PEOPLES ENERGY CORP (Form: 10-Q, Received: 08/10/2004 17:04:34)

FORM 10-Q

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
(Mark One)

[ X ]	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period Ended June 30, 2004
OR
[ ]	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

	Exact Name of Registrant as
	Specified in Charter, State of
	Incorporation, Address of
Commission	Principal Executive		IRS Employer
File Number	Office and Telephone Number		Identification Number
1-5540	PEOPLES ENERGY CORPORATION		36-2642766
2-26983	THE PEOPLES GAS LIGHT AND COKE COMPANY		36-1613900
2-35965	NORTH SHORE GAS COMPANY		36-1558720

	(Illinois Corporations)
	130 East Randolph Drive, 24 ^th Floor
	Chicago, Illinois 60601-6207
	Telephone (312) 240-4000

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes [x] No [ ]

Indicate by a check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act).
Peoples Energy Corporation		Yes [x] No [ ]
The Peoples Gas Light and Coke Company		Yes [ ] No [x]
North Shore Gas Company		Yes [ ] No [x]

Indicate the number of shares outstanding of each of the issuer's classes of common stock as of the latest practicable date (July 31, 2004):

Peoples Energy Corporation	Common Stock, no par value, 37,630,892 shares outstanding
The Peoples Gas Light and Coke Company	Common Stock, no par value, 24,817,566 shares outstanding (all of which are owned beneficially and of record by Peoples Energy Corporation)
North Shore Gas Company	Common Stock, no par value, 3,625,887 shares outstanding (all of which are owned beneficially and of record by Peoples Energy Corporation)

This combined Form 10-Q is separately filed by Peoples Energy Corporation, The Peoples Gas Light and Coke Company, and North Shore Gas Company. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company makes no representation as to information relating to the other companies. The Peoples Gas Light and Coke Company and North Shore Gas Company meet the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and are therefore filing this Form 10-Q with the reduced disclosure format permitted by General Instruction H(2) of Form 10-Q.

Part I - Financial Information

Item 1. Financial Statements

Peoples Energy Corporation
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)


	Three Months Ended		Nine Months Ended
	June 30,		June 30,
	2004	2003	2004	2003
(In Thousands, Except Per-Share Amounts)
Revenues	$ 401,137	$ 398,147	$ 1,933,042	$ 1,851,092

Operating Expenses:
Cost of energy sold	247,146	238,092	1,260,197	1,165,829
Operation and maintenance	83,739	84,058	270,106	261,570
Depreciation, depletion and amortization	29,749	27,658	89,641	83,135
Taxes, other than income taxes	29,761	27,729	148,508	144,835
Gains on property sales	(1,476)	-	(1,476)	-
Total Operating Expenses	388,919	377,537	1,766,976	1,655,369

Equity investment income (loss)	4,866	3,811	6,110	3,545

Operating Income	17,084	24,421	172,176	199,268

Other income and expense - net	918	661	2,299	1,751

Interest expense	11,758	12,004	36,420	37,376

Income Before Income Taxes	6,244	13,078	138,055	163,643

Income tax expense	621	5,065	46,178	61,148

Net Income	$ 5,623	$ 8,013	$ 91,877	$ 102,495

Average Shares of Common Stock Outstanding
Basic	37,549	36,265	37,212	35,867
Diluted	37,722	36,435	37,393	35,999

Earnings Per Share of Common Stock
Basic	$ 0.15	$ 0.22	$ 2.47	$ 2.86
Diluted	$ 0.15	$ 0.22	$ 2.46	$ 2.85

Dividends Declared Per Share	$ 0.54	$ 0.53	$ 1.61	$ 1.58

The Notes to Consolidated Financial Statements are an integral part of these statements.

Peoples Energy Corporation

CONSOLIDATED BALANCE SHEETS
(Unaudited)

	June 30,	September 30,	June 30,
(In Thousands)	2004	2003	2003
ASSETS
CAPITAL INVESTMENTS:
Property, plant and equipment
Utility plant	$ 2,600,526	$ 2,552,464	$ 2,532,654
Oil and gas	473,067	391,135	372,238
Other	20,450	18,357	17,092
Total property, plant and equipment	3,094,043	2,961,956	2,921,984
Less - Accumulated depreciation, depletion and amortization	1,201,012	1,123,783	1,103,946
Net property, plant and equipment	1,893,031	1,838,173	1,818,038
Investment in equity investees	130,950	142,142	137,216
Other investments	23,847	21,768	20,112
Total Capital Investments - Net	2,047,828	2,002,083	1,975,366

CURRENT ASSETS:
Cash and cash equivalents	75,900	13,648	52,007
Deposits with broker or trustee	15,493	19,361	18,368
Receivables -
Customers, net of reserve for uncollectible accounts
of $31,267, $33,185, and $33,318, respectively	267,880	212,901	313,455
Other	31,447	9,036	24,549
Materials and supplies, at average cost	10,083	9,754	9,841
Gas in storage	98,010	165,583	78,430
Gas costs recoverable through rate adjustments	21,878	22,665	32,319
Regulatory assets of utility subsidiaries	26,307	27,279	4,914
Other	14,701	9,917	8,387
Total Current Assets	561,699	490,144	542,270

OTHER ASSETS:
Prepaid pension costs	184,059	186,961	189,763
Noncurrent regulatory assets of utility subsidiaries	187,261	181,223	187,204
Deferred charges and other	74,143	68,127	41,639
Total Other Assets	445,463	436,311	418,606

Total Assets	$ 3,054,990	$ 2,928,538	$ 2,936,242

The Notes to Consolidated Financial Statements are an integral part of these statements.

Peoples Energy Corporation

CONSOLIDATED BALANCE SHEETS
(Unaudited)

	June 30,	September 30,	June 30,
(In Thousands, Except Shares)	2004	2003	2003
CAPITALIZATION AND LIABILITIES
CAPITALIZATION:
Common Stockholders' Equity:
Common stock, no par value -
Authorized 60,000,000 shares
Issued 37,826,054, 36,936,068 and
36,863,602 shares, respectively	$ 381,864	$ 346,545	$ 343,430
Treasury stock - 243,100, 246,100 and 246,100 shares, respectively	(6,677)	(6,760)	(6,760)
Retained earnings	581,756	549,969	567,976
Accumulated other comprehensive loss	(66,390)	(41,755)	(28,988)
Total Common Stockholders' Equity	890,553	847,999	875,658

Long-term debt, exclusive of maturities due within one
year and adjustable-rate bonds classified as short-term debt	846,330	744,345	744,345
Total Capitalization	1,736,883	1,592,344	1,620,003

CURRENT LIABILITIES:
Commercial paper	-	55,949	-
Adjustable-rate bonds classified as short-term debt	50,000	152,000	152,000
Accounts payable	187,356	148,769	184,409
Accrued taxes	51,726	45,730	76,067
Other accrued liabilities	134,328	98,870	97,846
Regulatory liabilities of utility subsidiaries	17,502	-	24,246
Dividends payable	20,293	19,446	19,407
Customer deposits	28,619	26,369	23,833
Customer credit balances	26,820	48,402	25,089
Gas costs refundable through rate adjustments	29	5,039	5,967
Temporary LIFO liquidation credit	50,539	-	47,916
Total Current Liabilities	567,212	600,574	656,780

DEFERRED CREDITS AND OTHER LIABILITIES:
Deferred income taxes	401,829	407,835	387,176
Investment tax credits	26,818	27,642	27,741
Environmental, pension and other	322,248	300,143	244,542
Total Deferred Credits and Other Liabilities	750,895	735,620	659,459

Total Capitalization and Liabilities	$ 3,054,990	$ 2,928,538	$ 2,936,242

The Notes to Consolidated Financial Statements are an integral part of these statements.

Peoples Energy Corporation
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

	Nine Months Ended
	June 30,
(In Thousands)	2004	2003
Operating Activities:
Net income	$ 91,877	$ 102,495
Adjustments to reconcile net income to cash provided by operations:
Depreciation, depletion and amortization	93,765	86,816
Deferred income taxes and investment tax credits - net	9,106	14,645
Change in environmental, pension and other liabilities	6,475	31,008
Change in undistributed earnings from equity investments	(383)	10,497
Other changes in noncurrent operating activities	(24,328)	(46,952)
Changes in current assets and liabilities:
Receivables - net	(77,390)	(114,424)
Gas in storage	67,573	11,138
Gas costs recoverable/refundable through rate adjustments	(4,223)	(16,162)
Net regulatory assets/liabilities of utility subsidiaries	18,474	7,630
Payables and other accrued liabilities	49,132	98,083
Accrued taxes	5,996	28,784
Temporary LIFO liquidation credit	50,539	47,916
Other	(24,446)	(23,799)
Net Cash Provided by Operating Activities	262,167	237,675

Investing Activities:
Capital spending	(144,855)	(133,326)
Return of capital investments	11,576	7,134
Decrease in deposits with broker or trustee	3,868	10,277
Proceeds from the sale of assets	1,250	-
Other	(73)	(1,721)
Net Cash Used in Investing Activities	(128,234)	(117,636)

Financing Activities:
Proceeds from (payment of) overdrafts	14,045	(21,632)
Retirement of commercial paper	(55,949)	(85,871)
Retirement of short-term debt	(102,000)	(140,000)
Issuance of long-term debt	177,000	265,000
Retirement of long-term debt	(75,015)	(74,669)
Long-term debt issuance/retirement costs	(5,954)	(2,037)
Issuance of common/treasury stock	35,402	41,731
Dividends paid on common stock	(59,210)	(55,987)
Net Cash Used in Financing Activities	(71,681)	(73,465)

Net Increase in Cash and Cash Equivalents	62,252	46,574
Cash and Cash Equivalents at Beginning of Period	13,648	5,433
Cash and Cash Equivalents at End of Period	$ 75,900	$ 52,007

Supplemental Information:
Income taxes paid	$ 12,149	$ 10,973
Interest paid	$ 31,281	$ 31,545

The Notes to Consolidated Financial Statements are an integral part of these statements.

The Peoples Gas Light and Coke Company
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)


	Three Months Ended		Nine Months Ended
	June 30,		June 30,
	2004	2003	2004	2003
(In Thousands)
Revenues	$ 202,279	$ 228,429	$ 1,150,188	$ 1,159,241

Operating Expenses:
Gas costs	98,929	115,317	668,426	645,474
Operation and maintenance	58,528	61,322	197,235	196,191
Depreciation and amortization	15,694	15,136	46,055	44,882
Taxes, other than income taxes	23,237	20,920	124,716	121,224
Gains on property sales	(111)	-	(111)	-
Total Operating Expenses	196,277	212,695	1,036,321	1,007,771

Operating Income	6,002	15,734	113,867	151,470

Other income and expense - net	767	500	2,022	1,647

Interest expense	4,934	5,311	15,601	17,115

Income Before Income Taxes	1,835	10,923	100,288	136,002

Income tax expense (credit)	(618)	4,370	36,774	51,458

Net Income	$ 2,453	$ 6,553	$ 63,514	$ 84,544

The Notes to Consolidated Financial Statements are an integral part of these statements.

The Peoples Gas Light and Coke Company

CONSOLIDATED BALANCE SHEETS
(Unaudited)


	June 30,	September 30,	June 30,
	2004	2003	2003
(In Thousands)
ASSETS
CAPITAL INVESTMENTS:
Property, plant and equipment	$ 2,246,808	$ 2,203,842	$ 2,185,851
Less - Accumulated depreciation and amortization	894,146	858,838	850,595
Net property, plant and equipment	1,352,662	1,345,004	1,335,256
Other investments	2,012	1,969	2,381
Total Capital Investments - Net	1,354,674	1,346,973	1,337,637

CURRENT ASSETS:
Cash and cash equivalents	45,960	-	8,620
Deposits with broker or trustee	772	11,080	10,158
Receivables -
Customers, net of reserve for uncollectible accounts
of $27,423, $29,207 and $29,454, respectively	163,369	131,248	206,540
Intercompany receivables	29,447	27,094	27,452
Other	3,417	2,971	4,082
Materials and supplies, at average cost	8,874	8,404	8,571
Gas in storage, at last-in, first-out cost	40,196	111,992	36,847
Gas costs recoverable through rate adjustments	18,082	22,341	32,308
Regulatory assets	24,372	23,223	3,916
Other	4,238	3,456	2,517
Total Current Assets	338,727	341,809	341,011

OTHER ASSETS:
Prepaid pension costs	176,122	178,003	189,764
Noncurrent regulatory assets	149,363	141,987	148,113
Deferred charges and other	48,546	47,073	29,569
Total Other Assets	374,031	367,063	367,446

Total Assets	$ 2,067,432	$ 2,055,845	$ 2,046,094

The Notes to Consolidated Financial Statements are an integral part of these statements.

The Peoples Gas Light and Coke Company

CONSOLIDATED BALANCE SHEETS
(Unaudited)


	June 30,	September 30,	June 30,
	2004	2003	2003
(In Thousands, Except Shares)
CAPITALIZATION AND LIABILITIES
CAPITALIZATION:
Common Stockholder's Equity:
Common stock, without par value -
Authorized 40,000,000 shares
Outstanding 24,817,566 shares	$ 165,307	$ 165,307	$ 165,307
Retained earnings	499,830	482,228	503,014
Accumulated other comprehensive loss	(21,019)	(21,052)	(911)
Total Common Stockholder's Equity	644,118	626,483	667,410

Long-term debt, exclusive of maturities due within one
year and adjustable-rate bonds classified as short-term debt	452,000	350,000	350,000
Total Capitalization	1,096,118	976,483	1,017,410

CURRENT LIABILITIES:
Commercial paper	-	55,949	-
Other short-term debt	50,000	176,400	152,000
Accounts payable	91,457	83,409	89,427
Accrued taxes	58,209	29,421	70,888
Other accrued liabilities	54,161	43,892	38,550
Intercompany payables	17,805	45,720	25,267
Regulatory liabilities	14,758	-	20,908
Dividends payable	13,200	-	17,400
Customer deposits	26,546	24,470	22,237
Customer credit balances	21,741	39,728	21,587
Gas costs refundable through rate adjustments	29	28	2,285
Temporary LIFO liquidation credit	36,227	-	32,386
Total Current Liabilities	384,133	499,017	492,935

DEFERRED CREDITS AND OTHER LIABILITIES:
Deferred income taxes	355,862	355,160	353,892
Investment tax credits	23,892	24,634	24,718
Environmental, pension and other	207,427	200,551	157,139
Total Deferred Credits and Other Liabilities	587,181	580,345	535,749

Total Capitalization and Liabilities	$ 2,067,432	$ 2,055,845	$ 2,046,094

The Notes to Consolidated Financial Statements are an integral part of these statements.

The Peoples Gas Light and Coke Company
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

	Nine Months Ended
	June 30,
	2004	2003
(In Thousands)
Operating Activities:
Net income	$ 63,514	$ 84,544
Adjustments to reconcile net income to cash provided by operations:
Depreciation and amortization	49,607	48,160
Deferred income taxes and investment tax credits - net	(1,558)	4,516
Change in environmental, pension and other liabilities	8,394	10,222
Other changes in noncurrent operating activities	(1,538)	(20,288)
Changes in current assets and liabilities:
Receivables - net	(34,920)	(85,289)
Gas in storage	71,796	28,517
Gas costs recoverable/refundable through rate adjustments	4,260	(22,993)
Net regulatory assets/liabilities	13,609	9,976
Payables and other accrued liabilities	(22,327)	50,957
Accrued taxes	28,788	33,078
Temporary LIFO liquidation credit	36,227	32,386
Other	(17,166)	(17,329)
Net Cash Provided by Operating Activities	198,686	156,457

Investing Activities:
Capital spending	(46,249)	(46,555)
Decrease in deposits with broker or trustee	10,308	11,644
Other	(81)	-
Net Cash Used in Investing Activities	(36,022)	(34,911)

Financing Activities:
Proceeds from (payment of) overdrafts	2,168	(16,277)
Retirement of commercial paper	(55,949)	(82,671)
Retirement of short-term debt	(126,400)	(140,475)
Issuance of long-term debt	177,000	225,000
Retirement of long-term debt	(75,000)	(50,000)
Long-term debt issuance/retirement costs	(5,923)	(1,391)
Dividends paid on common stock	(32,600)	(47,112)
Net Cash Used in Financing Activities	(116,704)	(112,926)

Net Increase in Cash and Cash Equivalents	45,960	8,620
Cash and Cash Equivalents at Beginning of Period	-	-
Cash and Cash Equivalents at End of Period	$ 45,960	$ 8,620

Supplemental Information:
Income taxes paid	$ 5,932	$ 3,771
Interest paid	$ 15,923	$ 16,194

The Notes to Consolidated Financial Statements are an integral part of these statements.

North Shore Gas Company
CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)


	Three Months Ended		Nine Months Ended
	June 30,		June 30,
	2004	2003	2004	2003
(In Thousands)
Revenues	$ 33,678	$ 40,313	$ 198,825	$ 208,526

Operating Expenses:
Gas costs	19,707	24,871	131,330	137,917
Operation and maintenance	8,300	8,132	26,637	24,048
Depreciation	1,784	1,769	5,386	5,284
Taxes, other than income taxes	2,840	2,952	13,735	14,266
Gains on property sales	(1,130)	-	(1,130)	-
Total Operating Expenses	31,501	37,724	175,958	181,515

Operating Income	2,177	2,589	22,867	27,011

Other income and expense - net	82	77	130	(85)

Interest expense	911	825	2,776	2,688

Income Before Income Taxes	1,348	1,841	20,221	24,238

Income tax expense	427	982	7,489	9,379

Net Income	$ 921	$ 859	$ 12,732	$ 14,859

The Notes to Consolidated Financial Statements are an integral part of these statements.

North Shore Gas Company

CONSOLIDATED BALANCE SHEETS
(Unaudited)


	June 30,	September 30,	June 30,
	2004	2003	2003
(In Thousands)
ASSETS
CAPITAL INVESTMENTS:
Property, plant and equipment	$ 353,718	$ 348,622	$ 346,803
Less - Accumulated depreciation	140,625	136,299	135,809
Net property, plant and equipment	213,093	212,323	210,994

CURRENT ASSETS:
Cash and cash equivalents	20,747	12,108	29,839
Deposits with broker or trustee	813	2,766	2,274
Receivables -
Customers, net of reserve for uncollectible
accounts of $1,024, $1,012 and $1,107, respectively	29,221	16,090	25,829
Intercompany receivables	4,529	1,466	2,668
Other	1,622	800	762
Materials and supplies, at average cost	1,209	1,351	1,270
Gas in storage, at last-in, first-out cost	5,856	9,442	4,481
Gas costs recoverable through rate adjustments	3,796	323	11
Regulatory assets	1,935	4,055	999
Other	517	202	330
Total Current Assets	70,245	48,603	68,463

OTHER ASSETS:
Noncurrent regulatory assets	37,898	39,236	39,091
Deferred charges and other	3,208	3,980	2,775
Total Other Assets	41,106	43,216	41,866

Total Assets	$ 324,444	$ 304,142	$ 321,323

The Notes to Consolidated Financial Statements are an integral part of these statements.

North Shore Gas Company

CONSOLIDATED BALANCE SHEETS
(Unaudited)


	June 30,	September 30,	June 30,
	2004	2003	2003
(In Thousands, Except Shares)
CAPITALIZATION AND LIABILITIES
CAPITALIZATION:
Common Stockholder's Equity:
Common stock, without par value -
Authorized 5,000,000 shares
Outstanding 3,625,887 shares	$ 24,757	$ 24,757	$ 24,757
Retained earnings	84,813	80,882	83,985
Accumulated other comprehensive loss	(2,260)	(2,278)	(224)
Total Common Stockholder's Equity	107,310	103,361	108,518

Long-term debt, exclusive of maturities due within one year	69,330	69,345	69,345
Total Capitalization	176,640	172,706	177,863

CURRENT LIABILITIES:
Accounts payable	15,760	13,202	14,918
Accrued taxes	6,500	315	8,885
Other accrued liabilities	4,431	5,143	4,200
Intercompany payables	4,252	10,060	1,825
Regulatory liabilities	2,744	-	3,338
Dividends payable	2,500	-	3,700
Customer deposits	2,073	1,899	1,596
Customer credit balances	4,186	6,963	3,441
Gas costs refundable through rate adjustments	-	5,011	3,682
Temporary LIFO liquidation credit	14,312	-	15,529
Total Current Liabilities	56,758	42,593	61,114

DEFERRED CREDITS AND OTHER LIABILITIES:
Deferred income taxes	32,275	31,126	30,063
Investment tax credits	2,926	3,008	3,023
Environmental, pension and other	55,845	54,709	49,260
Total Deferred Credits and Other Liabilities	91,046	88,843	82,346

Total Capitalization and Liabilities	$ 324,444	$ 304,142	$ 321,323

The Notes to Consolidated Financial Statements are an integral part of these statements.

