:    General Partner    Interest 
  160,412 
  129,935 
   30,477     Limited Partner    Units 
   18,312 
   23,938 
   (5,626)    Limited Partner    i-units1
   46,503 
   29,612 
   16,891 Equity in Earnings of Power Segment2
    4,478 
    3,922 
      556 Equity in Earnings of Horizon Pipeline    Company3
      731 
      415 
      316 Equity in Earnings of TransColorado    Pipeline4
        - 
    2,184 
   (2,184)Other Equity in Earnings (Losses) 
       (7)
      (93)
       86 Minority Interests:    Trust Preferred    Securities 
  (10,956)
  (10,956)
        -     Kinder Morgan    Management, LLC 
  (20,283)
  (14,365)
   (5,918)    Other 
   (158)
   (280)
  122 Other, Net 
      122 
    5,050 
   (4,928)    
$ 127,866 
$  90,004 
$  37,862 
========= 
========= 
========= 
1 Owned by Kinder Morgan Management.2 Included in Power segment earnings.3 Included in Natural Gas Pipeline Company of America segment earnings.4 Included in TransColorado Pipeline segment earnings.

"Other Income and (Expenses)" was a net increase to earningsof $68.8 million and $46.3 million in the second quarters of 2003 and 2002, respectively.This positive variance of $22.5 million is principally due to (i) an increase of $20.3million in equity in earnings of Kinder Morgan Energy Partners, which was partially offsetby an increase in expense of $2.7 million due principally to additional minority interestin Kinder Morgan Management, (ii) a decrease of $8.5 million in interest expense resultingfrom lower outstanding debt, lower interest rates and a reduction of $4.1 million inexpense as a result of the final settlement of a regulatory matter at Natural Gas PipelineCompany of America and (iii) a $2.9 million pre-tax gain ($1.8 million after tax) fromreceipt of loan principal in excess of our carrying value 

33

(see Note 8 of the accompanying Notes to Consolidated FinancialStatements). These positive impacts were partially offset by a $4.3 million pre-tax loss($2.7 million after tax) due to the sale of our interest in the Igasamex joint venture.

"Other Income and (Expenses)" was a net increase to earningsof $127.9 million and $90.0 million in the first six months of 2003 and 2002,respectively. This positive variance of $37.9 million is principally due to (i) anincrease of $41.7 million in equity in earnings of Kinder Morgan Energy Partners, whichwas partially offset by an increase in expense of $5.8 million, due principally toadditional minority interest in Kinder Morgan Management, (ii) a decrease of $8.1 millionin interest expense resulting from lower interest rates and a reduction of $4.1 million inexpense at Natural Gas Pipeline Company of America as discussed above and (iii) thereceipt of loan proceeds in excess of carrying value and the loss on sale of our Igasamexinvestment as discussed above.
**Income Taxes**
The increase of $9.1 million in the income tax provision for the secondquarter of 2003, relative to the second quarter of 2002, consisted of an increase of $13.0million resulting from an increase in pre-tax income, partially offset by a decrease of$3.9 million reflecting a reduction in the effective tax rate, largely due to a reducedprovision for state income taxes.

The increase of $16.3 million in the income tax provision for the firstsix months of 2003, relative to the first six months of 2002, consisted of an increase of$26.3 million resulting from an increase in pre-tax income, partially offset by a decreaseof $10.0 million reflecting a reduction in the effective tax rate, largely due to areduced provision 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 10 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 and thereafter reflect the May 2001 sale of shares of KinderMorgan Management in its initial public offering. The balances at December 31, 2002 andthereafter also reflect the impact of Kinder Morgan Management's August 2002 public saleof its shares. In addition to our results of operations, which affect the amount of cashwe generate internally, financing activities such as (i) retirement of debt securities,(ii) the November 2001 maturity of our premium equity participating security units and(iii) reacquisition of our common stock under our stock repurchase program impact thesebalances in various periods. Additional information on these matters is contained under"Cash Flows" following and in Notes 11 and 13 of the accompanying Notes toConsolidated Financial Statements.