North Shore Gas Company
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

	Nine Months Ended
	June 30,
	2004	2003
(In Thousands)
Operating Activities:
Net income	$ 12,732	$ 14,859
Adjustments to reconcile net income to cash provided by operations:
Depreciation	5,958	5,682
Deferred income taxes and investment tax credits - net	1,874	1,967
Change in environmental, pension and other liabilities	329	9,597
Other changes in noncurrent operating activities	973	(10,221)
Changes in current assets and liabilities:
Receivables - net	(17,016)	(9,502)
Gas in storage	3,586	5,048
Gas costs recoverable/refundable through rate adjustments	(8,484)	6,831
Net regulatory assets/liabilities	4,864	(2,347)
Payables and other accrued liabilities	(4,230)	3,976
Accrued taxes	6,185	6,684
Temporary LIFO liquidation credit	14,312	15,529
Other	(2,777)	(5,576)
Net Cash Provided by Operating Activities	18,306	42,527

Investing Activities:
Capital spending	(6,781)	(5,700)
Decrease in deposits with broker or trustee	1,953	2,788
Proceeds from the sale of assets	1,250	-
Other	(42)	-
Net Cash Used in Investing Activities	(3,620)	(2,912)

Financing Activities:
Proceeds from (payment of) overdrafts	268	(2,997)
Issuance of short-term debt	-	(17,210)
Issuance of long-term debt	-	40,000
Retirement of long-term debt	(15)	(24,669)
Dividends paid on common stock	(6,300)	(4,900)
Net Cash Used in Financing Activities	(6,047)	(9,776)

Net Increase in Cash and Cash Equivalents	8,639	29,839
Cash and Cash Equivalents at Beginning of Period	12,108	-
Cash and Cash Equivalents at End of Period	$ 20,747	$ 29,839

Supplemental Information:
Income taxes paid	$ 254	$ 302
Interest paid	$ 3,436	$ 3,743

The Notes to Consolidated Financial Statements are an integral part of these statements.

Notes to Consolidated Financial Statements (Unaudited)

1. BASIS OF PRESENTATION

The condensed, unaudited financial statements of Peoples Energy Corporation (the Company or Peoples Energy), The Peoples Gas Light and Coke Company (Peoples Gas) and North Shore Gas Company (North Shore Gas), have been prepared by the Company pursuant to the rules and regulations of the Securities and Exchange Commission (SEC). Peoples Gas and North Shore Gas are wholly-owned subsidiaries of the Company.

This Quarterly Report on Form 10-Q is a combined report of the Company, Peoples Gas and North Shore Gas. Certain footnote disclosures and other information, normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (GAAP), have been condensed or omitted from these interim financial statements, pursuant to SEC rules and regulations. Therefore, the statements should be read in conjunction with the consolidated financial statements and related notes contained in the Annual Report on Form 10-K for the Company, Peoples Gas and North Shore Gas for the fiscal year ended September 30, 2003. Certain items previously reported for the prior periods have been reclassified to conform with the presentation in the current period. Due to a number of factors, including seasonality of businesses and market price volatility, the quarterly results of operations and statements of financial position and cash flows should not be considered indicative of the year as a whole.

In the opinion of management, the accompanying unaudited consolidated financial statements contain all adjustments, consisting of normal recurring accruals unless otherwise noted, necessary to present fairly the financial position of the Company, Peoples Gas and North Shore Gas and their results of operations and cash flows for the interim periods presented.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Gas in Storage

Peoples Gas' and North Shore Gas' inventories are carried at cost on a last-in, first-out (LIFO) method. For interim periods, the difference between current projected replacement cost and the LIFO cost for quantities of gas temporarily withdrawn from storage is recorded as a temporary LIFO liquidation credit. Due to seasonality requirements, the Company expects interim reductions in LIFO layers to be replenished by the fiscal year end.

Stock Compensation Plans

A new compensation plan, the 2004 Incentive Compensation Plan (2004 Plan) was approved by shareholders at the Company's annual meeting held on February 27, 2004. The 2004 Plan is comprised of two sub-plans, the Long-Term Plan and the Short-Term Plan. The adoption of the 2004 Plan effectively replaces the Company's Long-Term Incentive Compensation Plan (LTIC Plan) and Short-Term Incentive Compensation Plan. The 2004 Plan does not provide for the grant of stock options. No expense has been accrued with respect to performance shares awarded under the 2004 Plan based upon current estimates of Company performance.

As allowed under Statement of Financial Accounting Standards (SFAS) No. 148, "Accounting for Stock-Based Compensation - Transition and Disclosure, an amendment of Financial Accounting Standards Board (FASB) Statement No. 123," the Company has chosen to continue accounting for stock-based compensation under Accounting Principles Board Opinion No. 25. Therefore, no compensation cost has been recognized for nonqualified stock options (under the superceded LTIC Plan and the Directors Stock and Option Plan (DSOP)) and shares issued under the Employee Stock Purchase Plan (ESPP). No options were granted in the nine-month period ended June 30, 2004. There were 426,900 options granted in the nine-month period ended June 30, 2003. There were 13,244 shares and 12,926 shares sold through the ESPP in the nine-month periods ended June 30, 2004 and 2003, respectively.

Stock-based employee compensation cost relative to stock appreciation rights, restricted stock awards and directors fees paid in stock included in reported net income for the three- and nine-month periods ended June 30, 2004 totaled $0.1 million and $1.5 million, respectively. Stock-based employee compensation cost included in reported net income for the three- and nine-month periods ended June 30, 2003 totaled $2.9 million and $5.4 million, respectively. Had compensation cost for stock options and shares issued under the superceded LTIC Plan, DSOP and ESPP been determined consistent with SFAS No. 123, the Company's net income and earnings per share would have been reduced to the following pro forma amounts:

	Three Months Ended		Nine Months Ended
	June 30,		June 30,
(In Thousands, Except Per-Share Amounts)	2004	2003	2004	2003
Net income as reported	$ 5,623	$ 8,013	$ 91,877	$ 102,495
Pro forma effects of LTIC, DSOP and ESPP
compensation expense under SFAS No. 123	17	227	29	672
Pro forma net income	$ 5,606	$ 7,786	$ 91,848	$ 101,823
Earnings per average common share:
Basic	$ 0.15	$ 0.22	$ 2.47	$ 2.86
Diluted	0.15	0.22	2.46	2.85
Pro forma basic	0.15	0.22	2.47	2.84
Pro forma diluted	0.15	0.21	2.46	2.83

For the three and nine months ended June 30, 2004, all outstanding options were included in the computation of diluted earnings per share. For the three and nine months ended June 30, 2003, options to purchase 470,300 shares and 580,900 shares of common stock, respectively, were excluded from the computation of diluted earnings per share because the option exercise prices were greater than the average market price of the common shares, and therefore were antidilutive.

The following table summarizes the assumptions used to calculate the fair value of each option grant. The pro forma disclosures are based upon recognizing expense over the vesting period of the options, the longest of which is 12 months. There was no pro forma effect for the three months ended June 30, 2004 as all outstanding options had vested prior to that period.

	Three Months Ended		Nine Months Ended
	June 30,		June 30,
	2004	2003	2004	2003
Expected volatility	N/A	25.84%	25.90%	25.80%
Dividend yield	N/A	4.9%	5.1%	4.9%
Risk-free interest rate	N/A	2.09%	2.47%	2.13%
Expected lives (years)	N/A	3	3	3
Weighted average fair value	N/A	$ 3.34	$ 3.83	$ 3.37

Derivative Instruments and Hedging Activities

The Company's earnings may vary due to changes in commodity prices and interest rates (market risk) that affect its subsidiaries' operations and investments. To manage this market risk, the Company uses forward contracts and financial instruments, including commodity futures contracts, swaps and options.

Cash Flow Hedges. The Company has positions in oil and gas reserves, natural gas, and transportation as part of its Oil and Gas Production, Midstream Services and Retail Energy Services businesses. The Company uses derivative financial instruments to protect against loss of value of future anticipated cash transactions caused by changes in the market place. These instruments are designated cash flow hedges, which allow for the unrealized changes in value during the life of the hedge to be recorded in other comprehensive income. The Company has also used cash flow hedges to reduce interest rate risk associated with debt refinancing activities. Realized gains and

losses from cash flow hedges are recorded in the income statement in the same month the related physical sales and purchases and interest expense is recorded.

The following table summarizes selected information related to cash flow hedges included in the Consolidated Income Statement and Balance Sheet through June 30, 2004.

		Interest	Partnership
(In Thousands)	Commodities	Rate	Transactions	Total
Portion of after tax gains (losses) on hedging instruments determined
to be ineffective and included in net income during the
nine months ended June 30, 2004	$ (422)	$ -	$ -	$ (422)
Accumulated other comprehensive income (loss) after tax at
June 30, 2004	$ (37,659)	$ (579)	$ (4,207)	$(42,445)
Portion of accumulated other comprehensive income (loss) expected
to be reclassified to earnings during the next 12 months based on
prices at June 30, 2004	$ (25,003)	$ (131)	N/A	$(25,134)
Maximum term	39 months	106 months

The maturities of the open cash flow hedges are summarized in the table below. All valuations are based on New York Mercantile Exchange (NYMEX) closing prices at June 30, 2004.

Cash Flow Hedges
Value by Year of Maturity

		Less than	1 to 2	2 to 3	3 to 4
(In Thousands)	Total	1 Year	Years	Years	Years
Gain (loss) at June 30, 2004	$(64,040)	$(39,351)	$(21,046)	$ (4,024)	$ 381
Loss at June 30, 2003	$(41,773)	$(22,567)	$(11,786)	$ (5,638)	$ (1,782)

Mark-To-Market Derivative Instruments. Peoples Gas and North Shore Gas use derivative instruments to manage each utility's cost of gas supply and mitigate price volatility. The regulated utilities' tariffs allow for full recovery from their customers of prudently incurred gas supply cost. Since the utilities do not bear the price risk associated with future gas supply purchases, any associated derivative activity will not qualify for hedge accounting and therefore must be mark to market. SFAS No. 71 allows any of these derivative gains or losses to be recorded as regulatory assets or regulatory liabilities. Realized gains or losses are recorded as an adjustment to the cost of gas supply in the period that the underlying gas purchase transaction takes place. The costs and benefits of this activity are passed through to customers under the tariffs of Peoples Gas and North Shore Gas. The following table summarizes this activity and other derivative instruments that are not hedges and are recorded on a mark-to-market basis. All amounts are expected to be settled during the next 12 months.

	June 30,
(In Thousands)	2004	2003
Peoples Gas mark-to-market asset	$ 14,758	$ 20,859
North Shore Gas mark-to-market asset	2,744	3,329
Other mark-to-market asset (liability)	128	(100)
Total	$ 17,630	$ 24,088

Fair Value Hedges. A small portion of the Company's financial hedges are used to protect the value of gas in storage and are accounted for as fair value hedges. The change in value of these hedges along with the change in value of the inventory hedged are recorded in the income statement.

Derivative Summary. The following table summarizes the changes in valuation of all outstanding derivative contracts during the nine months ended June 30, 2004 and 2003.

	Derivative Type
	Cash Flow		Fair Value
	Hedges		Hedges		Mark-to-Market
(In Thousands)	2004	2003	2004	2003	2004	2003
Gain (loss) on contracts outstanding at 10/01/2003	$(26,571)	$(35,029)	$ (65)	$ (3)	$ 13,691	$ 37,065
Less: Gain (loss) on contracts realized or otherwise
settled during the period	(17,291)	(8,410)	2	95	3,853	19,639
Plus: Gain (loss) on new contracts entered into during the
period and outstanding at end of period	(24,992)	1,220	157	102	14,320	(2,937)
Plus: Other gain (loss)	(29,768)	(16,374)	38	98	(6,528)	9,599
Gain (loss) on contracts outstanding at 06/30/2004	$ (64,040)	$ (41,773)	$ 128	$ 102	$ 17,630	$ 24,088

Revenue Recognition

Gas and electricity sales and transportation revenues are recorded on the accrual basis for all gas and electricity delivered during the month, including an estimate for gas and electricity delivered but unbilled at the end of each month. The amount of accrued unbilled revenue is summarized below.

	June 30,
(In Thousands)	2004	2003
Peoples Gas	$ 15,516	$ 21,131
North Shore Gas	3,666	3,799
Peoples Energy Services	15,701	11,190
Consolidated Peoples Energy	$ 34,883	$ 36,120

In Illinois, delivering, supplying, furnishing or selling gas for use or consumption and not for resale is subject to state and, in some cases, municipal taxes (revenue taxes). The Illinois Public Utility Act provides that the tax may be recovered from utility customers by adding an additional charge to customers' bills. These taxes are due only to the extent they are collected as cash receipts as opposed to amounts billed. As a result, most revenue taxes are reported on a gross basis. The billed amounts for the recovery of these taxes are included in revenues and an offsetting expense amount representing the expected cash payment of the taxes is included in taxes, other than income taxes on the income statement. Revenue tax amounts included in utility revenues are as follows:

	Three Months Ended		Nine Months Ended
	June 30,		June 30,
(In Thousands)	2004	2003	2004	2003
Peoples Gas	$ 18,997	$ 21,975	$ 112,855	$117,284
North Shore Gas	1,711	2,053	10,969	11,608
Consolidated Peoples Energy	$ 20,708	$ 24,028	$ 123,824	$128,892

Natural gas and crude oil production revenues are recorded on the entitlement method. Under the entitlement method, revenue is recorded when title is transferred based on the Company's net interest. The Company records its entitled share of revenues based on estimated production volumes. Subsequently, these estimated volumes are adjusted to reflect actual volumes that are supported by third party statements and/or cash receipts.

Statement of Cash Flows

For purposes of reporting cash flows, the Company considers all highly liquid financial instruments with a maturity at the date of purchase of three months or less to be cash equivalents. Under the Company's cash management practices, checks issued pending clearance that result in overdraft balances for accounting purposes are included in accounts payable and total $19.8 million and $0.7 million as of June 30, 2004 and 2003, respectively. For Peoples Gas, the amounts in accounts payable at June 30, 2004 and 2003 were $7.7 million and $0.5 million, respectively. North Shore Gas' amount in accounts payable at June 30, 2004 and 2003 was immaterial.

Recent Accounting Pronouncements

Under Financial Interpretation No. (FIN) 46R, "Consolidation of Variable Interest Entities - An Interpretation of ARB No. 51," as amended, if a business enterprise has a controlling financial interest in a variable interest entity, the assets, liabilities and results of the activities of the variable interest entity should be included in consolidated financial statements with those of the business enterprise. The Company's only off-balance sheet financing is through its equity method investments, none of which qualify as a Variable Interest Entity. Adoption of FIN 46R did not affect the Company's financial condition or results of operations.

On October 16, 2003, the FASB posted FASB Staff Position (FSP) No. 150-2, "Accounting for Mandatorily Redeemable Shares Requiring Redemption by Payment of an Amount That Differs from the Book Value of Those Shares, under FASB Statement No. 150." Under SFAS No. 150, the investment in Southeast Chicago Energy Project, LLC was deemed to be a mandatorily redeemable investment and the Company's equity in the partnership was reclassified to long-term liabilities on the partnership books. The change on the partnership books has no effect the Company's reporting its results using the equity method investment.

In December 2003, the "Medicare Prescription Drug, Improvement and Modernization Act of 2003" (Medicare Act) was signed into law. The Company has a postretirement health care plan that may be affected by the Medicare Act. Initially, the FASB issued FSP No. 106-1 "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug, Improvement and Modernization Act of 2003," in January 2004, to permit companies to elect a deferral of the accounting until additional guidance could be provided. In May 2004, the FASB issued FSP No. 106-2, "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug Improvement and Modernization Act of 2003" to provide the additional accounting guidance. However, for the Company to make an accurate determination of any potential impact from the Medicare Act, additional guidance is still required from the U.S. Department of Health and Human Services to define terms like "Medicare Equivalent." The effective date for FSP No. 106-2 is the quarter ended September 30, 2004. The Company has elected to defer any potential accounting impact. At this time, the Company cannot determine what effect, if any, the Medicare Act will have on the financial position or results of operations of the Company.

The Company adopted SFAS No. 141, "Business Combinations," and SFAS No. 142, "Goodwill and Other Intangible Assets," as of October 1, 2001. These statements, in part, clarify that more assets should be distinguished and classified between tangible and intangible. The Company did not change or reclassify contractual mineral rights included in oil and gas properties on the balance sheet upon adoption of SFAS No. 142. On April 30, 2004, the FASB staff issued FSP Nos. 141-1 and 142-1, which clarify that contractual mineral rights are tangible assets. This is consistent with the Company's previous interpretation and application of SFAS Nos. 141 and 142.

SFAS No. 132 (Revised 2003), "Employers' Disclosures about Pensions and Other Postretirement Benefits - An Amendment of FASB Statements No. 87, 88, and 106" revises employers' disclosures about pension plans and other postretirement benefit plans. It does not change the measurement or recognition of those plans. This Statement requires additional disclosures to those in the original SFAS No. 132 about the assets, obligations, cash flows and net periodic benefit cost of defined benefit pension plans and other defined benefit postretirement plans, and requires new disclosures in interim financial statements. The required information should be provided separately for pension plans and for other postretirement benefit plans. The interim disclosures were adopted in the

second quarter of fiscal 2004. The annual requirements will be adopted for the fiscal year ended September 30, 2004.

3. BUSINESS SEGMENTS

Total segment capital assets include net property, plant and equipment and certain intangible assets classified in other investments. Financial data by business segment is presented below.

					Retail		Corporate
	Gas	Oil and Gas	Power	Midstream	Energy		and
(In Thousands)	Distribution	Production	Generation	Services	Services	Other	Adjustments	Total
Three Months Ended June 30, 2004
Revenues	$ 234,611	$ 30,523	$ -	$ 83,506	$ 62,913	$ 36	$ (10,452)	$ 401,137
Depreciation, depletion and amortization	17,478	11,550	32	112	452	4	121	29,749
Equity investment income (loss)	-	1,725	3,091	-	-	50	-	4,866
Operating income (loss)	11,261	7,390	1,695	835	833	(116)	(4,814)	17,084
Segment capital assets - net	1,565,755	315,137	10,466	6,092	7,398	960	2,035	1,907,843
Investments in equity investees	-	19,807	107,469	-	-	3,674	-	130,950
Capital spending	17,133	13,918	1,517	4	481	-	260	33,313
Three Months Ended June 30, 2003
Revenues	$ 267,031	$ 27,988	$ -	$ 58,859	$ 50,372	$ 70	$ (6,173)	$ 398,147
Depreciation, depletion and amortization	16,905	10,759	32	106	(171)	4	23	27,658
Equity investment income (loss)	-	722	2,900	-	-	189	-	3,811
Operating income (loss)	19,121	10,168	1,704	(800)	792	(79)	(6,485)	24,421
Segment capital assets - net	1,546,250	261,097	7,150	5,790	7,403	1,343	1,423	1,830,456
Investments in equity investees	-	20,991	112,282	-	-	3,943	-	137,216
Capital spending	19,490	24,957	504	-	282	(264)	711	45,680
Nine Months Ended June 30, 2004
Revenues	$ 1,344,010	$ 93,915	$ -	$ 257,860	$270,627	$ 290	$ (33,660)	$ 1,933,042
Depreciation, depletion and amortization	51,441	36,093	95	336	1,326	12	338	89,641
Equity investment income (loss)	-	3,119	2,584	-	-	407	-	6,110
Operating income (loss)	142,009	31,287	(954)	7,642	8,802	111	(16,721)	172,176
Segment capital assets - net	1,565,755	315,137	10,466	6,092	7,398	960	2,035	1,907,843
Investments in equity investees	-	19,807	107,469	-	-	3,674	-	130,950
Capital spending	53,031	86,980	2,255	137	1,478	400	574	144,855
Nine Months Ended June 30, 2003
Revenues	$ 1,359,823	$ 78,122	$ -	$ 233,501	$211,935	$ 141	$ (32,430)	$ 1,851,092
Depreciation, depletion and amortization	50,166	31,238	95	319	1,235	12	70	83,135
Equity investment income (loss)	-	55	2,690	-	-	800	-	3,545
Operating income (loss)	177,603	23,839	(740)	9,827	5,100	15	(16,376)	199,268
Segment capital assets - net	1,546,250	261,097	7,150	5,790	7,403	1,343	1,423	1,830,456
Investments in equity investees	-	20,991	112,282	-	-	3,943	-	137,216
Capital spending	52,257	76,714	2,173	15	825	624	718	133,326

The financial results of Peoples Gas and North Shore Gas are reported primarily within the Gas Distribution segment. Operating income by business segment for Peoples Gas and North Shore Gas is presented below.

	The Peoples Gas Light and Coke Company				North Shore Gas Company
			Corporate			Corporate
	Gas	Midstream	and		Gas	and
(In Thousands)	Distribution	Services	Adjustments	Total	Distribution	Adjustments	Total

Three Months Ended June 30, 2004	$ 8,805	$ 886	$ (3,689)	$ 6,002	$ 2,644	$ (467)	$ 2,177
Three Months Ended June 30, 2003	16,523	1,261	(2,050)	15,734	2,790	(201)	2,589
Nine Months Ended June 30, 2004	119,487	4,060	(9,680)	113,867	24,093	(1,226)	22,867
Nine Months Ended June 30, 2003	151,308	7,230	(7,068)	151,470	27,865	(854)	27,011

4. EQUITY INVESTMENTS

The Company has several investments in the form of partnerships that are accounted for as unconsolidated equity method investments. Individually, the Company's equity investments do not meet the requirements for financial disclosure. However, in aggregate these investments are material. The Company records its share of income gains and losses based on financial information it receives from the partnerships. All information is current or based on estimated results for the quarter. The Company is not a managing partner in any of these investments.

The following table summarizes the combined partnership financial results and financial position of the Company's unconsolidated equity method investments.

	Three Months Ended		Nine Months Ended
	June 30,		June 30,
(In Thousands)	2004	2003	2004	2003
Revenues	$ 43,264	$ 40,281	$ 88,917	$ 91,641
Operating income	20,303	19,952	44,074	42,557
Interest expense	10,001	8,506	28,773	26,620
Net income (loss)	8,984	11,607	16,700	16,601

Total assets	822,131	848,336	822,131	848,336
Total liabilities	508,429	460,217	508,429	460,217

The following table summarizes the Company's equity method investment ownership percentage and its equity share of the net income (loss) shown in the previous table.

		Ownership Percentage						Equity Investment Income (Loss)
								Three Months Ended		Nine Months Ended
(Dollars in Thousands)		At June 30,						June 30,		June 30,
Investment	Segment	2004			2003			2004	2003	2004	2003
EnerVest	Oil and Gas		30	%		30	%	$ 1,725	$ 722	$ 3,119	$ 55
Elwood	Power		50			50		1,672	1,406	(1,729)	(1,849)
SCEP	Power		27			27		1,419	1,494	4,313	4,539
Trigen-Peoples	Other		50			50		50	189	407	797
Peoples NGV (1)	Other		0			0		-	-	-	3

Total equity investment income								$ 4,866	$ 3,811	$ 6,110	$ 3,545

Undistributed partnership income included in the
Company's retained earnings at the end of each period								$ 12,156	$ 6,015	$ 12,156	$ 6,015

(1) The Company liquidated its investment in Peoples NGV Corp. in the first quarter of fiscal 2003.

5. ENVIRONMENTAL MATTERS

Former Manufactured Gas Plant Operations

The Company's utility subsidiaries, their predecessors and certain former affiliates operated facilities in the past at multiple sites for the purpose of manufacturing gas and storing manufactured gas. In connection with manufacturing and storing gas, various by-products and waste materials were produced, some of which might have been disposed of rather than sold. Under certain laws and regulations relating to the protection of the environment, the subsidiaries might be required to undertake remedial action with respect to some of these materials. The subsidiaries are addressing these sites under a program supervised by the Illinois Environmental Protection Agency.

Peoples Gas is addressing 29 manufactured gas sites, including two sites described in more detail below. Investigations have been completed at all or portions of 23 sites. Remediations have been completed at all or portions of four sites.

North Shore Gas is addressing five manufactured gas sites, including one site described in more detail below. Investigations have been completed at all or portions of four sites. Remediations have not yet been completed at these sites.

The United States Environmental Protection Agency (EPA) has identified North Shore Gas as a potentially responsible party (PRP) under the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (CERCLA), at the Waukegan Coke Plant Site located in Waukegan, Illinois (Waukegan Site). The Waukegan Site is part of the Outboard Marine Corporation (OMC) Superfund Site. The EPA also has identified General Motors Corporation, OMC, Elgin Joliet and Eastern Railway Company, Larsen Marine Service and the City of Waukegan as PRPs at the Waukegan Site. OMC has filed for bankruptcy.

In September 1999, the EPA issued a record of decision (ROD) selecting the remedial action for the Waukegan Site. The selected remedy consists of on-site treatment of groundwater and off-site disposal of soil containing polynuclear aromatic hydrocarbons and arsenic. The EPA has estimated the present worth of the remedy to be $26.5 million (representing the present worth of estimated capital costs and of estimated operation and maintenance costs). North Shore Gas and the other PRPs (except for the City of Waukegan) are conducting the remedial design for the Waukegan Site.

In July 2004, North Shore Gas and the other PRPs executed a remedial action consent decree. The consent decree is currently undergoing review by EPA and other government agencies. If approved by the government agencies and lodged with and entered by the federal district court, the consent decree will require North Shore Gas and General Motors to perform the remedial action and establish and maintain financial assurance of $27 million.

The current owner of a site in the City of Chicago, Illinois (Chicago), formerly called Pitney Court Station, filed suit against Peoples Gas in federal district court under CERCLA. The suit seeks recovery of the past and future costs of investigating and remediating the site. The owners of another property in the vicinity of the former Pitney Court Station have filed suit against Peoples Gas in federal district court under the Resource Conservation and Recovery Act (RCRA). The suit seeks an order directing Peoples Gas to remediate the site. Peoples Gas is contesting both suits.

The current owner of a portion of another site in Chicago, formerly called the 22 ^nd Street Station, has notified Peoples Gas that it intends to file suit under RCRA seeking an order directing Peoples Gas to remediate the site.

The utility subsidiaries are accruing and deferring liabilities and costs incurred in connection with all of the manufactured gas sites, including related legal expenses, pending recovery through rates or from other entities. At June 30, 2004, the total of these deferred liabilities and costs (stated in current year dollars) for Peoples Gas was $134.6 million; for North Shore Gas the total was $36.7 million; and for the Company on a consolidated basis, the total deferred was $171.3 million. Each of these deferred amounts reflects the net amount of (1) costs incurred to date, (2) carrying costs, (3) amounts recovered from insurance companies and from customers, and (4) management's best estimates of the costs the utilities will spend in the future for investigating and remediating the manufactured gas sites. Management also estimates that additional costs in the following amounts are reasonably possible: for Peoples Gas, $73 million; for North Shore Gas, $27 million; and for the Company on a consolidated basis, $100 million. Management's estimates are based upon an ongoing review by management and its outside consultants of potential costs associated with conducting investigative and remedial actions at the manufactured gas sites, and of the likelihood of incurring such costs. While each subsidiary intends to seek contribution from other entities for the costs incurred at the sites, the full extent of such contributions cannot be determined at this time.

Management believes that the liabilities incurred by Peoples Gas and by North Shore Gas for environmental activities relating to former manufactured gas operations are recoverable through rates for utility service, from insurance carriers or other entities. Accordingly, management believes that the costs incurred by the subsidiaries in connection with former manufactured gas operations will not have a material adverse effect on the financial position or results of operations of the utilities. Peoples Gas and North Shore Gas are recovering the costs of environmental activities relating to the utilities' former manufactured gas operations, including carrying charges on the unrecovered balances, under rate mechanisms approved by the Illinois Commerce Commission (Commission).

Former Mineral Processing Site in Denver, Colorado

In 1994, North Shore Gas received a demand from the S.W. Shattuck Chemical Company, Inc. (Shattuck), a responsible party under CERCLA, for reimbursement, indemnification and contribution for response costs incurred at a former mineral processing site in Denver, Colorado (Denver site). Shattuck is a wholly-owned subsidiary of Salomon, Inc. (Salomon). The demand alleges that North Shore Gas is a successor to the liability of a former entity that was allegedly responsible during the period 1934-1941 for the disposal of mineral processing wastes containing radium and other hazardous substances at the site. In 1992, the EPA issued the ROD for the Denver site. The remedy selected in the ROD consisted of the on-site stabilization, solidification and capping of soils containing radioactive wastes. In 1997, the remedial action was completed. The cost of the remedy at the site has been estimated by Shattuck to be approximately $31 million. Salomon has provided financial assurance for the performance of the remediation of the site.

North Shore Gas filed a declaratory judgment action against Salomon in the District Court for the Northern District of Illinois. The suit asked the court to declare that North Shore Gas is not liable for response costs at the Denver site. Salomon filed a counterclaim for costs incurred by Salomon and Shattuck with respect to the site. In

1997, the District Court granted North Shore Gas' motion for summary judgment, declaring that North Shore Gas is not liable for any response costs in connection with the Denver site.

In 1998, the United States Court of Appeals, Seventh Circuit, reversed the District Court's decision and remanded the case for determination of what liability, if any, the former entity has, and therefore North Shore Gas has, for activities at the site.

In 1999, the EPA announced that it was reopening the ROD for the Denver site. The EPA's announcement followed a six-month scientific/technical review by the agency of the remedy's effectiveness. In 2000, the EPA amended the ROD to require removal of the radioactive wastes from the site to a licensed off-site disposal facility. The EPA estimates that this action will cost an additional $22.0 million (representing the present worth of estimated capital costs and estimated operation and maintenance costs).

In December 2001, Shattuck entered into a proposed settlement agreement with the United States and the State of Colorado regarding past and future response costs at the site. In August 2002, the agreement was approved by the District Court for the District of Colorado. Under the terms of the agreement, Shattuck will pay, in addition to amounts already paid for response costs at the site, approximately $7.2 million in exchange for a release from further obligations at the site. The release will not apply in the event that new information shows that the remedy selected in the amended ROD is not protective of human health or the environment or if it becomes necessary to remediate contaminated groundwater beneath or emanating from the site.

North Shore Gas does not believe that it has liability for the response costs, but cannot determine the matter with certainty. At this time, North Shore Gas cannot reasonably estimate what range of loss, if any, may occur. In the event that North Shore Gas incurs liability, it would pursue reimbursement from insurance carriers, other responsible parties, if any, and through its rates for utility service.

6. GAS CHARGE RECONCILIATION PROCEEDINGS AND RELATED MATTERS

For each utility subsidiary, the Commission conducts annual proceedings regarding the reconciliation of revenues from the Gas Charge and related gas costs. In these proceedings, the accuracy of the reconciliation of revenues and costs is reviewed and the prudence of gas costs recovered through the Gas Charge is examined by interested parties. If the Commission were to find that the reconciliation was inaccurate or any gas costs were imprudently incurred, the Commission would order the utility to refund the affected amount to customers through subsequent Gas Charge filings. The proceedings are typically initiated shortly after the close of the fiscal year and take at least a year to 18 months to complete.

Proceedings regarding Peoples Gas and North Shore Gas for fiscal 2001 costs are currently pending before the Commission. Three intervenors (Citizens Utility Board (CUB), Illinois Attorney General (AG) and Chicago filed testimony in Peoples Gas' proceeding and one intervenor (CUB) filed testimony in North Shore Gas' proceeding. Issues raised by the intervenors in the Peoples Gas proceeding related primarily to not having financially hedged gas costs during the winter of 2000-2001 and the use of its Manlove storage field to support transactions with third parties ("hub" transactions). Each of the intervenors requested disallowances, which vary in amount depending upon the issues raised and the assumptions and methodologies used to measure the impact of the issues. In the Peoples Gas proceeding, the AG and CUB have requested disallowances, which range from $8 million to $56 million, covering a variety of alleged issues other than financial hedging. CUB has requested an additional disallowance of $53 million and Chicago has requested a disallowance of $230 million based on the financial hedging issue. In the North Shore Gas proceeding, CUB raised only the hedging issue and recommended a disallowance of $10 million. The Commission's Staff (the Staff) requested a disallowance of $31 million in the Peoples Gas proceeding and $1.4 million in the North Shore Gas proceeding covering a variety of alleged issues, none of which relate to hedging.

Peoples Gas and North Shore Gas submitted rebuttal testimony in response to the Staff and the intervenors on November 13, 2003. In that testimony, Peoples Gas stated that it would not oppose two disallowances proposed by the Staff, totaling approximately $5.2 million. One of these proposed disallowances, totaling $4.7 million, results

in a change in the treatment for accounting and rate making purposes of gas used to support operational capabilities of Peoples Gas' underground storage. During the first quarter, this amount was capitalized as property, plant and equipment and will be depreciated over the asset's useful life. An offsetting liability for this amount, which is expected to be refunded to customers, was recorded. During the first quarter, Peoples Gas also recorded property, plant and equipment and liabilities totaling $5.9 million for similar amounts recovered through the Gas Charge in fiscal 2003 and fiscal 2002. A liability was also established for the second proposed disallowance of $0.5 million resulting in a charge to income. Peoples Gas opposed all other proposed disallowances and North Shore Gas opposed all disallowances in its case. At a status hearing on June 23, 2004, the Administrative Law Judge established a schedule for testimony and hearings in the fiscal 2001 cases. The schedule provides for the Staff and intervenors to file supplemental direct testimony on September 8, 2004, and Peoples Gas and North Shore Gas to file rebuttal testimony on October 6, 2004. Hearings in both cases are scheduled to commence on November 3, 2004. The schedule also provides for other routine procedural dates, including status hearings, prior to the hearings. An order from the Commission is not expected before the third quarter of fiscal 2005.

In January 2004, the Company received and responded to a subpoena from the AG requesting, among other things, information regarding transactions between the Company and Enron North America Corp. or its affiliates related to certain issues raised by the Staff and intervenors in the 2001 Gas Charge reconciliation proceedings.

The Company believes that its fiscal 2001 purchasing practices were consistent with the standards applied by the Commission in its past orders and upheld by the Illinois courts and that it conducted business prudently and in the best interest of customers within these established standards. However, management cannot predict the outcome of these proceedings or the potential resulting exposure and has not recorded a liability associated with this contingency other than with respect to the disallowances that Peoples Gas did not oppose as described above.

Fiscal 2002 Gas Charge reconciliation cases were initiated on November 7, 2002. Peoples Gas and North Shore Gas each filed direct testimony on August 1, 2003. A status hearing is scheduled for November 16, 2004. Fiscal 2003 Gas Charge reconciliation cases were initiated on November 12, 2003. Peoples Gas and North Shore Gas each filed direct testimony on April 1, 2004. A status hearing is scheduled for November 9, 2004.

Separately, in February 2004 a purported class action was filed against the Company and Peoples Gas by a Peoples Gas customer alleging, among other things, violation of the Illinois Consumer Fraud and Deceptive Business Practices Act related to matters at issue in Peoples Gas' gas reconciliation proceedings. The suit seeks unspecified compensatory and punitive damages. The Company and Peoples Gas deny the allegations made in the suit and intend to vigorously defend against the suit. Management cannot predict the outcome of this litigation or the potential exposure resulting from it and has not recorded a liability associated with this contingency.

7. COMPREHENSIVE INCOME

Comprehensive income is the total of net income and all other nonowner changes in equity. Comprehensive income recorded includes net income plus the effect of the unrealized hedge gain or loss on derivative instruments. Total comprehensive income for the Company is summarized below.

	Three Months Ended		Nine Months Ended
	June 30,		June 30,
(In Thousands)	2004	2003	2004	2003
Comprehensive income
Net income	$ 5,623	$ 8,013	$ 91,877	$ 102,495
Other comprehensive income (loss), net of tax	(4,885)	(3,283)	(24,635)	(17,992)

Total comprehensive income	$ 738	$ 4,730	$ 67,242	$ 84,503

Peoples Gas and North Shore Gas recorded an insignificant amount of other comprehensive income related to the amortization of interest rate lock cash flow hedges.

8. RETIREMENT AND POSTRETIREMENT BENEFITS

The Company and its subsidiaries participate in two defined benefit pension plans, the Retirement Plan and the Service Annuity System, covering substantially all employees. These plans provide pension benefits that generally are based on an employee's length of service, compensation during the five years preceding retirement and social security benefits. Employees who began participation in the Retirement Plan July 1, 2001 and thereafter will have their benefits determined based on their compensation during the five years preceding termination of employment and an aged-based percentage credited to them for each year of their participation. The Company and its subsidiaries make contributions to the plans based upon actuarial determinations and in consideration of tax regulations and funding requirements under federal law. The Company also has a nonqualified pension plan (Supplemental Plan) that provides certain employees with pension benefits in excess of qualified plan limits imposed by federal tax law. Retiring employees have the option of receiving retirement benefits in the form of an annuity or a lump sum payment.

The Company follows the procedures specified in SFAS No. 88 to account for unrecognized gains and losses related to the settlement of its pension plans' Projected Benefit Obligations (PBO). During fiscal 2004, as in past fiscal years, a portion of each plans' PBO was settled by the payment of lump sum benefits, resulting in a settlement cost (credit) under SFAS No. 88 for the Retirement Plan, Service Annuity System and Supplemental Plan.

In addition, the Company and its subsidiaries currently provide certain health care and life insurance benefits for retired employees. Substantially all employees may become eligible for such benefit coverage if they reach retirement age while working for the Company. These plans, like the pension plans, are funded based upon actuarial determinations, consideration of tax regulations and the Company's funding policy. The Company accrues the expected costs of such benefits over the average remaining service lives of all employees.

Net pension benefit cost and net other postretirement benefit cost for all plans include the following components:

			Other Postretirement
	Pension Benefits		Benefits
	Three Months Ended June 30,
(In Millions)	2004	2003	2004	2003
Service cost	$ 4.5	$ 3.4	$ 1.4	$ 0.6
Interest cost	6.9	7.3	1.9	1.9
Expected return on plan assets (gain)	(11.7)	(13.0)	(1.0)	(1.1)
Amortization of:
Net transition (asset) obligation	(0.3)	(0.3)	0.5	0.8
Prior service costs	0.8	0.8	-	-
Net (gain) loss	0.4	(0.1)	0.2	-
Net periodic benefit cost (credit)	0.6	(1.9)	3.0	2.2
Effect of lump sum settlements upon retirement	2.3	0.2	-	-
Net cost (credit)	$ 2.9	$ (1.7)	$ 3.0	$ 2.2



			Other Postretirement
	Pension Benefits		Benefits
	Nine Months Ended June 30,
(In Millions)	2004	2003	2004	2003
Service cost	$ 13.5	$ 10.2	$ 3.8	$ 2.9
Interest cost	20.7	21.9	5.7	5.7
Expected return on plan assets (gain)	(35.1)	(39.0)	(3.0)	(3.3)
Amortization of:
Net transition (asset) obligation	(0.9)	(0.9)	1.5	2.4
Prior service costs	2.4	2.4	-	-
Net (gain) loss	1.2	(0.3)	0.6	-
Net periodic benefit cost (credit)	1.8	(5.7)	8.6	7.7
Effect of lump sum settlements upon retirement	6.9	5.3	-	-
Net cost (credit)	$ 8.7	$ (0.4)	$ 8.6	$ 7.7

9. SUBSEQUENT EVENTS - STRATEGIC RESTRUCTURING

Subsequent to the close of the third quarter, the Company announced that it has initiated a strategic restructuring plan, which includes key senior management changes affecting the Company and its utility subsidiaries, Peoples Gas and North Shore Gas. William E. Morrow, 48, was elected Executive Vice President of Operations for Peoples Energy. Desiree G. Rogers, 45, was elected President of Peoples Gas and North Shore Gas, succeeding Donald M. Field, who will retire on October 1, 2004.

Additionally, the Company announced it is offering an enhanced severance package to non-union employees of Peoples Energy, Peoples Gas, North Shore Gas and employees of its diversified Power Generation and Midstream Services business who elect a voluntary resignation of employment. The enhanced severance offer can be accepted by employees from the vice president level and below through August 30, 2004. The cost of this program will be expensed in the fourth quarter of fiscal 2004 and the related pension settlement cost will be expensed in fiscal 2005.

Item 2. Management's Discussion and Analysis of Results of Operations and Financial Condition

EXECUTIVE SUMMARY

Peoples Energy is a diversified energy company comprised of five main business segments: the core business - Gas Distribution, and diversified businesses - Oil and Gas Production, Power Generation, Midstream Services and Retail Energy Services. The Company's Gas Distribution segment consists of two regulated utilities, Peoples Gas and North Shore Gas. This segment has the most significant impact on the consolidated financial results of Peoples Energy, accounting for a major portion of operating income. Since 1998, the Company has developed a portfolio of complementary energy businesses that help to diversify the sources of consolidated operating income. The Company expects these businesses to provide increasing contributions to its long-term growth.

Net income for the fiscal 2004 third quarter and fiscal year-to-date was down $0.07 and $0.39 per share, respectively, from the same periods last year. Both the quarter and year-to-date comparisons with the year-ago periods were negatively affected by lower gas deliveries in the Gas Distribution business. The decline in deliveries reflects the impacts of both warmer weather and lower non-weather related demand. In terms of the non-weather related component, it became more apparent in the third quarter that customers are responding to the current high gas price environment by lowering their energy usage. Natural gas prices are not expected to decline significantly anytime soon, and it is anticipated they will continue to have a dampening effect on gas distribution demand over the next year. These negative effects were partially offset by lower provision for uncollectible accounts compared to the three- and nine-month periods of the previous fiscal year.