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

34

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 11 of the accompanying Notesto Consolidated Financial Statements.
**June 30,**December 31,**2003**2002**2001**2000
(Dollars in    thousands)Long-term Debt:     Outstanding    
$2,842,440 
$2,852,181 
$2,409,798 
$2,478,983      Value    of Interest Rate Swaps1
   185,623 
   139,589 
    (4,831)
         - 
3,028,063 
2,991,770 
2,404,967 
2,478,983 Minority Interests 
   983,346 
   967,802 
   817,513 
     4,910 Common Equity 
 2,540,713 
 2,354,997 
 2,259,997 
 1,777,624 Capital Securities 
   275,000 
   275,000 
   275,000 
   275,000 
 6,827,122 
 6,589,569 
 5,757,477 
 4,536,517 Less: Value of Interest Rate    Swaps 
  (185,623)
  (139,589)
     4,831 
         -      Capitalization    
 6,641,499 
 6,449,980 
 5,762,308 
 4,536,517 Short-term Debt, Less Cash and    Cash Equivalents2
   191,568 
   465,614 
   613,918 
   766,244      Invested    Capital 
$6,833,067 
$6,915,594 
$6,376,226 
$5,302,761 
========== 
========== 
========== 
==========   Capitalization:     Outstanding    Long-term Debt 
42.8%
44.2%
41.8%
54.6%     Minority    Interests 
14.8%
15.0%
14.2%
 0.1%     Common    Equity 
38.3%
36.5%
39.2%
39.2%     Capital    Securities 
 4.1%
 4.3%
 4.8%
 6.1%  Invested Capital:     Total    Debt (Excluding Interest Rate Swaps) 
44.4%
48.0%
47.4%
61.2%     Equity,    Including Capital Securities and Minority           Interests 
55.6%
52.0%
52.6%
38.8%    1See Note 16 of the accompanying Notes to    Consolidated Financial Statements.2
Cash and cash equivalents    netted against short-term debt were $29,932, $35,653, $16,134 and $141,923 for June 30,    2003 and December 31, 2002, 2001 and 2000, respectively.
Certain of our customers are experiencing financial problems that havehad a significant impact on their creditworthiness. We are working to implement, to theextent allowable under applicable laws, tariffs 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 June 30, 2003, wehad repurchased a total of approximately $417.2 million (8,361,800 shares) of ouroutstanding common stock under the program, of which $1.1 million (22,500 shares) and $2.5million (53,600 shares) were repurchased in the three months and six months ended June 30,2003, respectively.

On May 15, 2003, Kinder Morgan Management paid a share distribution of859,933 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. On August 14,2003, Kinder Morgan Management will pay a share distribution of 811,878 of its shares toshareholders of record as of July 31, 2003, based on the $0.65 per 

35

common unit distribution declared by Kinder Morgan Energy Partners forthe second quarter of 2003. These distributions are paid in the form of additional sharesor fractions 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. Kinder Morgan Management has paid sharedistributions totaling 1,718,914 shares in the six months ended June 30, 2003.

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 $176.3 million for the six months ended June 30, 2002 to $296.8 million for the sixmonths ended June 30, 2003, an increase of $120.5 million (68.3%). This positive varianceis principally due to (i) an increase of $36.9 million in 2003 earnings beforedepreciation and amortization expense, deferred income taxes and equity in earnings ofKinder Morgan Energy Partners, (ii) a $28.7 million increase in cash distributionsreceived in 2003 attributable to our interests in Kinder Morgan Energy Partners, (iii)$28.1 million of cash proceeds received in 2003 from termination of an interest rate swap,(iv) an increase of $84.4 million in cash inflows for gas in underground storage during2003 and (v) the fact that cash flows for the first six months of 2002 included $22.1million and $18.9 million of cash outflows for a litigation settlement and pensioncontribution, respectively. These positive impacts were partially offset by (i) anincrease of $15.3 million in 2003 cash outflows for deferred purchased gas costs and (ii)an increased 2003 use of cash for miscellaneous working capital of $92.1 million (see Note5 of the accompanying Notes to Consolidated Financial Statements).