The Oil and Gas Production segment is progressing toward another year of significant production growth and increased profitability, with fiscal 2004 operating income expected to be up 35 to 40 percent from the prior year. However, in the third quarter, higher exploration expense and lower than expected production volumes resulted in a decline in operating income compared to a year ago. In terms of production levels, several operational and timing issues resulted in third quarter production volumes that were essentially flat with the year-ago period and less than had been anticipated. Fourth quarter production is expected to increase from third quarter levels. Operating income from the other diversified businesses as a group is up over last year with mixed results from each segment in the quarter and year-to-date periods.

In July, Peoples Energy announced a strategic reorganization of the utilities and corporate support organization. The objectives of this reorganization are to streamline the Company's management structure and to refocus on new sources of efficiency and revenue. The Company believes that a rough estimate of fiscal 2005 cost savings is $8 million to $12 million.

Management now estimates that fiscal 2004 earnings will be in the range of $2.60 to $2.70 per diluted share, excluding any expenses in the fourth quarter related to the above mentioned restructuring. This estimate includes fourth quarter gains on asset sales in the Power Generation and Gas Distribution segments totaling approximately $0.10 per share. Although discussions are continuing on those potential sales, the timing is difficult to predict and they could potentially extend into fiscal 2005. (See Forward-Looking Information).

RESULTS OF OPERATIONS

Net income for the third quarter was $5.6 million, or $0.15 per diluted share, compared to $8.0 million, or $0.22 per diluted share in the year-ago quarter. Fiscal year-to-date net income was $91.9 million, or $2.46 per diluted share, compared to $102.5 million, or $2.85 per diluted share a year ago. Operating income for the current quarter and fiscal year-to-date totaled $17.1 million and $172.2 million, respectively, versus $24.4 million and $199.3 million in the same periods last year.

Financial results for the three months ended June 30, 2004 reflect lower operating results primarily due to lower deliveries in the Gas Distribution segment resulting from weather that was 18 percent warmer than the same period last year and customer conservation. Lower performance in the third quarter by the Oil and Gas Production segment also affected the quarterly results, primarily as a result of increased exploration expense due to an unsuccessful well in Louisiana. Financial results for the nine months ended June 30, 2004 reflect the adverse impact of lower deliveries resulting from weather that was nine percent warmer than the same period last year and customer conservation. Continued strong growth from the diversified energy businesses partially offset the negative delivery impact. The Oil and Gas Production segment benefited from higher production volumes and higher realized natural gas and oil prices than a year ago.

Income Statement Variations

The Company's revenues and cost of energy sold increased $3.0 million and $9.1 million, respectively, for the three-month period and increased $82.0 million and $94.4 million, respectively, for the nine-month period due to:

higher realized commodity prices; and
increased sales volumes in the Oil and Gas Production and Retail Energy Services segments.

These increases were offset by a 10 percent and eight percent decrease in Gas Distribution deliveries in the three- and nine-month periods, respectively, resulting from warmer weather and lower normalized deliveries.

Operation and maintenance expense for the three-month period decreased slightly and increased $8.5 million for the nine-month period. Significant items to note in both periods were:

higher pension expense of $4.3 million and $8.0 million. Pension expense related to normal activity increased as expected due to the ongoing effects of both lower pension plan returns in recent years and a lower discount rate. The prior nine-month period included a $4.7 million impact on pension expense related to a retiring executive officer.
higher outside professional services ($3.2 million and $5.5 million) mainly related to higher legal costs associated with the utilities ongoing gas reconciliation case before the Commission;
higher expense in the Oil and Gas Production segment ($5.2 million and $6.8 million) resulting primarily from an increase in lease operating expense and exploration expense;
decreased provision for uncollectible accounts ($5.5 million and $5.2 million), mainly as a result of improving credit and collection metrics in its Gas Distribution businesses;
lower corporate expenses resulting from the impact of a lower Peoples Energy stock price on the value of stock appreciation rights ($2.8 million and $2.7 million); and
lower utility environmental costs of $0.2 million and $5.0 million, respectively. (These costs are recovered through the utilities' rate mechanism and a like amount is included in revenues; therefore, these costs do not affect operating income).

Depreciation, depletion and amortization for the three- and nine-month periods increased $2.1 million and $6.5 million, respectively, mainly resulting from higher production and a higher depletion rate in the Oil and Gas Production segment and from higher depreciable property in the Gas Distribution segment.

Taxes, other than income taxes, which are typically directly related to the level of utility revenues, increased for the three- and nine-month periods by $2.0 million and $3.7 million, respectively, due to adjustments to reduce municipal and state utility tax accruals recorded in the previous periods. For the three- and nine-month periods, these adjustments were $5.6 million and $9.7 million, respectively. Absent this impact, these taxes declined due to lower levels of utility revenues. The period-to-period comparison was also affected by a change in the state revenue tax law that resulted in the Company recording more taxes as a direct liability to the state where previous period amounts were included in both revenue and revenue tax expense.

Income tax expense for the three- and nine-month periods decreased $4.4 million and $15.0 million, respectively, primarily from lower pre-taxable income. The fiscal year-to-date period also benefited from a lower effective tax rate due to prior fiscal 2004 adjustments in accrued income taxes and due to the ability under recent tax legislation to realize tax benefits from dividends reinvested in Peoples Energy stock under the Company's Employee Stock Ownership Plan.

Segment Discussion

A summary of the Company's operating income by segment, and variations between periods, is presented below.

	Three Months Ended		Nine Months Ended		Increase/(Decrease)
	June 30,		June 30,		Three Months	Nine Months
(In Thousands)	2004	2003	2004	2003	Ended	Ended
Operating income (loss):
Gas Distribution	$ 11,261	$ 19,121	$ 142,009	$ 177,603	$ (7,860)	$ (35,594)
Oil and Gas Production	7,390	10,168	31,287	23,839	(2,778)	7,448
Power Generation	1,695	1,704	(954)	(740)	(9)	(214)
Midstream Services	835	(800)	7,642	9,827	1,635	(2,185)
Retail Energy Services	833	792	8,802	5,100	41	3,702
Other	(116)	(79)	111	15	(37)	96
Corporate and Adjustments	(4,814)	(6,485)	(16,721)	(16,376)	1,671	(345)
Total operating income	$ 17,084	$ 24,421	$ 172,176	$ 199,268	$ (7,337)	$ (27,092)

Gas Distribution Segment. The following table summarizes revenue, deliveries and other statistics for the Gas Distribution segment.

Gas Distribution Statistics

	Three Months Ended		Nine Months Ended		Increase/(Decrease)
Margin Data	June 30,		June 30,		Three Months	Nine Months
(In Thousands)	2004	2003	2004	2003	Ended	Ended
Gas Distribution revenues:
Sales
Residential	$ 176,009	$ 200,072	$1,041,623	$1,046,277	$ (24,063)	$ (4,654)
Commercial	27,624	29,571	165,288	158,467	(1,947)	6,821
Industrial	4,504	4,495	27,391	29,068	9	(1,677)
Total sales	208,137	234,138	1,234,302	1,233,812	(26,001)	490

Transportation
Residential	5,878	7,229	28,449	33,297	(1,351)	(4,848)
Commercial	8,468	9,114	40,830	44,428	(646)	(3,598)
Industrial	3,841	3,540	15,954	16,937	301	(983)
Contract pooling	3,914	8,433	12,135	19,335	(4,519)	(7,200)
Total transportation	22,101	28,316	97,368	113,997	(6,215)	(16,629)

Other Gas Distribution revenues	4,373	4,577	12,340	12,014	(204)	326

Total Gas Distribution revenues	234,611	267,031	1,344,010	1,359,823	(32,420)	(15,813)
Less: Gas costs	118,637	140,187	799,756	783,391	(21,550)	16,365
Gross margin ⁽¹⁾	115,974	126,844	544,254	576,432	(10,870)	(32,178)
Less: Revenue taxes	22,257	19,921	125,548	121,824	2,336	3,724
Environmental costs recovered	3,052	3,262	15,142	20,119	(210)	(4,977)
Net margin ⁽¹⁾	$ 90,665	$ 103,661	$ 403,564	$ 434,489	$ (12,996)	$ (30,925)

Gas Distribution deliveries (MDth):
Gas sales
Residential	15,279	17,753	109,271	120,356	(2,474)	(11,085)
Commercial	2,731	2,990	18,598	19,445	(259)	(847)
Industrial	503	503	3,302	3,878	-	(576)
Total gas sales	18,513	21,246	131,171	143,679	(2,733)	(12,508)

Transportation
Residential	3,236	4,190	19,552	22,173	(954)	(2,621)
Commercial	7,219	7,397	38,491	39,631	(178)	(1,140)
Industrial	4,864	4,969	19,318	20,542	(105)	(1,224)
Total transportation	15,319	16,556	77,361	82,346	(1,237)	(4,985)

Total Gas Distribution deliveries	33,832	37,802	208,532	226,025	(3,970)	(17,493)

Gross margin per Dth delivered	$ 3.43	$ 3.36	$ 2.61	$ 2.55	$ 0.07	$ 0.06

Net margin per Dth delivered	$ 2.68	$ 2.74	$ 1.94	$ 1.92	$ (0.06)	$ 0.02

Average cost per Dth of gas sold	$ 6.41	$ 6.60	$ 6.10	$ 5.45	$ (0.19)	$ 0.65

Actual heating degree days (HDD)	692	845	6,002	6,567	(153)	(565)
Normal heating degree days ⁽²⁾	752	774	6,307	6,307

Actual heating degree days as a percent
of normal (actual/normal)	92	109	95	104

(1) As used above, net margin is not a financial measure computed under GAAP. Gross margin is the GAAP measure most closely related to net margin. Management believes net margin to be useful in understanding the Gas Distribution segment's operations because the utility subsidiaries are allowed, under their tariffs, to recover gas costs, revenue taxes and environmental costs from their customers on a dollar-for-dollar basis.

(2) Normal heating degree days are based on a 30-year average of monthly temperatures at Chicago's O'Hare Airport for the years 1970-1999. The difference between fiscal 2004 and 2003 third quarter normal degree days is caused by a shift of one heating season day from the third quarter to the second quarter due to leap year.

Revenues for the Gas Distribution segment for the three- and nine-month periods decreased $32.4 million and $15.8 million, respectively, from the previous periods. The decreases were mainly due to a decline in deliveries ($40.9 million and $100.9 million) resulting from weather that was 18 percent and nine percent warmer than the previous periods and conservation. Partially offsetting these effects was higher realized gas prices ($8.5 million and $85.1 million). Operating income for the three- and nine-month periods decreased $7.8 million and $35.6 million, respectively, compared with the previous periods due mainly to the effects of weather ($1.6 million and $14.1 million) and lower non-weather related delivery variations ($5.4 million and $9.2 million). Also contributing to lower operating income were reductions in municipal and state utility tax accruals recorded in the previous periods ($5.6 million and $9.7 million) and higher pension expense ($3.9 million and $7.1 million). Partially offsetting these effects was a decrease in the provision for uncollectible accounts ($5.5 million and $5.0 million) mainly as a result of improved credit and collection experience.

The Company expects the provision for uncollectibles to be lower for the full fiscal year as compared to fiscal 2003. The utilities continue to improve the collection of accounts receivable. Peoples Gas and North Shore Gas believe that their reserves are adequate given what is known at this time. The reserve for uncollectible accounts remains an estimate and could require future adjustments. The following table summarizes collection statistics for Peoples Gas.

	Peoples Gas
	Accounts Receivable Balance
	At June 30,
(Dollars in Millions)	2004	2003	2002
Current	$ 61.3	$ 74.5	$ 81.0
30-89 days	60.0	75.7	55.1
90-149 days	41.1	48.3	31.6

150 days - active	11.4	19.5	32.0
150 days - terminated	17.0	18.0	30.0
Total 150 days	28.4	37.5	62.0

Accounts receivable	$ 190.8	$ 236.0	$ 229.7

Reserve balance	$ 27.4	$ 29.5	$ 36.0
Reserve to accounts receivable ratio	14.4%	12.5%	15.7%
Reserve to 90 days +	39.4%	34.4%	38.5%
Days sales outstanding	56	69	83

The Company's weather insurance policy expires on September 30, 2004. The Company has obtained a new insurance policy for fiscal year 2005 through a subsidiary of X.L. America, Inc. Under this policy, the Company will receive $20,000 for each heating degree day in fiscal year 2005 below 6,100 (i.e., approximately five percent warmer than normal), up to a maximum of $10 million. If total heating degree days during fiscal year 2005 exceed 6,800 (i.e., approximately six percent colder than normal), the Company will pay an additional premium to the insurer of $10,000 for each heating degree day above 6,800.

Oil and Gas Production Segment. Revenues for the three- and nine-month periods increased $2.5 million and $15.8 million compared with the same periods last year. Operating income for the three-month period decreased $2.8 million compared with the previous period. The decrease in operating income for the three-month period was due to higher operating expenses and higher exploration expense ($3.8 million) related primarily to an unsuccessful exploratory well in Louisiana. Gas production was flat compared to the same period a year ago and lower than second quarter levels due to several operational and timing issues, as described below. Partially offsetting these effects was higher net realized commodity prices and higher income from the Company's equity investment in EnerVest Energy, L.P. (EnerVest). Operating income for the nine-month period increased $7.5 million compared with the previous period due mainly to higher production volumes and higher realized commodity prices, as well as higher income from the Company's investment in EnerVest ($3.1 million). On an equivalent basis, production increased 10 percent compared to the prior year nine-month period due primarily to the current and previous fiscal year's acquisitions and successful drilling program. An increase in depreciation, depletion and amortization expense ($4.9 million) resulted from higher production and an increase in the depletion rate.

Several operational and timing issues resulted in third quarter production volumes that were essentially flat with the year-ago period and less than had been anticipated. Production was hampered by a pipeline force majeure that resulted in 4 MMcfe per day of net production being shut in for nearly the entire month of June. The Company experienced a number of smaller production disruptions due to mechanical problems or well work operations during the quarter, all of which have been rectified going into the fiscal fourth quarter. Combined, these shut-ins resulted in nearly 3 MMcfe per day being off production for the quarter. The Company drilled 15 wells during the third quarter (of which 93 percent were successful), but only six of these wells produced for a portion of the quarter due to timing delays of getting the wells completed and ready for production. Over 2 MMcfe per day of net production for the quarter was delayed as a result. The Company expects to have these wells and a substantial portion of the fourth quarter program on line for a large part of the fourth quarter. The Company still expects solid production growth of 10 percent over fiscal 2003.

The following table summarizes hedges in place for the remaining fiscal 2004 (July through September) and 2005 for the Oil and Gas Production segment as of July 22, 2004 (date of information used in the Company's third quarter earnings release).

	Remaining Fiscal 2004	Fiscal 2005
Gas hedges in place (MMbtus)	6,549,000	22,143,500
Gas hedges as a percent of estimated fiscal production ⁽¹⁾	95%	75%
Percent of gas hedges that are swaps	52%	38%
Average swap price ($/MMbtu)	$ 4.14	$ 4.10
Percent of gas hedges that are no cost collars	48%	62%
Weighted average floor price ($/MMbtu)	$ 4.76	$ 4.37
Weighted average ceiling price ($/MMbtu)	$ 5.61	$ 5.45
Oil hedges in place (MBbls)	113	418
Oil hedges as a percent of estimated fiscal production ⁽¹⁾	80%	70%
Average hedge price ($/Bbl)	$ 26.60	$ 26.94

Based on expected production for fiscal 2004 and assumes fiscal 2005 production increases 10 percent over fiscal 2004 levels.

The following table summarizes operating statistics from the Oil and Gas Production segment.

	Three Months Ended June 30,		Nine Months Ended June 30,
	2004	2003	2004	2003
Total production - gas equivalent (MMcfe) ⁽¹⁾	6,649	6,574	21,089	19,138
Daily average gas production (MMcfd)	64.2	64.4	67.9	62.5
Daily average oil production (MBd)	1.5	1.3	1.5	1.3
Daily average production - gas equivalent (MMcfed) ⁽¹⁾	73.1	72.2	77.0	70.1
Gas production as a percentage of total production	88.0	89.0	88.0	89.0
Percent of production hedged during the period - gas	100.0	78.0	91.0	78.0
Percent of production hedged during the period - oil	83.0	55.0	75.0	60.0
Net realized gas price received ($/Mcf)	$ 4.60	$ 4.31	$ 4.46	$ 4.12
Net realized oil price received ($/Bbl)	$ 27.19	$ 22.72	$ 26.27	$22.53
Depreciation, depletion and amortization rate ($/Mcfe)	$ 1.72	$ 1.63	$ 1.70	$ 1.62
Average lease operating expense ($/Mcfe)	$ 0.58	$ 0.42	$ 0.43	$ 0.41
Average production taxes ($/Mcfe)	$ 0.43	$ 0.36	$ 0.34	$ 0.38

(1) Oil production is converted to gas equivalents based on a conversion of six Mcf of gas per barrel of oil.

Certain producing properties owned by Peoples Energy Production Company qualified for income tax credits as defined in Section 29 of the Internal Revenue Code of 1986. These credits expired on December 31, 2002. The amount recorded to income for the nine months ended June 30, 2003 was $1.1 million.

On December 31, 2003, the Company acquired, through a series of transactions, certain oil and gas properties located in Texas for approximately $33.1 million. The acquired reserves, 88 percent of which are natural gas, contributed approximately 3.2 MMcfe per day of production to the Company's fiscal year-to-date production. The majority of the acquired properties are located adjacent to or in close proximity to existing holdings of the Company, and each of the acquired properties are operated by the Company.

On July 30, 2004, subsequent to the end of the third quarter, the Company acquired certain oil and gas properties in east Texas from a private entity for approximately $9.5 million. The acquisition includes approximately 5,300 gross acres and estimated proved undeveloped reserves of approximately 10 Bcfe, with an additional 10 to 20 Bcfe of low risk, upside reserve potential. Initial development of the acquired reserves will begin in fiscal 2005 with anticipated capital spending on these properties of between $10 million to $15 million of a planned fiscal 2005 capital program. The acquired properties, which will be operated by the Company, are located in close proximity to the existing Peoples Energy Production holdings in east Texas.

Power Generation Segment. Results for the three and nine months ended were relatively unchanged from the prior period. Impacting the results was an increase in expenses related to the development of new power projects, partially offset by lower operating losses compared to the previous period related to Elwood Energy LLC (Elwood).

This segment is engaged in the development of power generation sites. The costs of activities related to these sites are either expensed as incurred or are capitalized as specific site development assets, as appropriate. Included in other investment at June 30, 2004 was $9.3 million related to this activity. The Company is actively pursuing the sale of one its power generation sites under development in the western United States.

The electric capacity of Elwood has been sold through long-term contracts with Exelon Generation Company, LLC, Engage Energy America LLC and Aquila, Inc. (Aquila). Standard & Poor's Rating Services (S&P) recently downgraded Aquila's senior unsecured debt rating to CCC+ and placed the rating on CreditWatch with developing implications. In fiscal 2003, Moody's Investor Services (Moody's) downgraded Aquila's senior unsecured debt rating to Caa1 with a negative outlook. S&P and Moody's have lowered the ratings on Elwood's bonds to B+ with a negative outlook and Ba2 with a stable outlook, respectively. As a result of earlier downgrading in Aquila's credit

ratings, Aquila provided Elwood with security in the form of letters of credit and a cash escrow equal to one year of capacity payments of approximately $37.7 million. In the event Aquila does not fulfill its payment obligations or terminates its power sales agreements and Elwood cannot make adequate alternate arrangements, Elwood could suffer a revenue shortfall or an increase in its costs that could adversely affect the ability of Elwood to fully perform its obligations under the indenture related to its outstanding bonds. If Elwood is adversely affected by the failure of Aquila to make payments under its power sales agreements, the Company may receive substantially reduced or no investment income from Elwood. At this time, the Company cannot determine whether or to what extent Aquila's failure to pay Elwood would result in a material adverse effect on the Company.

Midstream Services Segment. Revenues for the three- and nine-month periods increased $24.6 million and $24.4 million, respectively, compared with the previous periods due to higher commodity prices and increased volumes. Operating income for the three-month period increased $1.6 million compared with the prior period due to improved results from wholesale and asset management activities. Operating income for the nine-month period decreased $2.2 million compared with the prior period due primarily to lower results from the hub ($3.2 million). Partially offsetting this effect was higher contributions from wholesale and asset management activities and the Company's propane-based peaking facility.

Retail Energy Services Segment. The following table summarizes operating statistics for Peoples Energy Services Corporation.

	Three Months Ended June 30,		Nine Months Ended June 30,
(In Thousands, Except Customers)	2004	2003	2004	2003
Gas sales sendout (MDth)	8,525	7,919	41,638	35,780
Number of gas customers	20,554	16,798	20,554	16,798
Electric sales sendout (Mwh)	267	216	759	656
Number of electric customers	1,794	1,377	1,794	1,377

Revenues for the three- and nine-month periods increased from last year by $12.5 million and $58.7 million, respectively, primarily due to continued customer growth and higher gas and energy prices. Operating income for the three-month period increased slightly, with customer and volume growth offset by higher operating expenses. Operating income increased by $3.7 million in the fiscal year-to-date period due to customer growth and enhanced gas margin.

Peoples Gas Discussion

Most of Peoples Gas' results are recorded in the Gas Distribution segment, with some activity in the Midstream Services and Corporate segments. The following discussion supplements Peoples Gas information included in the Company's Gas Distribution discussion within this Management's Discussion and Analysis of Results of Operations and Financial Condition (MD&A).

Revenues for Peoples Gas for the three- and nine-month periods decreased approximately $26.2 million and $9.1 million, respectively, from the previous periods. The decrease was mainly due to a decline in deliveries ($35.1 million and $90.8 million) resulting from weather that was 18 percent and nine percent warmer than the previous periods and conservation. Partially offsetting these effects were higher realized gas prices ($9.1 million and $84.7 million). Operating income for the three-and nine-month periods decreased $9.7 million and $37.6 million compared with the previous periods due mainly to the effects of weather ($1.4 million and $12.3 million), lower non-weather related deliveries ($4.5 million and $8.1 million) and lower hub results ($0.4 million and $3.2 million). Also negatively impacting operating income were reductions in municipal and state utility tax accruals recorded in the previous periods ($5.6 million and $9.7 million) and increases in pension expense ($3.7 million and $6.4 million) and other non-labor operating costs. Partially offsetting these effects was a decrease in the provision for uncollectible accounts ($5.0 million and $4.5 million).

Interest expense for the three- and nine-month periods decreased $0.4 million and $1.5 million, respectively, compared with the previous periods primarily due to lower interest rates. The reduction was due to the impact of lower interest rates on variable rate debt and the retirement or refinancing of higher cost bonds.

North Shore Gas Discussion

Most of North Shore Gas' results are recorded in the Gas Distribution segment, with some activity in the Corporate segment. The following discussion supplements North Shore Gas information included in the Company's Gas Distribution discussion within this MD&A.

Revenues for North Shore Gas for the three- and nine-month periods decreased $6.6 million and $9.7 million over the previous periods resulting from a decrease in deliveries ($5.8 million and $10.1 million) due primarily to warmer weather. Operating income for the three- and nine-month periods decreased $0.4 million and $4.1 million compared with the previous periods due mainly to the effects of weather ($0.2 million and $1.8 million) and lower non-weather related deliveries ($0.9 million and $1.0 million). Also contributing to lower operating income were increases in pension expense, group insurance expense and outside services expense, partially offset by a gain on the sale of property and a decrease in the provision for uncollectible accounts.

The Peoples Gas Light and Coke Company
Gas Distribution Statistics

	Three Months Ended		Nine Months Ended		Increase/(Decrease)
Margin Data	June 30,		June 30,		Three Months	Nine Months
(In Thousands)	2004	2003	2004	2003	Ended	Ended
Gas Distribution revenues:
Sales
Residential	$ 149,910	$ 169,042	$ 885,293	$ 882,741	$ (19,132)	$ 2,552
Commercial	23,540	24,505	139,681	131,316	(965)	8,365
Industrial	3,775	3,624	21,489	23,077	151	(1,588)
Total sales	177,225	197,171	1,046,463	1,037,134	(19,946)	9,329

Transportation
Residential	5,559	6,944	26,978	32,041	(1,385)	(5,063)
Commercial	7,306	7,946	35,572	39,381	(640)	(3,809)
Industrial	3,221	2,884	13,757	14,579	337	(822)
Contract pooling	3,633	7,588	11,056	17,120	(3,955)	(6,064)
Total transportation	19,719	25,362	87,363	103,121	(5,643)	(15,758)

Other Gas Distribution revenues	3,989	4,185	11,359	11,042	(196)	317

Total Gas Distribution revenues	200,933	226,718	1,145,185	1,151,297	(25,785)	(6,112)
Less: Gas costs	98,929	115,317	668,427	645,474	(16,388)	22,953
Gross margin ⁽¹⁾	102,004	111,401	476,758	505,823	(9,397)	(29,065)
Less: Revenue taxes	20,162	17,542	113,679	109,323	2,620	4,356
Environmental costs recovered	2,933	3,092	14,066	19,434	(159)	(5,368)
Net margin ⁽¹⁾	$ 78,909	$ 90,767	$ 349,013	$ 377,066	$ (11,858)	$ (28,053)

Gas Distribution deliveries (MDth):
Gas sales
Residential	12,705	14,578	90,925	100,005	(1,873)	(9,080)
Commercial	2,305	2,433	15,449	15,895	(128)	(446)
Industrial	419	401	2,523	3,041	18	(518)
Total gas sales	15,429	17,412	108,897	118,941	(1,983)	(10,044)

Transportation
Residential	3,108	4,065	18,766	21,476	(957)	(2,710)
Commercial	6,127	6,391	32,872	34,510	(264)	(1,638)
Industrial	3,551	3,785	14,891	16,300	(234)	(1,409)
Total transportation	12,786	14,241	66,529	72,286	(1,455)	(5,757)

Total Gas Distribution deliveries	28,215	31,653	175,426	191,227	(3,438)	(15,801)

Gross margin per Dth delivered	$ 3.62	$ 3.52	$ 2.72	$ 2.65	$ 0.10	$ 0.07

Net margin per Dth delivered	$ 2.80	$ 2.87	$ 1.99	$ 1.97	$ (0.07)	$ 0.02

Average cost per Dth of gas sold	$ 6.41	$ 6.62	$ 6.14	$ 5.43	$ (0.21)	$ 0.71

Actual heating degree days (HDD)	692	845	6,002	6,567	(153)	(565)
Normal heating degree days ⁽²⁾	752	774	6,307	6,307

Actual heating degree days as a percent
of normal (actual/normal)	92	109	95	104

North Shore Gas Company
Gas Distribution Statistics

	Three Months Ended		Nine Months Ended		Increase/(Decrease)
Margin Data	June 30,		June 30,		Three Months	Nine Months
(In Thousands)	2004	2003	2004	2003	Ended	Ended
Gas Distribution revenues:
Sales
Residential	$ 26,099	$ 31,030	$ 156,330	$ 163,536	$ (4,931)	$ (7,206)
Commercial	4,084	5,066	25,607	27,151	(982)	(1,544)
Industrial	729	871	5,902	5,991	(142)	(89)
Total sales	30,912	36,967	187,839	196,678	(6,055)	(8,839)

Transportation
Residential	319	285	1,471	1,256	34	215
Commercial	1,162	1,168	5,258	5,047	(6)	211
Industrial	620	656	2,197	2,358	(36)	(161)
Contract pooling	281	845	1,079	2,215	(564)	(1,136)
Total transportation	2,382	2,954	10,005	10,876	(572)	(871)

Other Gas Distribution revenues	384	392	981	972	(8)	9

Total Gas Distribution revenues	33,678	40,313	198,825	208,526	(6,635)	(9,701)
Less: Gas costs	19,708	24,870	131,329	137,917	(5,162)	(6,588)
Gross margin ⁽¹⁾	13,970	15,443	67,496	70,609	(1,473)	(3,113)
Less: Revenue taxes	2,095	2,379	11,869	12,501	(284)	(632)
Environmental costs recovered	119	170	1,076	685	(51)	391
Net margin ⁽¹⁾	$ 11,756	$ 12,894	$ 54,551	$ 57,423	$ (1,138)	$ (2,872)

Gas Distribution deliveries (MDth):
Gas sales
Residential	2,574	3,175	18,346	20,351	(601)	(2,005)
Commercial	426	557	3,149	3,550	(131)	(401)
Industrial	84	102	779	837	(18)	(58)
Total gas sales	3,084	3,834	22,274	24,738	(750)	(2,464)

Transportation
Residential	128	125	786	697	3	89
Commercial	1,092	1,006	5,619	5,121	86	498
Industrial	1,313	1,184	4,427	4,242	129	185
Total transportation	2,533	2,315	10,832	10,060	218	772

Total Gas Distribution deliveries	5,617	6,149	33,106	34,798	(532)	(1,692)

Gross margin per Dth delivered	$ 2.49	$ 2.51	$ 2.04	$ 2.03	$ (0.02)	$ 0.01

Net margin per Dth delivered	$ 2.09	$ 2.10	$ 1.65	$ 1.65	$ (0.01)	$ 0.00

Average cost per Dth of gas sold	$ 6.39	$ 6.49	$ 5.90	$ 5.58	$ (0.10)	$ 0.32

Actual heating degree days (HDD)	692	845	6,002	6,567	(153)	(565)
Normal heating degree days ⁽²⁾	752	774	6,307	6,307

Actual heating degree days as a percent
of normal (actual/normal)	92	109	95	104

Fiscal 2004 and 2005 Outlook

While operating income from the diversified energy businesses is expected to be up 25 to 30 percent over last year, this strong performance will not overcome the negative effects of lower Gas Distribution deliveries. As a result, the Company now expects that fiscal 2004 earnings will be in the range of $2.60 to $2.70 per share, excluding the charge expected to be incurred in the fourth fiscal quarter associated with the Company's restructuring, which cannot be estimated at this time. This range is based on several factors, including a return to normal weather for the rest of the fiscal year, an assumed average NYMEX price for gas of $5.90 per MMbtu, ongoing cost control measures, pension expense of approximately $10 million, and a higher average number of shares outstanding of approximately 37.5 million. Also included in this estimate are expected gains on the sale of assets in the Power Generation and Gas Distribution segments totaling approximately $0.10 per share. Although progress continues in moving toward those sales, the timing is difficult to predict and these transaction could potentially occur in fiscal 2005. The current estimate for fiscal 2004 capital spending is $190 million. (See Forward-Looking Information.)

The Company is optimistic that fiscal 2005 results will improve over fiscal 2004. The Gas Distribution business remains fundamentally strong, and the Company is confident that the recently announced strategic reorganization and other ongoing cost reduction initiatives within the utilities and corporate support organization will provide immediate savings in fiscal 2005. In addition, the Company expects to achieve 10 percent or better growth from the diversified businesses. Although the Company currently is in the process of preparing the budget for fiscal 2005, on a preliminary basis, the July 22, 2004 First Call range of analysts' estimates of $2.70 to $2.88 per share is reasonable, assuming normal weather. (See Forward-Looking Information.)

Critical Accounting Policies

See the MD&A in the Company's Annual Report on Form 10-K for the fiscal year ended September 30, 2003 for a detailed discussion of the Company's critical accounting policies. These policies include Regulated Operations, Environmental Activities Relating to Former Manufactured Gas Operations, Retirement and Postretirement Benefits, Derivative Instruments and Hedging Activities, and Provision for Uncollectible Accounts. In May 2004, the FASB issued FSP No. 106-2, "Accounting and Disclosure Requirements Related to the Medicare Prescription Drug Improvement and Modernization Act of 2003." (See Note 2 of the Notes to Consolidated Financial Statements.)

Other Matters

Strategic Restructuring. Subsequent to the close of the third quarter, the Company announced that it has initiated a strategic restructuring plan. (See Note 9 of the Notes to Consolidated Financial Statements.)

LIQUIDITY AND CAPITAL RESOURCES

The following is a summary of cash flows for the Company:

	Nine Months Ended June 30,
(In Thousands)	2004	2003
Net cash provided by operating activities	$ 262,167	$ 237,675
Net cash used in investing activities	$ (128,234)	$ (117,636)
Net cash used in financing activities	$ (71,681)	$ (73,465)

Cash provided by operating activities increased for the nine months ended June 30, 2004 as compared to the nine months ended June 30, 2003, primarily due to favorable net changes to working capital that were partially offset by lower net income. The increase in net cash used in investing activities was due to increased capital spending in the Oil and Gas Production segment. While the change in net cash used in financing activities was relatively flat,

notable activity included lower retirements of short-term debt and commercial paper in the current period and lower net issuance of long-term debt in the current period.

See the Consolidated Statements of Cash Flows and the discussion of major balance sheet variations for more detail.

Balance Sheet Variations

Total assets at June 30, 2004 increased $126.5 million as compared to September 30, 2003 primarily due to the seasonal increase in the Gas Distribution and Retail Energy Services segments, customer accounts receivable, additional capital investment in the Gas Distribution and Oil and Gas Production segments, receivables from hedges and increased cash and cash equivalents. These items were offset, in part, by normal seasonal changes in gas inventory levels. The Company's decrease in current liabilities was driven primarily by refinancing short-term debt with long-term debt and by having no commercial paper outstanding, partially offset by increases in liabilities related to normal seasonal LIFO gas inventory adjustment, liabilities related to hedging, revenue tax and income tax accruals and accounts payable. The Company's capitalization increased as a result of the refinancing of a portion of short-term debt with long-term debt, fiscal year-to-date earnings, net of dividends declared, and common stock issued through the continuous equity program, dividend reinvestments and long-term incentive compensation plans.

Total assets at June 30, 2004 increased $118.7 million compared to June 30, 2003 reflecting the Company's continued capital investment in its Gas Distribution and Oil and Gas Production segments. The Company's inventory increase can be attributed to higher gas prices and 5.8 Bcf higher inventory volume in the Gas Distribution, Midstream Services and Retail Energy Services segments. Offsetting these increases were lower customer accounts receivable balances resulting from the Company's continuing collection efforts. Long-term assets, long-term liabilities and accumulated other comprehensive income (AOCI) were affected by a pension adjustment recorded in September 2003 caused by lower discount rates and returns on pension assets. The Company's capitalization increased as a result of refinancing a portion of short-term debt with long-term debt and ongoing common stock issuances through the continuous equity program, dividend reinvestments and long-term incentive compensation plans.

Changes in Debt Securities

There were no changes to the Company's debt securities during the third quarter of fiscal 2004. The following table summarizes the changes that have occurred in the composition of the Company's debt during the current fiscal year.

(Dollars In Millions)	Issuances			Retirements
Peoples Gas	$ 51.0	(1)	Auction Rate 34-year,	$ 27.0	(1)(3)	Variable rate, Series EE
			Series OO (2)	37.5	(1)(3)	Variable rate, Series II
	51.0	(1)	Auction Rate 34-year,	37.5	(1)(3)	Variable rate, Series JJ
			Series PP (2)	75.0	(1)	5.75%, Series DD
	75.0	(1)	Variable rate, 35-year (4.875%
			fixed 15 years), Series QQ
Total	$177.0			$177.0

(1) Tax Exempt
(2) Current Mode Auction Rate 35-day period
(3) Classified as short-term debt

In addition, subsequent to the close of the quarter, the Company fixed the interest rate for the Peoples Gas $50 million Series HH bonds at 4.75% until July 2014. Due to the tender provisions of the Series HH Bonds and the remarketing periods being less than one year, at June 30, 2004 the debt was classified as short term. Since the new remarketing period exceeds one year, beginning in the fourth quarter the debt will be classified as long term.

Financial Sources

In addition to cash generated internally by operations, as of June 30, 2004, the Company had committed credit facilities of $392.5 million (Peoples Energy, $225.0 million; Peoples Gas, $167.5 million, of which $37.0 million could be utilized by North Shore Gas). These various facilities primarily support the Company's ability to borrow using commercial paper. As of June 30, 2004, all of Peoples Energy's $225.0 million facilities were available and $167.0 million of the $167.5 million Peoples Gas and North Shore Gas facilities were available. The Peoples Energy credit facilities expire in March 2007.

On August 4, 2004, Peoples Gas replaced the $167.5 million of bilateral credit facilities available to Peoples Gas and North Shore Gas with a $200.0 million 364-day syndicated facility available to Peoples Gas that will expire in August 2005. North Shore Gas intends to meet its future short-term borrowing requirements through loans from Peoples Energy or Peoples Gas. The banks that are party to Peoples Gas' syndicated facility are ABN AMRO Bank, N.V. (Agent), Harris Nesbitt Financing, Inc., JPMorgan Chase Bank, The Northern Trust Company, Sumitomo Mitsui Banking Corporation, KBC Bank N.V., U.S. Bank National Association, The Bank of New York, Merill Lynch Bank USA and Fifth Third Bank.

The Company's and Peoples Gas' credit facilities contain debt triggers that permit the lenders to terminate the credit commitments to the borrowing company and declare any outstanding amounts due and payable if the borrowing company's debt-to-total capital ratio exceeds 65 percent. The current debt-to-total capital ratio for the Company, Peoples Gas and North Shore Gas is 50 percent, 44 percent and 39 percent, respectively.

In addition to the committed credit facilities discussed above, the Company has an uncommitted line of credit of $15.0 million, which was unused as of June 30, 2004. Peoples Gas and North Shore Gas also have the authority to borrow up to $150.0 million and $50.0 million, respectively, from Peoples Energy. As of June 30, 2004, neither Peoples Gas nor North Shore Gas had any loans outstanding from Peoples Energy.

The current credit ratings for the Company, Peoples Gas and North Shore Gas have not changed since the filing of the September 30, 2003 Annual Report on Form 10-K.

Changes in Equity Securities

During fiscal 2003 the Company filed a universal shelf registration statement on Form S-3 for the issuance from time to time of up to 1.5 million shares of common stock pursuant to a continuous equity offering in one or more negotiated transactions or "at-the-market" offerings. Since inception of this plan, the Company has issued 1,235,700 shares with proceeds, net of issuance costs, totaling $47.9 million. No shares have been issued subsequent to March 31, 2004. This and other common stock activity is summarized in the table below.

	Three Months Ended		Nine Months Ended
	June 2004		June 2004
(Dollars in Thousands)	Shares	Dollars	Shares	Dollars
Beginning balance	37,502,425	$ 371,621	36,689,968	$ 339,785
Shares issued:
Employee Stock Purchase Plan	6,937	258	13,244	487
Long-Term Incentive Compensation
Plan - net	8,081	542	305,212	11,179
Continuous equity offerings	-	(8)	377,400	15,450
Directors Stock and Option Plan	-	-	766	32
Direct Purchase and Investment Plan	65,511	2,774	196,364	8,254
Total activity for the period	80,529	3,566	892,986	35,402

Ending balance	37,582,954	$ 375,187	37,582,954	$ 375,187

Financial Uses

Capital Spending. In the nine-month period ended June 30, 2004, the Company spent $144.9 million on capital projects. The Gas Distribution segment spent $53.0 million on property, plant and equipment of which $46.2 million was spent by Peoples Gas and $6.8 million was spent by North Shore Gas. The majority of the remaining $91.9 million was spent by the Oil and Gas Production segment, which spent $87.0 million on the acquisition of reserves, drilling projects and the exploitation of the acquired and existing assets. Management currently estimates that capital spending for fiscal 2004 will total approximately $190 million. Including the acquisition of properties on July 30, 2004, expenditures in the Oil and Gas Production segment are expected to total $100 million to $105 million assuming no additional acquisitions in the fiscal year. Most of the remaining balance of the Company's total capital expenditures for fiscal year 2004 is targeted for the Gas Distribution segment.

Dividends . On February 4, 2004, the Directors of the Company voted to increase the regular quarterly dividend on the Company's common stock from 53 cents per share to 54 cents per share. The first payment at this new level was made on April 15, 2004 to shareholders of record at the close of business on March 22, 2004.

Commitments and Contingencies

The Company has certain contractual obligations directly related to the Company's operations and unconsolidated equity investees. The majority of these are long-term debt related with other substantial commitments for gas supply, transportation and storage contracts.

Contractual Obligations and Other Commitments. Since the filing of the September 30, 2003 Annual Report on Form 10-K there have been no significant changes to contractual obligations.

Off-balance Sheet Financing. Off-balance sheet debt at June 30, 2004 and 2003 consists of the Company's pro rata share of nonrecourse debt of various equity investments, including Trigen-Peoples District Energy Company (Trigen-Peoples) ($15.1 million and $15.4 million), EnerVest ($8.3 million and $2.7 million) and Elwood ($184.0 million and $191.1 million). The Company believes this off-balance sheet financing will not have a material effect on the Company's future financial condition. The Company also has commercial obligations of $50.4 million in guarantees and $7.2 million in letters of credit at June 30, 2004.

Environmental Matters . Peoples Gas and North Shore Gas are conducting environmental investigations and remedial work at certain sites that were the locations of former manufactured gas operations. (See Note 5 of the Notes to Consolidated Financial Statements.)

In 1994, North Shore Gas received a demand from a responsible party under CERCLA for environmental costs associated with a former mineral processing site in Denver, Colorado. The demand alleged that North Shore Gas is a successor to the liability of a former entity that allegedly disposed of mineral processing wastes there between 1934 and 1941. (See Note 5 of the Notes to Consolidated Financial Statements.)