Net Cash Flows from Investing Activities

"Net Cash Flows Used in Investing Activities" decreased from$239.9 million for the six months ended June 30, 2002 to $49.2 million for the six monthsended June 30, 2003, a decrease of $190.6 million (79.5%). This decreased use of cash isprincipally due to the fact that the first six months of 2002 included (i) $15.7 millionin capital expenditures for the Natural Gas Pipeline Company of America pipeline extensionto East St. Louis, Illinois, (ii) a $137.5 million cash outflow for incrementalinvestments in power plant facilities and (iii) a $16.5 million investment in HorizonPipeline Company. 

Net Cash Flows from Financing Activities

"Net Cash Flows (Used in) Provided by Financing Activities"decreased from a source of $64.8 million for the six months ended June 30, 2002 to a useof $253.3 million for the six months ended June 30, 2003, a decrease of $318.1 million.This decrease is principally due to $500 million of cash used during the six months endedJune 30, 2003 to retire our $500 million 6.45% Senior Notes and an increase of $24.3million paid in 2003 for dividends, principally due to the increased dividends declaredper share. Partially offsetting these factors were (i) a $137.4 million decreased use ofcash during 2003 to repurchase shares and (ii) a $74.1 million increased source of cashfrom short-term advances to unconsolidated affiliates during 2003.

36

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 June 30, 2003, we had $221.5 million ofcommercial paper (which is backed by the bank facilities) issued and outstanding. At July31, 2003, we had $179.8 million of commercial paper issued and outstanding. Afterinclusion of applicable letters of credit, the remaining available borrowing capacityunder the bank facilities was $547.2 million and $588.9 million at June 30, 2003 and July31, 2003, respectively. For additional information on utilization of these facilities, seeNote 11 of the accompanying Notes to Consolidated Financial Statements.

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$32.2 million at June 30, 2003. 

As further described in Note 16 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 $162.2 million at June 30, 2003. These swaps are accounted for as hedgesunder Statement of Financial Accounting Standards ("SFAS") No. 133, *Accountingfor Derivative Instruments and Hedging Activities*.
**Change in Compensation Policies**
On July 16, 2003, we announced a change to our compensation policies.Chairman and Chief Executive Officer Richard D. Kinder will continue to receive $1 peryear in salary with no bonuses, stock options, grants of restricted stock or othercompensation. The ten most senior executives (excluding Mr. Kinder) will continue to havetheir base salaries capped at $200,000 per year and will continue to be eligible forannual bonuses when we and Kinder Morgan Energy Partners meet annual earnings per shareand distributions per unit targets. In addition, these senior executives will no longer beeligible for future stock option grants and have received grants of restricted stock whichwill vest 25 percent after three years and the remaining 75 percent after five years. Weexpect that executives will receive no further equity compensation during the five-yearlife of these restrictions. In total, 575,000 restricted shares of our common stock havebeen issued under a shareholder approved plan. As a result, we and Kinder Morgan EnergyPartners will each expense approximately $3.5 million annually related to the grants ofrestricted stock. Other than restricted stock, executives will continue to have only thosebenefits which are available to all other employees. All other employees will be eligiblefor annual grants of stock options which will vest after three years. On July 16, 2003, weissued 656,450 options to purchase our common shares for $53.80 (the closing price of ourcommon shares on that date) to eligible employees. We expect to issue to employees fewerthan 700,000 options to purchase our common shares annually.

The reader is directed to Part II, Item 5 for further informationregarding the retention agreement of C. Park Shaper.

We and Kinder Morgan Energy Partners have, collectively, agreed toguarantee potential borrowings under lines of credit available from Wachovia Bank,National Association, formerly known as First Union National Bank, to Messrs. ThomasBannigan, C. Park Shaper and James Street and Ms. Deborah Macdonald. Each of theseofficers is primarily liable for any borrowing on his or her line of credit, and if we orKinder Morgan Energy Partners makes any payment with respect to an outstanding loan, theofficer on behalf of whom payment is made must surrender a percentage of his or heroptions to purchase our common stock. Our and Kinder Morgan Energy Partners' currentobligations under the guaranties generally do not exceed $1.0 million in respect of anysuch officer individually and such 