Gas Charge Reconciliation Proceedings and Related Matters. For each utility subsidiary, the Commission conducts annual proceedings regarding the reconciliation of revenues from the Gas Charge and related gas costs. In these proceedings, the accuracy of the reconciliation of revenues and costs is reviewed and the prudence of gas costs recovered through the Gas Charge is examined by interested parties. Proceedings regarding Peoples Gas and North Shore Gas for fiscal 2003, 2002 and 2001 costs are currently pending before the Commission. In February 2004, a purported class action was filed against the Company and Peoples Gas by a Peoples Gas customer alleging, among other things, violation of the Illinois Consumer Fraud and Deceptive Business Practices Act related to matters at issue in Peoples Gas' gas reconciliation proceedings. (See Note 6 of the Notes to Consolidated Financial Statements.)

Indenture Restrictions

North Shore Gas' indenture relating to its first mortgage bonds contains provisions and covenants restricting the payment of cash dividends and the purchase or redemption of capital stock. At June 30, 2004, such restrictions amounted to $6.9 million of North Shore Gas' total retained earnings of $84.8 million.

Peoples District Energy Corporation owns a 50 percent equity interest in Trigen-Peoples. The Construction and Term Loan Agreement between Trigen-Peoples and Prudential Insurance Company of America related to Trigen-Peoples' project financing prohibits any distribution that would result in the partners' total capital account in Trigen-Peoples being less than $7.0 million. At June 30, 2004, the partners' capital account was $7.3 million. The Construction and Term Loan Agreement also prohibits any distribution unless the partnership's debt service coverage ratio for the four fiscal quarters prior to the distribution was at least 1.25 to 1.0. Trigen-Peoples' debt service coverage ratios for the last four fiscal quarters starting with the most recent quarter were 1.85 to 1.0, 2.09 to 1.0, 1.72 to 1.0, and 1.90 to 1.0.

Peoples Energy Resources Company, LLC owns a 50 percent equity interest in Elwood. Elwood's trust indenture and other agreements related to its project financing prohibit Elwood from making distributions, unless Elwood has maintained certain minimum historic and projected debt service coverage ratios. At July 6, 2004, the most recent semi-annual distribution date, a minimum debt service coverage ratio of 1.2 to 1.0 was required and Elwood's actual debt service coverage ratio was approximately 1.5 to 1.0.

FORWARD-LOOKING INFORMATION

This MD&A contains statements that may be considered forward-looking, such as: management's expectations, the statements of the Company's business and financial goals regarding its business segments, the effect of weather on net income, cash position, source of funds, financing activities, market risk, the insignificant effect on income arising from changes in revenue from customers' gas purchases from entities other than the Gas Distribution subsidiaries, the adequacy of the Gas Distribution segment's reserves for uncollectible accounts, capital expenditures of the Company's subsidiaries, and environmental matters. These statements speak of the Company's plans, goals, beliefs, or expectations, refer to estimates or use similar terms. Generally, the words "may," "could," "project," "believe," "anticipate," "estimate," "plan," "forecast," "will be" and similar words identify forward-looking statements. Actual results could differ materially, because the realization of those results is subject to many uncertainties including:

adverse decisions in proceedings before the Commission concerning the prudence review of the utility subsidiaries' gas purchases;
the effects of the Company's announced strategic reorganization;
the future health of the United States and Illinois economies;
the timing and extent of changes in interest rates and energy commodity prices, including but not limited to the effect of gas prices on cost of gas supplies, accounts receivable and the provision for uncollectible accounts and interest expense;
adverse resolution of material litigation;
effectiveness of the Company's risk management policies and the creditworthiness of customers and counterparties;
regulatory developments in the United States, Illinois and other states where the Company does business;
changes in the nature of the Company's competition resulting from industry consolidation, legislative change, regulatory change and other factors, as well as action taken by particular competitors;
the Company's success in identifying diversified business segment projects on financially acceptable terms and generating earnings from projects in a reasonable time;
operational factors affecting the Company's Gas Distribution, Oil and Gas Production and Power Generation segments;
Aquila's financial ability to perform under its power sales agreements with Elwood;
drilling risks and the inherent uncertainty of oil and gas reserve estimates;

weather and price effects on energy demand; and
terrorist activities.

Some of these uncertainties that may affect future results are discussed in more detail in Item 1 - Business and Item 7 - MD&A, in the combined Annual Report on Form 10-K most recently filed with the SEC by the Company, Peoples Gas and North Shore Gas. All forward-looking statements included in this MD&A are based upon information presently available, and the Company, Peoples Gas and North Shore Gas assume no obligation to update any forward-looking statements.

ITEM 3. Quantitative and Qualitative Disclosures about Market Risk

Quantitative and qualitative disclosures about market risk are reported under Note 2 of the Notes to Consolidated Financial Statements.

ITEM 4. Controls and Procedures

The Company, Peoples Gas and North Shore Gas maintain disclosure controls and procedures (as defined in Rule 13a-15e of the Securities Exchange Act of 1934, as amended) which are designed to ensure that information required to be disclosed by the Company, Peoples Gas and North Shore Gas in the reports that are submitted or filed with the SEC is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms. Thomas M. Patrick, principal executive officer and Thomas A. Nardi, principal financial officer of the Company, Peoples Gas and North Shore Gas, have evaluated the disclosure controls and procedures as of the end of the period covered by this report. Based upon that evaluation, Messrs. Patrick and Nardi have concluded that the disclosure controls and procedures are effective.

During the period covered by this report, there was no change in the companies' internal control over financial reporting identified in connection with the evaluation of the disclosure controls and procedures that has materially affected, or is reasonably likely to materially affect, the companies' internal control over financial reporting.

Part II - Other Information

Item 1. Legal Proceedings

See Note 5 of the Notes to Consolidated Financial Statements - Environmental Matters for a discussion pertaining to environmental matters and Note 6 of the Notes to Consolidated Financial Statements - Gas Charge Reconciliation Proceedings and Other Matters pertaining to proceedings at the Commission regarding the prudency of gas purchases by Peoples Gas and North Shore Gas, which notes are incorporated herein by reference.

Item 2. Changes in Securities and Use of Proceeds

None.

Item 3. Defaults Upon Senior Securities

None.

Item 4. Submission of Matters to a Vote of Security Holders

None.

Item 5. Other Information

None.

Item 6. Exhibits and Reports on Form 8-K

Peoples Energy Corporation :

a. Exhibits

Exhibit

Number

Description of Document

10(a)

Directors Deferred Compensation Plan, as amended April 7, 2004.

10(b)

Amendment No. 3 to FTS Service Agreement, Contract No. 113418 between Natural Gas Pipeline Company of America and Peoples Gas, dated February 18, 2004.

10(c)

FTS Service Agreement, Contract No. 130626 between Natural Gas Pipeline Company of America and Peoples Gas, dated February 18, 2004.

10(d)

FTS Service Agreement, Contract No. 130628 between Natural Gas Pipeline Company of America and Peoples Gas, dated February 18, 2004.

10(e)

Amendment No. 4 to DSS Storage Agreement, Contract No. 117164 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 17, 2004.

10(f)

Amendment No. 2 to FTS Service Agreement, Contract No. 117117 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.

			10(g)		Amendment No. 3 to FTS Service Agreement, Contract No. 113421 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.
			10(h)		FTS Service Agreement, Contract No. 130625 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.
			10(i)		FTS Service Agreement, Contract No. 130629 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.
			12		Statement re: Computation of Ratio of Earnings to Fixed Charges for the Company
			31(a)		Certification of Thomas M. Patrick on behalf of the Company pursuant to 17 CFR 240.13a-14(a) or 17 CFR 240.15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
			31(b)		Certification of Thomas A. Nardi on behalf of the Company pursuant to 17 CFR 240.13a-14(a) or 17 CFR 240.15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
			32(a)		Certification of Thomas M. Patrick on behalf of the Company, Peoples Gas and North Shore Gas pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
			32(b)		Certification of Thomas A. Nardi on behalf of the Company, Peoples Gas and North Shore Gas pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

		b. Reports on Form 8-K filed or furnished during the quarter ended June 30, 2004
			Date of Report - April 14, 2004
			Item 5 - Other Events
			Item 12 - Disclosure of Results of Operations and Financial Condition
			Analyst Presentation

			Date of Report - April 23, 2004
			Item 9 - Regulation FD Disclosure
			Item 12 - Disclosure of Results of Operations and Financial Condition
			Press Release

			Date of Report - April 29, 2004
			Item 5 - Other Events
			Conference Call Script and Forward-Looking Information

			Date of Report - April 30, 2004
			Item 9 - Regulation FD Disclosure
			Item 12 - Disclosure of Results of Operations and Financial Condition
			Analyst Presentation

The Peoples Gas Light and Coke Company :

	a. Exhibits

		Exhibit
		Number	Description of Document
		10(b)	Amendment No. 3 to FTS Service Agreement, Contract No. 113418 between Natural Gas Pipeline Company of America and Peoples Gas, dated February 18, 2004.
		10(c)	FTS Service Agreement, Contract No. 130626 between Natural Gas Pipeline Company of America and Peoples Gas, dated February 18, 2004.
		10(d)	FTS Service Agreement, Contract No. 130628 between Natural Gas Pipeline Company of America and Peoples Gas, dated February 18, 2004.
		31(a)	Certification of Thomas M. Patrick on behalf of Peoples Gas pursuant to 17 CFR 240.13a-14(a) or 17 CFR 240.15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
		31(b)	Certification of Thomas A. Nardi on behalf of Peoples Gas pursuant to 17 CFR 240.13a-14(a) or 17 CFR 240.15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
		32(a)	Certification of Thomas M. Patrick on behalf of the Company, Peoples Gas and North Shore Gas pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
		32(b)	Certification of Thomas A. Nardi on behalf of the Company, Peoples Gas and North Shore Gas pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

		b. Reports on Form 8-K filed during the quarter ended June 30, 2004
			None.

North Shore Gas Company :

	a. Exhibits

		Exhibit
		Number	Description of Document
		10(e)	Amendment No. 4 to DSS Storage Agreement, Contract No. 117164 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 17, 2004.
		10(f)	Amendment No. 2 to FTS Service Agreement, Contract No. 117117 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.

	10(g)	Amendment No. 3 to FTS Service Agreement, Contract No. 113421 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.
	10(h)	FTS Service Agreement, Contract No. 130625 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.
	10(i)	FTS Service Agreement, Contract No. 130629 between Natural Gas Pipeline Company of America and North Shore Gas, dated February 18, 2004.
	31(a)	Certification of Thomas M. Patrick on behalf of North Shore Gas pursuant to 17 CFR 240.13a-14(a) or 17 CFR 240.15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
	31(b)	Certification of Thomas A. Nardi on behalf of North Shore Gas pursuant to 17 CFR 240.13a-14(a) or 17 CFR 240.15d-14(a), as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
	32(a)	Certification of Thomas M. Patrick on behalf of the Company, Peoples Gas and North Shore Gas pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
	32(b)	Certification of Thomas A. Nardi on behalf of the Company, Peoples Gas and North Shore Gas pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
b. Reports on Form 8-K filed during the quarter ended June 30, 2004
	None.

SIGNATURE


Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		Peoples Energy Corporation
		(Registrant)

August 10, 2004		By: /s/ THOMAS A. NARDI
(Date)		Thomas A. Nardi
		Senior Vice President and Chief Financial Officer

		(Same as above)
		Principal Financial Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		The Peoples Gas Light and Coke Company
		(Registrant)

August 10, 2004		By: /s/ THOMAS A. NARDI
(Date)		Thomas. A. Nardi
		Senior Vice President and Chief Financial Officer

		(Same as above)
		Principal Financial Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		North Shore Gas Company
		(Registrant)

August 10, 2004		By: /s/ THOMAS A. NARDI
(Date)		Thomas. A. Nardi
		Senior Vice President and Chief Financial Officer

		(Same as above)
		Principal Financial Officer

Exhibit 10(a)

DIRECTORS DEFERRED COMPENSATION PLAN
(As amended and restated, effective April 7, 2004)

1. Purpose

The purpose of the Directors Deferred Compensation Plan (the "Plan") is to attract and retain well-qualified persons who are not employees of Peoples Energy Corporation (the "Company") or any of its subsidiaries for service as directors of the Company by providing such persons with the opportunity to defer, in cash and/or shares of the Company's common stock, all or a portion of the compensation which they earn as directors of the Company.

2. Administration

The Board of Directors of the Company (the "Board") shall have Authority to administer and interpret the provisions of the Plan and to prescribe forms and promulgate rules and regulations with respect thereto. All determinations of the Board with respect to the Plan shall be final and binding upon all persons.

3. Eligibility

Directors of the Company who are not employees of the Company or any of its subsidiaries are eligible to participate in the Plan.

4. Shares Available for Issuance

Up to 200,000 authorized, but unissued shares of the Company's common stock, without par value (the "Common Stock") may be issued pursuant to the Plan. No shares of Common Stock shall be issued pursuant to this Plan prior to compliance with requirements under applicable laws and regulations.

5. Election to Defer

(a) An election to defer, or to cease to defer, compensation earned as a director of the Company shall be effective only with respect to compensation earned in the calendar year following the year in which the election is made, but in no event with respect to compensation earned within six months of the date on which the election is made; provided, however, that solely with respect to an election to defer in whole or in part the "Stock Payment" to be made May 1, 2000 under the Company's Directors Stock and Option Plan, such election to defer may be made by a director delivering written notice thereof to the Company no later than March 31, 2000. An election to defer shall specify the form and timing of payment under the Plan. All elections shall be in writing and shall be made on such forms and in such manner as the Board may from time to time prescribe.

(b) An election shall be binding upon, and shall inure to the benefit of the heirs, legatees and personal representatives of the participant and the successors and assigns of the Company.

6. Deferral of Compensation

(a) Each participant may, with respect to cash compensation earned as a director of the Company, elect to have (i) all or a portion of such compensation deferred and paid in cash in the manner set forth in subparagraphs 6(c) and 6(d) below and/or (ii) all or a portion of such compensation deferred and paid in shares of Common Stock in the manner set forth in subparagraphs 6(e) and 6(f) below. Additionally, each participant who elected to defer all or a portion of the "Stock Payments" deliverable prior to December 5, 2002, pursuant to the Company's Directors Stock and Option Plan shall have such deferred amounts paid in the form of shares of Common Stock in the manner set forth in subparagraph 6(e) and 6(f) below, subject to the availability of shares of Common Stock for issuance under Paragraph 3 of the Directors Stock and Option Plan (as such shares may be adjusted pursuant to Paragraph 8 thereof), as modified, amended or supplemented from time to time.

(b) A bookkeeping account shall be established for each participant. The account shall reflect the amount of cash to which the participant is entitled in accordance with subparagraph 6(c) below and/or the number of share equivalents to which the participant is entitled in accordance with subparagraph 6(e) below.

(c) The account of a participant who elects to defer compensation in the form of cash shall be credited with the dollar amount of compensation so deferred on each date that the participant is entitled to payment for services as a director. Interest on the cash balance of the account shall be computed and credited quarterly on March 31, June 30, September 30 and December 31 of each year at the prime commercial rate as reported in the Wall Street Journal.

(d) Payment to the participant in the form of cash shall be made in a single payment on such date, or in such number of equal annual installments commencing on such date, as provided in the participant's election.

(e) The account of a participant who elects to defer compensation in the form of stock shall be credited with share equivalents on each date that the participant is entitled to a payment for services as a director. The number of share equivalents to be credited shall be determined by dividing the amount of compensation so deferred by the mean price of a share of Common Stock on the New York Stock Exchange on the date that the participant is entitled to a payment for services as a director. Additional share equivalents shall be credited to the participant's account on each date that the Company pays a dividend on the Common Stock. The number of additional share equivalents so credited shall be determined by dividing the dividend which would be paid on the number of shares of Common Stock equal to the number of share equivalents credited to the participant's account as of the dividend record date by an amount equal to the mean price of a share of Common Stock on the New York Stock Exchange on the date which such dividend is paid to the Company's shareholders. In determining the number of share equivalents to be credited to a participant's account in accordance with this subparagraph 6(e), fractions of share equivalents shall be computed to three decimal places.

(f) Payment to the participant in the form of shares of Common Stock shall be made in whole shares in a single payment on such date, or in such number of equal annual installments (or in installments as nearly equal as possible without the issuance of fractional shares) commencing on such date, as provided in the participant's election. Any fractional share to which the participant is entitled as of date of the single payment or last installment shall be paid in cash.

7. Payment in the Event of Participant's Death

Neither the participant nor any other person claiming under the participant shall have any right to the payment of any compensation deferred under the Plan in advance of the schedule of payments as provided in the participant's election except that:

(a) Any of the deferred compensation which shall not have been paid to the participant during his or her lifetime shall be paid to the participant's spouse, if any, who shall survive the participant or to such person or persons other than such surviving spouse as the participant may designate in writing to receive the same. The participant shall have the right during his or her lifetime to designate and to change the designation of the person or persons to whom the Company shall make any payments of deferred compensation remaining unpaid at the death of the participant and to designate and to change the designation of the timing of such payments.

(b) In the event of the death of the participant prior to his or her receiving any deferred compensation, the single payment or installment payments provided for in subparagraph 7(a) above shall be made or shall commence on the first day of the second month following the month in which the death of the participant occurred.

(c) Payments of deferred compensation required to be made to their surviving spouse of the participant of to such other persons or persons as the participant may have designated in writing to the Company to receive the same pursuant to subparagraphs 7(a) or 7(b) above shall be made in the same manner and, except as provided in subparagraph 7(b) above, at the same time or times as such amount or amounts would have been paid to the participant's election.

(d) If any amount of the deferred compensation shall remain unpaid upon the death of the last to survive of (i) the participant, (ii) the participant's spouse, unless a person or persons other than the spouse has been designated to receive the same, as provided in subparagraph 7(a) above, or (iii) such other person or persons who may have been so designated, the Company shall pay the aggregated amount thereof to the executor or administrator of the estate of the last to survive of the following:

the participant
the participant's spouse, unless a person or persons other than the spouse has been designated as provided in subparagraph 7(a) above; or
any person theretofore receiving payments under a written designation as in this paragraph 7 provided.

The words "person or persons" wherever they appear in this paragraph 7 are intended and shall be construed for all purposes to include the estate of the participant.

8. No Right of Assignment or Acceleration

The right of the participant, the participant's spouse, or any other person designated to receive deferred compensation is personal and, except as provided in subparagraphs 7(a) and 7(b) above, is not subject to acceleration or assignment. The Company shall have no liability for the payment of any of the deferred compensation to any other person or in any other person or in any other manner than is provided in this Plan.

9. Amendment or Discontinuance

The Board may amend, rescind or terminate the Plan as it shall deem advisable; provided, however, that no change shall have a retroactive effect and no change shall be made with respect to compensation deferred under the Plan which would impair a participant's rights to such compensation without his or her consent.

10. Governing Law

This Plan and all determinations made actions taken pursuant hereto shall be governed by the laws of the State of Illinois pertaining to contracts made and to be performed wholly within such jurisdiction, except as federal law may apply.

11. Adjustments Upon Changes in Capitalization

In the event there is any change in the Common Stock of the Company through the declaration of stock dividends, or through recapitalization resulting in stock split-ups, or combinations or exchanges of shares, or otherwise, then the number of shares remaining available for issuance under the Plan shall be appropriately adjusted. Appropriately adjustment shall also be made to the number of shares to which a participant is entitled under the Plan.

12. Effective Date

This amendment and restatement of the Plan is effective April 7, 2004.

EXHIBIT 10(b)

Contract No. 113418

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
TRANSPORTATION RATE SCHEDULE FTS
AMENDMENT NO.3 DATED February 18, 2004
TO AGREEMENT DATED January 15,1998 (Agreement)

1. [X] Exhibit A dated February 18, 2004. Changes Primary Receipt Point(s) and Point MDQ's. This Exhibit A replaces any previously dated Exhibit A.

2. [ ] Exhibit B dated February 18, 2004. Changes Primary Delivery Point(s) and Point MDQ's. This Exhibit B replaces any previously dated Exhibit B.

3. [ ] Exhibits A and B dated February 18, 2004. Changes Primary Receipt and Delivery Points and Point MDQ's. These Exhibits A and B replace any previously dated Exhibits A and B.

4. [X] Exhibit C dated February 18, 2004. Changes the Agreement's Path. This Exhibit C replaces any previously dated Exhibit C.

5. [ ] Revise Agreement MDQ: [ ] Increase [ ] Decrease
In Section 2. of Agreement substitute Dth for Dth.

6. [ ] Revise Service Options

Service option selected (check any or all):

[ ] LN

[ ] SW

[ ] NB

7. [ ] The term of this Agreement is extended through ___________________.

8. [ ] Other:

This Amendment No.3 becomes effective May 1, 2004.