37

obligations, in the aggregate, do not exceed $1.9 million. To date, weand Kinder Morgan Energy Partners have made no payment with respect to these lines ofcredit. Further, we and Kinder Morgan Energy Partners' involvement in these lines ofcredit will expire in October 2003.
**Recent Accounting Pronouncements**
FASB Interpretation No. 46, *Consolidation of Variable InterestEntities*
In January 2003, the Financial Accounting Standards Board("FASB") issued Interpretation No. 46, *Consolidation of Variable InterestEntities*. This interpretation of Accounting Research Bulletin No. 51, *ConsolidatedFinancial Statements*, addresses consolidation by business enterprises of variableinterest entities (some, but not all, of which have been referred to as "specialpurpose entities") with certain defined characteristics. One provision of theinterpretation increases the minimum amount of third-party investment required to supportnon-consolidation from 3% to 10%. Certain of the disclosure provisions contained in theinterpretation are effective for financial statements issued after January 31, 2003, allof the provisions are immediately applicable to variable interest entities created afterJanuary 31, 2003 and public entities with variable interests in entities created beforeFebruary 1, 2003 are required to apply the provisions (other than the transitiondisclosure provisions) to that entity no later than the beginning of the first interim orannual reporting period beginning after June 15, 2003.

The principal impact of this interpretation on us is that, uponimplementation, we expect to begin consolidation of Triton Power Company LLC and itswholly owned subsidiary, Triton Power Michigan LLC, the lessee of the Jackson, Michiganpower generation facility. We operate the Jackson facility and have a preferred interestin Triton Power Company LLC, in which the common interest is owned by others. Neitherentity has debt but, as a result of this consolidation, we will include the leaseobligation on the Jackson plant in our consolidated financial statements. We expect toapply the provisions of the statement beginning with the third quarter of 2003 and, atthat time, the total remaining lease payments will be $553.5 million and will be $21.7million, $20.3 million, $20.3 million, $20.4 million and $20.6 million for 2004 through2008, respectively. The difference between the earnings impact under consolidation andunder the currently-applied cost method is not expected to be material.

In addition, a preliminary conclusion has been reached that the trustswhich are our wholly owned subsidiaries that issued our trust preferred trust securitiesare variable interest entities for purposes of applying this statement and, further, thatupon application of this statement these trusts would no longer be consolidated. Assumingthat this conclusion is not changed, we expect that, upon application of the statement,(i) an amount equal to the carrying value of the trust preferred securities will bereported as part of long-term debt in our consolidated balance sheet and (ii) we willclassify future payments made by us in conjunction with the trust preferred securities asinterest expense, rather than minority interest.

Statement of Financial Accounting Standards No. 149, *Amendment ofStatement 133 on Derivative Instruments and Hedging Activities*
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;
38
  •
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 require that contracts withcomparable characteristics be accounted for similarly. In particular, this statementclarifies under what circumstances a contract with an initial net investment meets thecharacteristic of a derivative as discussed in SFAS No. 133. In addition, it clarifieswhen a derivative contains a financing component that warrants special reporting in thestatement of cash flows. SFAS No. 149 amends certain other existing pronouncements. Thosechanges will result in more consistent reporting of contracts that are derivatives intheir entirety or that contain embedded derivatives that warrant 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 do not expect the impacts ofadopting this statement on our financial position or results of operations to be material.

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. 

Statement of Financial Accounting Standards No. 150, *Accounting forCertain Financial Instruments with Characteristics of Both Liabilities and Equity*.

In May 2003, the FASB issued SFAS No. 150, *Accounting for CertainFinancial Instruments with Characteristics of Both Liabilities and Equity*. Thisstatement establishes standards for how an issuer classifies and measures certainfinancial instruments with characteristics of both liabilities and equity. It requiresthat an issuer classify a financial instrument that is within its scope as a liability (oran asset in some circumstances). Many of those instruments were previously classified asequity.