Except as hereinabove amended, the Agreement shall remain in full force and effect as written.

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		THE PEOPLES GAS LIGHT AND COKE COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

EXHIBIT A
DATED: February 18, 2004
EFFECTIVE DATE: May 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 113418

RECEIPT POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY RECEIPT POINT/S

5/1/2004 - 7/31/2004
1. ONEOKFS/NGPL STINNETT PLANT RESIDUE	MOORE	TX	36971	02	37200

2. TPC/NGPL GAGE	GAGE	NE	902900	07	67871
INTERCONNECT WITH TRAILBLAZER PIPELINE IN
SEC. 15-T4N-R6E, GAGE COUNTY, NEBRASKA.

8/1/2004 - 10/31/2004
3. ONEOKFS/NGPL STINNETT PLANT RESIDUE	MOORE	TX	36971	02	49600

4. TPC/NGPL GAGE	GAGE	NE	902900	07	55471
INTERCONNECT WITH TRAILBLAZER PIPELINE IN
SEC. 15-T4N-R6E, GAGE COUNTY, NEBRASKA.

11/1/2004 - 4/30/2005
5. ONEOKFS/NGPL STINNETT PLANT RESIDUE	MOORE	TX	36971	02	55500

6. EL PASO/NGPL TAP MOORE	MOORE	TX	3251	02	49571
INTERCONNECT WITH EL PASO NATURAL GAS
ON TRANSPORTER'S AMARILLO MAINLINE IN
SECTION 2 OF THE T.T.R.R. CO. SURVEY,
MOORE COUNTY, TEXAS.

SECONDARY RECEIPT POINT/S

All secondary receipt points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

RECEIPT PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

Natural gas to be delivered to Natural at the Receipt Point/s shall be at a delivery pressure sufficient to enter Natural's pipeline facilities at the pressure maintained from time to time, but Shipper shall not deliver gas at a pressure in excess of the Maximum Allowable Operating Pressure (MAOP) stated for each Receipt Point. The measuring party shall use or cause to be used an assumed atmospheric pressure corresponding to the elevation at such Receipt Point/s.

RATES

Except as otherwise provided below or in any written agreement(s) between the parties in effect during the term hereof, Shipper shall pay Natural the applicable maximum rate(s) and all other lawful charges as specified in Natural's applicable rate schedule. Shipper and Natural may agree that Shipper shall pay a rate other than the applicable maximum rate so long as such rate is between the applicable maximum and minimum rates specified for such service in the Tariff. Natural and Shipper may agree that a specific discounted rate will apply only to certain volumes under the agreement. The parties may agree that a specified discounted rate will apply only to specified volumes (MDQ or commodity volumes) under the agreement; that a specified discounted rate will apply only if specified volumes are achieved or only if the volumes do not exceed a specified level; that a specified discounted rate will apply only during specified periods of the year or for a specifically defined period; that a specified discounted rate will apply only to specified points, zones, mainline segments, supply areas, transportation paths, markets or other defined geographical area(s); that a specified discounted rate(s) will apply in a specified relationship to the volumes actually transported (i.e., that the reservation charge will be adjusted in a specified relationship to volumes actually transported); and/or that the discount will apply only to reserves dedicated by Shipper to Natural's system. Notwithstanding the foregoing, no discount agreement may provide that an agreed discount as to a certain volume level will be invalidated if the Shipper transports an incremental volume above that agreed level. In addition, the discount agreement may include a provision that if one rate component which was at or below the applicable maximum rate at the time the discount agreement was executed subsequently exceeds the applicable maximum rate due to a change in Natural's maximum rates so that such rate component must be adjusted downward to equal the new applicable maximum rate, then other rate components may be adjusted upward to achieve the agreed overall rate, so long as none of the resulting rate components exceed the maximum rate applicable to that rate component. Such changes to rate components shall be applied prospectively, commencing with the date a Commission order accepts revised tariff sheets. However, nothing contained herein shall be construed to alter a refund obligation under applicable law for any period during which rates which had been charged under a discount agreement exceeded rates which ultimately are found to be just and reasonable. If the parties agree upon a rate other than the applicable maximum rate, such written Agreement shall specify that the parties mutually agree either: (1) that the agreed rate is a discount rate; or (2) that the agreed rate is a Negotiated Rate (or Negotiated Rate Formula). In the event that the parties agree upon a Negotiated Rate or Negotiated Rate Formula, this Agreement shall be subject to Section 49 of the General Terms and Conditions of Natural's Tariff. Shipper and Natural may agree that Shipper shall pay a rate other than the applicable maximum rate so long as such rate is between the applicable maximum and minimum rates specified for such service in the Tariff.

FUEL GAS AND GAS LOST AND UNACCOUNTED FOR PERCENTAGE (%)

Shipper will be assessed the applicable percentage for Fuel Gas and Gas Lost and Unaccounted For.

TRANSPORTATION OF LIQUIDS

Transportation of liquids may occur at permitted points identified in Natural's current Catalog of Receipt and Delivery Points, but only if the parties execute a separate liquids agreement.

EXHIBIT C
DATED February 18, 2004
EFFECTIVE DATE: May 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 113418

Pursuant to Natural's tariff, an MDQ exists for each primary transportation path segment and direction under the Agreement. Such MDQ is the maximum daily quantity of gas which Natural is obligated to transport on a firm basis along a primary transportation path segment.

A primary transportation path segment is the path between a primary receipt, delivery, or node point and the next primary receipt, delivery, or node point. A node point is the point of interconnection between two or more of Natural's pipeline facilities.

A segment is a section of Natural's pipeline system designated by a segment number whereby the Shipper under the terms of their agreement based on the points within the segment identified on Exhibit C have throughput capacity rights.

The segment numbers listed on Exhibit C reflect this Agreement's path corresponding to Natural's most recent Pipeline System Map which identifies segments and their corresponding numbers. All information provided in this Exhibit C is subject to the actual terms and conditions of Natural's Tariff.

EXHIBIT C
DATED February 18, 2004
EFFECTIVE DATE: May 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 113418

	Segment	Upstream	Forward/Backward	Flow Through
	Number	Segment	Haul (Contractual)	Capacity

5/1/2004 - 7/31/2004
1.	10	0	F	0
2.	11	10	F	37200
3.	12	11	F	37200
4.	13	12	F	105071
5.	14	13	F	105071
6.	29	14	F	50000
7.	30	14	F	55071
8.	37	29	F	50000
9.	39	37	F	50000

8/1/2004 - 10/31/2004
10.	10	0	F	0
11.	11	10	F	49600
12.	12	11	F	49600
13.	13	12	F	105071
14.	14	13	F	105071
15.	29	14	F	50000
16.	30	14	F	55071
17.	37	29	F	50000
18.	39	37	F	50000

11/1/2004 - 4/30/2005
19.	10	0	F	0
20.	11	10	F	105071
21.	12	11	F	105071
22.	13	12	F	105071
23.	14	13	F	105071
24.	29	14	F	50000
25.	30	14	F	55071
26.	37	29	F	50000
27.	39	37	F	50000

EXHIBIT 10(c)

Contract No. 130626

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
TRANSPORTATION RATE SCHEDULE FTS AGREEMENT DATED February 18, 2004
UNDER SUBPART G OF PART 284 OF THE FERC'S REGULATIONS

1. SHIPPER is: THE PEOPLES GAS LIGHT AND COKE COMPANY, a LDC.

2.	(a)	MDQ totals:	50,000	Dth per day for the period April 1, 2004 to October 31, 2004
			0	Dth per day for the period November 1, 2004 to March 31, 2005
			50,000	Dth per day for the period April 1, 2005 to October 31, 2005
			0	Dth per day for the period November 1, 2005 to March 31, 2006
			50,000	Dth per day for the period April 1, 2006 to October 31, 2006

	(b)	Service option selected (check any or all):
			[ ] LN	[ ] SW	[ ] NB

3. TERM: April 1, 2004 through October 31, 2006.

4. Service will be ON BEHALF OF: [X] Shipper or [ ] Other:

5. The ULTIMATE END USERS are customers within any state in the continental U.S.; or (specify state): _______________________________________________

6. [ ] This Agreement supersedes and cancels a ___________ Agreement dated ________________.

[X] Service and reservation charges commence the latter of:

(a) April 1, 2004, and
(b) the date capacity to provide the service hereunder is available on Natural's System.

[ ] Other:

7.	SHIPPER'S ADDRESSES	NATURAL'S ADDRESSES
	General Correspondence:
	THE PEOPLES GAS LIGHT AND COKE COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	TOM ZACK	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVENUE	ONE ALLEN CENTER, SUITE 1000
	SUITE 3900	500 DALLAS STREET
	CHICAGO, IL 60601	HOUSTON, TEXAS 77002

	Statements/Invoices/Accounting Related Materials:
	THE PEOPLES GAS LIGHT AND COKE COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	GAS ACCOUNTING DEPARTMENT	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVENUE	ONE ALLEN CENTER, SUITE 1000
	SUITE 3900	500 DALLAS STREET
	CHICAGO, IL 60601	HOUSTON, TEXAS 77002

	Payments:
		NATURAL GAS PIPELINE COMPANY OF AMERICA
		P. O. BOX 70605
		CHICAGO, ILLINOIS 60673-0605

		FOR WIRE TRANSFER OR ACH:
		DEPOSITORY INSTITUTION: THE CHASE
		MANHATTAN BANK, NEW YORK, NY
		WIRE ROUTING #: 021000021
		ACCOUNT #: 323-206042

8. The above stated Rate Schedule, as revised from time to time, controls this Agreement and is incorporated herein. The attached Exhibits A, B, and C are part of this Agreement. NATURAL AND SHIPPER ACKNOWLEDGE THAT THIS AGREEMENT IS SUBJECT TO THE PROVISIONS OF NATURAL'S FERC GAS TARIFF AND APPLICABLE FEDERAL LAW. TO THE EXTENT THAT STATE LAW IS APPLICABLE, NATURAL AND SHIPPER EXPRESSLY AGREE THAT THE LAWS OF THE STATE OF TEXAS SHALL GOVERN THE VALIDITY, CONSTRUCTION, INTERPRETATION AND EFFECT OF THIS CONTRACT, EXCLUDING, HOWEVER, ANY CONFLICT OF LAWS RULE WHICH WOULD APPLY THE LAW OF ANOTHER STATE. This Agreement states the entire agreement between the parties and no waiver, representation, or agreement shall affect this Agreement unless it is in writing. Shipper shall provide the actual end user purchasers names(s) to Natural if Natural must provide them to the FERC.

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		THE PEOPLES GAS LIGHT AND COKE COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

Contract No. 130626

EXHIBIT A
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130626

RECEIPT POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY RECEIPT POINT/S

4/1/2004 - 10/31/2004
1. KMTP/NGPL KATY TAP HARRIS	HARRIS	TX	905231	04	6500
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN SEC. 2, J.C. OGBURN SURVEY, A-616,
HARRIS COUNTY, TEXAS.

2. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	43500
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

11/1/2004 - 3/31/2005
3. KMTP/NGPL KATY TAP HARRIS	HARRIS	TX	905231	04	0
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN SEC. 2, J.C. OGBURN SURVEY, A-616,
HARRIS COUNTY, TEXAS.

4. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	0
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

4/1/2005 - 10/31/2005
5. KMTP/NGPL KATY TAP HARRIS	HARRIS	TX	905231	04	6500
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN SEC. 2, J.C. OGBURN SURVEY, A-616,
HARRIS COUNTY, TEXAS.

6. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	43500
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

11/1/2005 - 3/31/2006
7. KMTP/NGPL KATY TAP HARRIS	HARRIS	TX	905231	04	0
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN SEC. 2, J.C. OGBURN SURVEY, A-616,
HARRIS COUNTY, TEXAS.

8. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	0
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

4/1/2006 - 10/31/2006
9. KMTP/NGPL KATY TAP HARRIS	HARRIS	TX	905231	04	6500
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN SEC. 2, J.C. OGBURN SURVEY, A-616,
HARRIS COUNTY, TEXAS.

10. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	43500
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

SECONDARY RECEIPT POINT/S

All secondary receipt points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

RECEIPT PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

RATES

maximum rate at the time the discount agreement was executed subsequently exceeds the applicable maximum rate due to a change in Natural's maximum rates so that such rate component must be adjusted downward to equal the new applicable maximum rate, then other rate components may be adjusted upward to achieve the agreed overall rate, so long as none of the resulting rate components exceed the maximum rate applicable to that rate component. Such changes to rate components shall be applied prospectively, commencing with the date a Commission order accepts revised tariff sheets. However, nothing contained herein shall be construed to alter a refund obligation under applicable law for any period during which rates which had been charged under a discount agreement exceeded rates which ultimately are found to be just and reasonable. If the parties agree upon a rate other than the applicable maximum rate, such written Agreement shall specify that the parties mutually agree either: (1) that the agreed rate is a discount rate; or (2) that the agreed rate is a Negotiated Rate (or Negotiated Rate Formula). In the event that the parties agree upon a Negotiated Rate or Negotiated Rate Formula, this Agreement shall be subject to Section 49 of the General Terms and Conditions of Natural's Tariff. Shipper and Natural may agree that Shipper shall pay a rate other than the applicable maximum rate so long as such rate is between the applicable maximum and minimum rates specified for such service in the Tariff.

FUEL GAS AND GAS LOST AND UNACCOUNTED FOR PERCENTAGE (%)

Shipper will be assessed the applicable percentage for Fuel Gas and Gas Lost and Unaccounted For.

TRANSPORTATION OF LIQUIDS

Transportation of liquids may occur at permitted points identified in Natural's current Catalog of Receipt and Delivery Points, but only if the parties execute a separate liquids agreement.

EXHIBIT B
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130626

DELIVERY POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

4/1/2004 - 10/31/2004
1. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	50000
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN OR NEAR THE AUGUSTINE VIESCA SURVEY,
A-77, POLK COUNTY, TEXAS.

11/1/2004 - 3/31/2005
2. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	0
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN OR NEAR THE AUGUSTINE VIESCA SURVEY,
A-77, POLK COUNTY, TEXAS.

04/1/2005 - 10/31/2005
3. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	50000
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN OR NEAR THE AUGUSTINE VIESCA SURVEY,
A-77, POLK COUNTY, TEXAS.

11/1/2005 - 3/31/2006
4. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	0
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN OR NEAR THE AUGUSTINE VIESCA SURVEY,
A-77, POLK COUNTY, TEXAS.

04/1/2006 - 10/31/2006
5. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	50000
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN OR NEAR THE AUGUSTINE VIESCA SURVEY,
A-77, POLK COUNTY, TEXAS.

SECONDARY DELIVERY POINT/S

All secondary delivery points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

DELIVERY PRESSURE. ASSUMED ATMOSPHERIC PRESSURE

Natural gas to be delivered by Natural to Shipper, or for Shipper's account, at the Delivery Point(s) shall be at the pressures available in Natural's pipeline facilities from time to time; provided, however, that the delivery pressure shall not be less than na . The measuring party shall use or cause to be used an assumed atmospheric pressure corresponding to the elevation at such Delivery Point(s).

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130626

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130626

	Segment	Upstream	Forward/Backward	Flow Through
	Number	Segment	Haul (Contractual)	Capacity

4/1/2004 - 10/31/2004
1.	22	0	F	0
2.	26	22	F	50000

4/1/2005 - 10/31/2005
3.	22	0	F	0
4.	26	22	F	50000
4/1/2006 - 10/31/2006
5.	22	0	F	0
6.	26	22	F	50000

EXHIBIT 10(d)

Contract No. 130628

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
TRANSPORTATION RATE SCHEDULE FTS AGREEMENT DATED February 18, 2004
UNDER SUBPART G OF PART 284 OF THE FERC'S REGULATIONS

1. SHIPPER is: THE PEOPLES GAS LIGHT AND COKE COMPANY, a LDC.

2.	(a)	MDQ totals:	50,000	Dth per day for the period April 1, 2004 to October 31, 2004
			0	Dth per day for the period November 1, 2004 to March 31, 2005
			50,000	Dth per day for the period April 1, 2005 to October 31, 2005
			0	Dth per day for the period November 1, 2005 to March 31, 2006
			50,000	Dth per day for the period April 1, 2006 to October 31, 2006

	(b)	Service option selected (check any or all):
			[ ] LN	[ ] SW	[X] NB

3. TERM: April 1, 2004 through October 31, 2006.

4. Service will be ON BEHALF OF: [X] Shipper or [ ] Other:

5. The ULTIMATE END USERS are customers within any state in the continental U.S.; or (specify state): _______________________________________________

6. [ ] This Agreement supersedes and cancels a ___________ Agreement dated ________________.

[X] Service and reservation charges commence the latter of:

(a) April 1, 2004, and
(b) the date capacity to provide the service hereunder is available on Natural's System.

[ ] Other:

7.	SHIPPER'S ADDRESSES	NATURAL'S ADDRESSES
	General Correspondence:
	THE PEOPLES GAS LIGHT AND COKE COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	TOM ZACK	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVENUE	ONE ALLEN CENTER, SUITE 1000
	SUITE 3900	500 DALLAS STREET
	CHICAGO, IL 60601	HOUSTON, TEXAS 77002

	Statements/Invoices/Accounting Related Materials:
	THE PEOPLES GAS LIGHT AND COKE COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	GAS ACCOUNTING DEPARTMENT	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVENUE	ONE ALLEN CENTER, SUITE 1000
	SUITE 3900	500 DALLAS STREET
	CHICAGO, IL 60601	HOUSTON, TEXAS 77002

	Payments:
		NATURAL GAS PIPELINE COMPANY OF AMERICA
		P. O. BOX 70605
		CHICAGO, ILLINOIS 60673-0605

		FOR WIRE TRANSFER OR ACH:
		DEPOSITORY INSTITUTION: THE CHASE
		MANHATTAN BANK, NEW YORK, NY
		WIRE ROUTING #: 021000021
		ACCOUNT #: 323-206042

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		THE PEOPLES GAS LIGHT AND COKE COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

Contract No. 130628

EXHIBIT A
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130628

RECEIPT POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY RECEIPT POINT/S

4/1/2004 - 10/31/2004
1. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	50000
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

11/1/2004 - 3/31/2005
2. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	0
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

4/1/2005 - 10/31/2005
3. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	50000
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

11/1/2005 - 3/31/2006
4. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	0
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

4/1/2006 - 10/31/2006
5. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	50000
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

SECONDARY RECEIPT POINT/S

All secondary receipt points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

RECEIPT PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

RATES

FUEL GAS AND GAS LOST AND UNACCOUNTED FOR PERCENTAGE (%)

Shipper will be assessed the applicable percentage for Fuel Gas and Gas Lost and Unaccounted For.

TRANSPORTATION OF LIQUIDS

Transportation of liquids may occur at permitted points identified in Natural's current Catalog of Receipt and Delivery Points, but only if the parties execute a separate liquids agreement.

EXHIBIT B
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130628

DELIVERY POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

4/1/2004 - 10/31/2004
1. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	50000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2004 - 3/31/2005
2. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2005 - 10/31/2005
3. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	50000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2005 - 3/31/2006
4. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2006 - 10/31/2006
5. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	50000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

SECONDARY DELIVERY POINT/S

All secondary delivery points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

DELIVERY PRESSURE. ASSUMED ATMOSPHERIC PRESSURE

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130628

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130628

	Segment	Upstream	Forward/Backward	Flow Through
	Number	Segment	Haul (Contractual)	Capacity

4/1/2004 - 10/31/2004
1.	23	24	B	50000
2.	24	0	B	0
3.	25	23	B	50000
4.	26	25	F	50000
5.	27	26	F	50000
6.	28	27	F	50000
7.	30	28	F	50000

4/1/2005 - 10/31/2005
8.	23	24	B	50000
9.	24	0	B	0
10.	25	23	B	50000
11.	26	25	F	50000
12.	27	26	F	50000
13.	28	27	F	50000
14.	30	28	F	50000

4/1/2006 - 10/31/2006
15.	23	24	B	50000
16.	24	0	B	0
17.	25	23	B	50000
18.	26	25	F	50000
19.	27	26	F	50000
20.	28	27	F	50000
21.	30	28	F	50000

EXHIBIT D - (NB Service Option)
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: THE PEOPLES GAS LIGHT AND COKE COMPANY
CONTRACT: 130628

FTS-NB DELIVERY POINT/S

					NB
					Service
	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

4/1/2004 - 10/31/2004
1. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	50000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2004 - 3/31/2005
2. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2005 - 10/31/2005
3. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	50000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2005 - 3/31/2006
4. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2006 - 10/31/2006
5. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	50000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

NGPL STORAGE AGREEMENTS DEDICATED TO FTS-NB SERVICE:

113417

EXHIBIT 10(e)

Contract No. 117164

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
STORAGE RATE SCHEDULE DSS
AMENDMENT NO.4 DATED February 17, 2004
TO AGREEMENT DATED March 9, 2000 (Agreement)

1.	[X] Exhibit A dated February 17, 2004. Changes Primary Delivery Point(s) and Point MDQ's. This Exhibit A replaces any previously dated Exhibit A.