SFAS No. 150 requires an issuer to classify the following instrumentsas liabilities (or assets in some circumstances):
•
a financial instrument issued in the form    of shares that is mandatorily redeemable - that embodies an unconditional obligation    requiring the issuer to redeem it by transferring its assets at a specified or    determinable date (or dates) or upon an event that is certain to occur;
  •
a financial instrument, other than an    outstanding share, that, at inception, embodies an obligation to repurchase the issuer's    equity shares, or is indexed to such an obligation, and that requires or may require the    issuer to settle the obligation by transferring assets (for example, a forward purchase    contract or written put option on the issuer's equity shares that is to be physically    settled or net cash settled); and
  •
a financial instrument that embodies an    unconditional obligation, or a financial instrument other than an outstanding share that    embodies a conditional obligation, that the issuer must or may settle by issuing a    variable number of its equity shares, if, at inception, the monetary value of the    obligation is based solely or predominantly on any of the following:
39
    •
a fixed monetary amount known at    inception, for example, a payable settleable with a variable number of the issuer's equity    shares;    •
variations in something other than the    fair value of the issuer's equity shares, for example, a financial instrument indexed to    the Standard & Poor's 500 and settleable with a variable number of the issuer's equity    shares; or    •
variations inversely related to changes in    the fair value of the issuer's equity shares, for example, a written put option that could    be net share settled.
The requirements of this statement apply to issuers' classification andmeasurement of freestanding financial instruments, including those that comprise more thanone option or forward contract. This statement does not apply to features that areembedded in a financial instrument that is not a derivative in its entirety. It also doesnot affect the classification or measurement of convertible bonds, puttable stock, orother outstanding shares that are conditionally redeemable. This statement also does notaddress certain financial instruments indexed partly to the issuer's equity shares andpartly, but not predominantly, to something else.

This statement is effective for financial instruments entered into ormodified after May 31, 2003, and otherwise is effective at the beginning of the firstinterim period beginning after June 15, 2003, except for mandatorily redeemable financialinstruments of nonpublic entities. It is to be implemented by reporting the cumulativeeffect of a change in accounting principle for financial instruments created before theissuance date of the statement and still existing at the beginning of the interim periodof adoption. Restatement is not permitted. In the event that, under the provisions of FASBInterpretation No. 46, our wholly owned subsidiary trusts which issued our preferred trustsecurities are determined not to be variable interest entities or if they are determinedto be variable interest entities but continued consolidation is determined to beappropriate, we expect that the provisions of this statement will, upon implementation,result in (i) the reclassification of our trust preferred securities to the debt portionof our balance sheet and (ii) the classification of future payments made by us inconjunction with the trust preferred securities as interest expense, rather than minorityinterest.
**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;
40
    •
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;    •
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
41
    •
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 actualresults to differ materially from those contained in any forward-looking statement. Wedisclaim any obligation to update the above list or to announce publicly the result of anyrevisions to any of the forward-looking statements to reflect future events ordevelopments. Our future results also could be adversely impacted by unfavorable resultsof litigation and the coming to fruition of contingencies referred to in Notes 17 and 18of the accompanying Notes to Consolidated Financial Statements.
***Item 3.  Quantitative and Qualitative Disclosures aboutMarket 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 16 of the accompanying Notes to Consolidated Financial Statements.
***Item 4.  Controls and Procedures.***
As of the end of the quarter ended June 30, 2003, our management,including our Chief Executive Officer and Chief Financial Officer, has evaluated theeffectiveness of the design and operation of our disclosure controls and procedurespursuant to Rule 13a-15(b) under the Securities Exchange Act of 1934. Based upon thatevaluation, our Chief Executive Officer and Chief Financial Officer concluded that thedesign and operation of our disclosure controls and procedures were effective.

There has been no change in our internal control over financialreporting during the quarter ended June 30, 2003 that has materially affected, or isreasonably likely to materially affect, our internal control over financial reporting.

42
**PART II - OTHER INFORMATION
*Item 1.  Legal Proceedings.***
The reader is directed to Note 18 of the accompanying Notes toConsolidated Financial Statements in Part I, Item 1, which is incorporated herein byreference.***Item 2.  Changes in Securities and Use of Proceeds.***
During the quarter ended June 30, 2003, we did not sell any equitysecurities that were not registered under the Securities Act of 1933, as amended.
***Item 3.  Defaults Upon Senior Securities.***
None.
***Item 4.  Submission of Matters to a Vote of Security Holders.***a)
The Company held its Annual Meeting of    Shareholders on May 8, 2003 (the "Annual Meeting").  b)
Proxies for the Annual Meeting were    solicited pursuant to Regulation 14A of the Securities Exchange Act of 1934. There was no    solicitation in opposition to management's nominees for directors as listed in the Proxy    Statement and all such nominees were elected, which included Messrs. Kinder, Austin, Hybl    and Gardner. In addition, those directors continuing in office after the meeting included    Messrs. Battey, Bliss, Morgan, Randall, Sarofim and True. The number of votes for and    withheld for the nominees elected at the meeting were as follows:**For**WithheldRichard D. Kinder
97,835,239
12,493,527Edward H. Austin, Jr.
106,297,595
4,031,171William J. Hybl
107,034,616
3,294,150Ted A. Gardner
106,943,865
3,384,901  c)
The following matters were also voted on    at the Annual Meeting:    (1)
A proposal to ratify and approve the    selection of PricewaterhouseCoopers LLP as our independent auditors for 2003 was approved    and the number of affirmative votes, negative votes, abstentions and broker non-votes with    respect to the matter were as follows:  For
107,516,377Against
2,237,023Abstain
575,366Broker Non-votes
N/A
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    (2)
A stockholder proposal relating to the    adoption of an executive compensation policy requiring the use of indexed stock options    was not approved and the number of affirmative votes, negative votes, abstentions and    broker non-votes with respect to the matter were as follows:  For
5,966,778Against
85,373,287Abstain
958,613Broker Non-votes
N/A  (3)
A stockholder proposal relating to    establishing a policy of expensing the costs of all future stock options was not approved    and the number of affirmative votes, negative votes, abstentions and broker non-votes with    respect to the matter were as follows:  For
28,278,890Against
62,401,564Abstain
1,618,220Broker Non-votes
N/A***Item 5.  Other Information.

Certain Relationships and Related Transactions**
Retention Agreement*
Effective January 17, 2002, we entered into a retention agreement withC. Park Shaper, an officer of us, Kinder Morgan G.P., Inc. (the general partner of KinderMorgan Energy Partners) and its delegate, Kinder Morgan Management. Pursuant to the termsof the agreement, Mr. Shaper obtained a $5 million personal loan guaranteed by KinderMorgan Energy Partners and us. Mr. Shaper was required to purchase and did purchase ourcommon stock and Kinder Morgan Energy Partners' common units in the open market with theloan proceeds. 

The Sarbanes-Oxley Act of 2002 does not allow companies to issue orguarantee new loans to executives, but it "grandfathers" loans that were inexistence prior to the act. Regardless, Mr. Shaper and we have agreed that in today'sbusiness environment it would be prudent for him to repay the loan. In conjunction withthis decision, Mr. Shaper has sold 37,000 of our shares and 82,000 of Kinder Morgan EnergyPartner's common units. He used the proceeds to repay the $5 million personal loanguaranteed by Kinder Morgan Energy Partners and us. Kinder Morgan Energy Partners' and ourguarantee of this loan has been removed. Mr. Shaper will instead participate in ourrestricted stock plan with other senior executives.

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***Item 6.  Exhibits and Reports on Form 8-K.*****  ****(A)     Exhibits.  31.1          31.2          32.1            32.2Section 13a - 14(a) / 15d - 14(a) Certification of Chief    Executive Officer    Section 13a - 14(a) / 15d - 14(a) Certification of Chief Financial Officer          Section 1350 Certification of Chief Executive Officer    Section 1350 Certification of Chief Financial Officer**  ****  ****(B)     Reports on Form 8-K.****  ****  ****(1)**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.**  ****  ****(2)**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.**  ****  ****(3)**Current Report on Form 8-K dated June    9, 2003 was furnished as of June 6, 2003 pursuant to Item 9. of that form.**  ****  
We announced our intention to make    presentations on June 9, 2003 at the Deutsche Bank Conference to investors, analysts and    others, in order to address various strategic and financial issues relating to the    business plans and objectives of 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 August    4, 2003 was furnished as of August 5, 2003 pursuant to Item 9. of that form.**  ****  
We announced our intention to make    presentations on August 5, 2003 and August 6, 2003 at various meetings with investors,    analysts and others, in order to discuss the second quarter and year-to-date financial    results, business plans and objectives of 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.
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**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)            August 8, 2003/s/ C.    Park ShaperC. Park Shaper    Vice President, Treasurer and Chief Financial Officer    (Principal Financial and Accounting Officer)
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