2.	(a) [X] Revise Agreement MDQ: [X] Increase [ ] Decrease In Section 2. of Agreement substitute 45,000 Dth for 35,000 Dth.

	(b) [ ] Revise Agreement MSV: [ ] Increase [ ] Decrease In Section 2. of Agreement substitute ________ Dth for ________ Dth.

3.	[ ] The term of this Agreement is extended through ____________________________.

4.	[ ] Other: _________________________________________.

This Amendment No.4 becomes effective May 1, 2004.

Except as hereinabove amended, the Agreement shall remain in full force and effect as written.

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		NORTH SHORE GAS COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

EXHIBIT A
DATED: February 17, 2004
EFFECTIVE DATE: May 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 117164

DELIVERY POINT/S

	County/Parish		PIN		MDQ
Name I Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

5/1/2004 - 4/30/2007
1. NO SHORE/NGPL GRAYSLAKE LAKE	LAKE	IL	900001	09	10000
INTERCONNECT WITH NORTH SHORE GAS COMPANY
LOCATED IN SEC.12-T44N-R10E, LAKE COUNTY, ILLINOIS.

2. NO SHORE/NGPL TONNE RD COOK	COOK	IL	7866	09	35000
INTERCONNECT WITH NORTH SHORE GAS COMPANY
ON TRANSPORTER'S HOWARD STREET LINE IN
SEC. 27-T41N-R11E, COOK COUNTY, ILLINOIS.

RATES

Except as otherwise provided below or in any written agreement(s) between the parties in effect during the term hereof, Shipper shall pay Natural the applicable maximum rate(s) and all other lawful charges as specified in Natural's applicable rate schedule. Shipper and Natural may agree that Shipper shall pay a rate other than the applicable maximum rate so long as such rate is between the applicable maximum and minimum rates specified for such service in the Tariff. Natural and Shipper may agree that a specific discounted rate will apply only to certain volumes under the agreement. The parties may agree that a specified discounted rate will apply only to specified volumes (MDQ, WQ, IQ or commodity volumes) under the agreement; that a specified discounted rate will apply only if specified volumes are achieved or only if the volumes do not exceed a specified level; that a specified discounted rate will apply only during specified periods of the year or for a specifically defined period; that a specified discounted rate will apply only to specified points, zones, mainline segments, supply areas, transportation paths, markets or other defined geographical area(s); that a specified discounted rate(s) will apply in a specified relationship to the volumes actually tendered (i.e., that the reservation charge will be adjusted in a specified relationship to volumes actually tendered); and/or that the discount will apply only to reserves dedicated by Shipper to Natural's system. Notwithstanding the foregoing, no discount agreement may provide that an agreed discount as to a certain volume level will be invalidated if the Shipper transports an incremental volume above that agreed level. In addition, the discount agreement may include a provision that if one rate component which was at or below the applicable maximum rate at the time the discount agreement was executed subsequently exceeds the applicable maximum rate due to a change in Natural's maximum rates so that such rate component must be adjusted downward to equal the new applicable maximum rate, then other rate components may be adjusted upward to achieve the agreed overall rate, so long as none of the resulting rate components exceed the maximum rate applicable to that rate component. Such changes to rate components shall be applied prospectively, commencing with the date a Commission order accepts revised tariff sheets. However, nothing contained herein shall be construed to alter a refund obligation under applicable law for any period during which rates which had been charged under a discount agreement exceeded rates which ultimately are found to be just and reasonable. If the parties agree upon a rate other than the applicable maximum rate, such written Agreement shall specify that the parties mutually agree either: (1) that the agreed rate is a discount rate; or (2) that the agreed rate is a Negotiated Rate (or Negotiated Rate Formula). In the event that the parties agree upon a Negotiated Rate or Negotiated Rate Formula, this Agreement shall be subject to Section 49 of the General Terms and Conditions of Natural's Tariff.

DELIVERY PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

Natural gas to be delivered by Natural to Shipper, or for Shipper's account, at the Delivery Point/s shall be at the pressure available in Natural's pipeline facilities from time to time. The measuring party shall use or cause to be used an assumed atmospheric pressure corresponding to the elevation at such Delivery Point/s.

EXHIBIT 10(f)

Contract No. 117117

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
TRANSPORTATION RATE SCHEDULE FTS
AMENDMENT NO.2 DATED February 18, 2004
TO AGREEMENT DATED February 25, 2000 (Agreement)

1.	[ ] Exhibit A dated February 18, 2004. Changes Primary Receipt Point(s) and Point MDQ's. This Exhibit A replaces any previously dated Exhibit A.

2.	[ ] Exhibit B dated February 18, 2004. Changes Primary Delivery Point(s) and Point MDQ's. This Exhibit B replaces any previously dated Exhibit B.

3.	[X] Exhibits A and B dated February 18, 2004. Changes Primary Receipt and Delivery Points and Point MDQ's. These Exhibits A and B replace any previously dated Exhibits A and B.

4.	[X] Exhibit C dated February 18, 2004. Changes the Agreement's Path. This Exhibit C replaces any previously dated Exhibit C.

5.	[X] Revise Agreement MDQ: [X] Increase [ ] Decrease
	In Section 2. of Agreement substitute 9,000 Dth for 7,000 Dth.

6.	[ ] Revise Service Options

	Service option selected (check any or all):

	[ ] LN [ ] SW [ ] NB

7.	[ ] The term of this Agreement is extended through _____________________________.

8.	[ ] Other:

This Amendment No.2 becomes effective November 1, 2004.

Except as hereinabove amended, the Agreement shall remain in full force and effect as written.

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		NORTH SHORE GAS COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

EXHIBIT A
DATED: February 18, 2004
EFFECTIVE DATE: November 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 117117

RECEIPT POINT/S

	County/Parish		PIN		MDQ
Name I Location	Area	State	No.	Zone	(Dth)

PRIMARY RECEIPT POINT/S

11/1/2004 - 4/30/2007

1. ONEOKWES/NGPL WARD	WARD	TX	900962	01	2000
INTERCONNECT WITH WESTAR TRANSMISSION
COMPANY IN SEC. 93 OF H. T.C.R.R. CO.
SURVEY, BLOCK 34, WARD COUNTY, TEXAS.

2. AGAVE/NGPL SHOE BAR RCH LEA	LEA	NM	1759	01	7000
INTERCONNECT WITH AGAVE ENERGY COMPANY
ON TRANSPORTER'S SHOE BAR RANCH GATHERING
SYSTEM IN SEC. 21-T16S-R35E, LEA COUNTY, NEW MEXICO.

SECONDARY RECEIPT POINT/S

All secondary receipt points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

RECEIPT PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

RATES

period during which rates which had been charged under a discount agreement exceeded rates which ultimately are found to be just and reasonable. If the parties agree upon a rate other than the applicable maximum rate, such written Agreement shall specify that the parties mutually agree either: (1) that the agreed rate is a discount rate; or (2) that the agreed rate is a Negotiated Rate (or Negotiated Rate Formula). In the event that the parties agree upon a Negotiated Rate or Negotiated Rate Formula, this Agreement shall be subject to Section 49 of the General Terms and Conditions of Natural's Tariff. Shipper and Natural may agree that Shipper shall pay a rate other than the applicable maximum rate so long as such rate is between the applicable maximum and minimum rates specified for such service in the Tariff.

FUEL GAS AND GAS LOST AND UNACCOUNTED FOR PERCENTAGE (%)

Shipper will be assessed the applicable percentage for Fuel Gas and Gas Lost and Unaccounted For.

TRANSPORTATION OF LIQUIDS

Transportation of liquids may occur at permitted points identified in Natural's current Catalog of Receipt and Delivery Points, but only if the parties execute a separate liquids agreement.

EXHIBIT B
DATED February 18, 2004
EFFECTIVE DATE: November 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 117117

DELIVERY POINT/S

	County/Parish		PIN		MDQ
Name I Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

11/1/2004 - 4/30/2007
1. NO SHORE/NGPL GRAYSLAKE LAKE	LAKE	IL	900001	09	2000
INTERCONNECT WITH NORTH SHORE GAS COMPANY
LOCATED IN SEC. 12-T44N-R10E, LAKE COUNTY, ILLINOIS.

2. NO SHORE/NGPL TONNE RD COOK	COOK	IL	7866	09	7000
INTERCONNECT WITH NORTH SHORE GAS COMPANY
ON TRANSPORTER'S HOWARD STREET LINE IN
SEC. 27-T41N-R11E, COOK COUNTY, ILLINOIS.

SECONDARY DELIVERY POINT/S

All secondary delivery points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

DELIVERY PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

EXHIBIT C
DATED February 18, 2004
EFFECTIVE DATE: November 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 117117

EXHIBIT C
DATED February 18, 2004
EFFECTIVE DATE: November 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 117117

	Segment	Upstream	Forward/Backward	Flow Through
	Number	Segment	Haul (Contractual)	Capacity

11/1/2004 - 4/30/2007
1.	8	9	F	9000
2.	9	0	F	0
3.	10	8	F	9000
4.	11	10	F	9000
5.	12	11	F	9000
6.	13	12	F	9000
7.	14	13	F	9000
8.	29	14	F	2000
9.	30	14	F	7000
10.	37	29	F	2000
11.	39	37	F	2000

EXHIBIT 10(g)

Contract No. 113421

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
TRANSPORTATION RATE SCHEDULE FTS
AMENDMENT NO.3 DATED February 18, 2004
TO AGREEMENT DATED January 15, 1998 (Agreement)

1.	[X] Exhibit A dated February 18, 2004. Changes Primary Receipt Point(s) and Point MDQ's. This Exhibit A replaces any previously dated Exhibit A.

2.	[ ] Exhibit B dated February 18, 2004. Changes Primary Delivery Point(s) and Point MDQ's. This Exhibit B replaces any previously dated Exhibit B.

3.	[ ] Exhibits A and B dated February 18, 2004. Changes Primary Receipt and Delivery Points and Point MDQ's. These Exhibits A and B replace any previously dated Exhibits A and B.

4.	[X] Exhibit C dated February 18, 2004. Changes the Agreement's Path. This Exhibit C replaces any previously dated Exhibit C.

5.	[ ] Revise Agreement MDQ: [ ] Increase [ ] Decrease
	In Section 2. of Agreement substitute ____ Dth for ____ Dth.

6.	[ ] Revise Service Options

	Service option selected (check any or all):

	[ ] LN [ ] SW [ ] NB

7.	[ ] The term of this Agreement is extended through _____________________________.

8.	[ ] Other:

This Amendment No.3 becomes effective November 1, 2004.

Except as hereinabove amended, the Agreement shall remain in full force and effect as written.

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		NORTH SHORE GAS COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

EXHIBIT A
DATED: February 18, 2004
EFFECTIVE DATE: November 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 113421

RECEIPT POINT/S

	County/Parish		PIN		MDQ
Name I Location	Area	State	No.	Zone	(Dth)

PRIMARY RECEIPT POINT/S

11/1/2004 - 4/30/2005
1. ONEOKWES/NGPL WARD	WARD	TX	900962	01	8929
INTERCONNECT WITH WESTAR TRANSMISSION
COMPANY IN SEC. 93 OF H. T.C.R.R. CO.
SURVEY, BLOCK 34, WARD COUNTY, TEXAS.

SECONDARY RECEIPT POINT/S

All secondary receipt points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

RECEIPT PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

RATES

found to be just and reasonable. If the parties agree upon a rate other than the applicable maximum rate, such written Agreement shall specify that the parties mutually agree either: (1) that the agreed rate is a discount rate; or (2) that the agreed rate is a Negotiated Rate (or Negotiated Rate Formula). In the event that the parties agree upon a Negotiated Rate or Negotiated Rate Formula, this Agreement shall be subject to Section 49 of the General Terms and Conditions of Natural's Tariff. Shipper and Natural may agree that Shipper shall pay a rate other than the applicable maximum rate so long as such rate is between the applicable maximum and minimum rates specified for such service in the Tariff.

FUEL GAS AND GAS LOST AND UNACCOUNTED FOR PERCENTAGE (%)

Shipper will be assessed the applicable percentage for Fuel Gas and Gas Lost and Unaccounted For.

TRANSPORTATION OF LIQUIDS

Transportation of liquids may occur at permitted points identified in Natural's current Catalog of Receipt and Delivery Points, but only if the parties execute a separate liquids agreement.

EXHIBIT C
DATED February 18, 2004
EFFECTIVE DATE: November 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 113421

EXHIBIT C
DATED February 18, 2004
EFFECTIVE DATE: November 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 113421

	Segment	Upstream	Forward/Backward	Flow Through
	Number	Segment	Haul (Contractual)	Capacity

11/1/2004 - 4/30/2005
1.	8	9	F	8929
2.	9	0	F	0
3.	10	8	F	8929
4.	11	10	F	8929
5.	12	11	F	8929
6.	13	12	F	8929
7.	14	13	F	8929
8.	29	14	F	8929
9.	37	29	F	8929
10.	39	37	F	8929

EXHIBIT 10(h)

Contract No. 130625

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
TRANSPORTATION RATE SCHEDULE FTS AGREEMENT DATED February 18, 2004
UNDER SUBPART G OF PART 284 OF THE FERC'S REGULATIONS

1.	SHIPPER is: NORTH SHORE GAS COMPANY, a LDC.

2.	(a)	MDQ totals:	9,000	Dth per day for the period April 1, 2004 to October 31, 2004
			0	Dth per day for the period November 1, 2004 to March 31, 2005
			9,000	Dth per day for the period April 1, 2005 to October 31, 2005
			0	Dth per day for the period November 1,2005 to March 31, 2006
			9,000	Dth per day for the period April 1, 2006 to October 31, 2006

	(b)	Service option selected (check any or all):
		[ ] LN [ ] SW [X] NB

3.	TERM: April 1, 2004 through October 31, 2006.

4.	Service will be ON BEHALF OF: [X] Shipper or [ ] Other:

5.	The ULTIMATE END USERS are customers within any state in the continental U.S.; or (specify state): ___________________________________.

6.	[ ] This Agreement supersedes and cancels a ____________ Agreement dated ______________.

	[X] Service and reservation charges commence the latter of:
		(a) April 1, 2004, and
		(b) the date capacity to provide the service hereunder is available on Natural's System.

	[ ] Other:

7.	SHIPPER'S ADDRESSES	NATURAL'S ADDRESSES
	General Correspondence:
	NORTH SHORE GAS COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	TOM ZACK	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVE.	ONE ALLEN CENTER, SUITE 1000
	39 ^TH FLOOR	500 DALLAS STREET
	CHICAGO, IL 60601-6207	HOUSTON, TEXAS 77002

	Statements/Invoices/Accounting Related Materials:
	NORTH SHORE GAS COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	GAS ACCOUNTING DEPARTMENT	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVE.	ONE ALLEN CENTER, SUITE 1000
	39 ^TH FLOOR	500 DALLAS STREET
	CHICAGO, IL 60601-6207	HOUSTON, TEXAS 77002

	Payments:
		NATURAL GAS PIPELINE COMPANY OF AMERICA
		P. O. BOX 70605
		CHICAGO, ILLINOIS 60673-0605

		FOR WIRE TRANSFER OR ACH:
		DEPOSITORY INSTITUTION: THE CHASE
		MANHATTAN BANK, NEW YORK, NY
		WIRE ROUTING #: 021000021
		ACCOUNT #: 323-206042

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		NORTH SHORE GAS COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

Contract No. 130625

EXHIBIT A
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130625

RECEIPT POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY RECEIPT POINT/S

4/1/2004 - 10/31/2004
1. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	9000
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

11/1/2004 - 3/31/2005
2. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	0
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

4/1/2005 - 10/31/2005
3. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	9000
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

11/1/2005 - 3/31/2006
4. SABINEPl/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	0
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

4/1/2006 - 10/31/2006
5. SABINEPL/NGPL HENRY PLT VERMILION	VERMILION	LA	3592	05	9000
INTERCONNECT WITH SABINE PIPELINE COMPANY'S
GAS PLANT ON TRANSPORTER'S LOUISIANA MAINLINE
IN SEC. 21-T13S-R4E, VERMILION PARISH, LOUISIANA.

SECONDARY RECEIPT POINT/S

All secondary receipt points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

RECEIPT PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

RATES

FUEL GAS AND GAS LOST AND UNACCOUNTED FOR PERCENTAGE (%)

Shipper will be assessed the applicable percentage for Fuel Gas and Gas Lost and Unaccounted For.

TRANSPORTATION OF LIQUIDS

Transportation of liquids may occur at permitted points identified in Natural's current Catalog of Receipt and Delivery Points, but only if the parties execute a separate liquids agreement.

EXHIBIT B
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130625

DELIVERY POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

4/1/2004 - 10/31/2004
1. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	9000
INTERCONNECT WITH THE PEOPLES GAS LIGHT
AND COKE COMPANY ON TRANSPORTER'S HOWARD
STREET LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2004 - 3/31/2005
2. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT
AND COKE COMPANY ON TRANSPORTER'S HOWARD
STREET LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2005 - 10/31/2005
3. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	9000
INTERCONNECT WITH THE PEOPLES GAS LIGHT
AND COKE COMPANY ON TRANSPORTER'S HOWARD
STREET LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2005 - 3/31/2006
4. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT
AND COKE COMPANY ON TRANSPORTER'S HOWARD
STREET LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2006 - 10/31/2006
5. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	9000
INTERCONNECT WITH THE PEOPLES GAS LIGHT
AND COKE COMPANY ON TRANSPORTER'S HOWARD
STREET LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

SECONDARY DELIVERY POINT/S

All secondary delivery points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

DELIVERY PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130625

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130625

	Segment	Upstream	Forward/Backward	Flow Through
	Number	Segment	Haul (Contractual)	Capacity

4/1/2004 - 10/31/2004
1.	23	24	B	9000
2.	24	0	B	0
3.	25	23	B	9000
4.	26	25	F	9000
5.	27	26	F	9000
6.	28	27	F	9000
7.	30	28	F	9000

4/1/2005 - 10/31/2005
8.	23	24	B	9000
9.	24	0	B	0
10.	25	23	B	9000
11.	26	25	F	9000
12.	27	26	F	9000
13.	28	27	F	9000
14.	30	28	F	9000

4/1/2006 - 10/31/2006
15.	23	24	B	9000
16.	24	0	B	0
17.	25	23	B	9000
18.	26	25	F	9000
19.	27	26	F	9000
20.	28	27	F	9000
21.	30	28	F	9000

EXHIBIT D - (NB Service Option)
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130625

FTS-NB DELIVERY POINT/S

					NB
					Service
	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

4/1/2004 - 10/31/2004
1. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	9000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2004 - 3/31/2005
2. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2005 - 10/31/2005
3. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	9000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

11/1/2005 - 3/31/2006
4. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	0
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

4/1/2006 - 10/31/2006
5. PGLC/NGPL OAKTON STREET COOK	COOK	IL	904174	09	9000
INTERCONNECT WITH THE PEOPLES GAS LIGHT AND
COKE COMPANY ON TRANSPORTER'S HOWARD STREET
LINE IN SEC. 26-T41N-R13E, COOK COUNTY, ILLINOIS

NGPL STORAGE AGREEMENTS DEDICATED TO FTS-NB SERVICE:

113417

EXHIBIT 10(i)

Contract No. 130629

NATURAL GAS PIPELINE COMPANY OF AMERICA (Natural)
TRANSPORTATION RATE SCHEDULE FTS AGREEMENT DATED February 18, 2004
UNDER SUBPART G OF PART 284 OF THE FERC'S REGULATIONS

1.	SHIPPER is: NORTH SHORE GAS COMPANY, a LDC.

2.	(a)	MDQ totals:	9,000	Dth per day for the period April 1, 2004 to October 31, 2004
			0	Dth per day for the period November 1, 2004 to March 31, 2005
			9,000	Dth per day for the period April 1, 2005 to October 31, 2005
			0	Dth per day for the period November 1,2005 to March 31, 2006
			9,000	Dth per day for the period April 1, 2006 to October 31, 2006

	(b)	Service option selected (check any or all):
		[ ] LN [ ] SW [ ] NB

3.	TERM: April 1, 2004 through October 31, 2006.

4.	Service will be ON BEHALF OF: [X] Shipper or [ ] Other:

5.	The ULTIMATE END USERS are customers within any state in the continental U.S.; or (specify state): ___________________________________.

6.	[ ] This Agreement supersedes and cancels a ____________ Agreement dated ______________.

	[X] Service and reservation charges commence the latter of:
		(a) April 1, 2004, and
		(b) the date capacity to provide the service hereunder is available on Natural's System.

	[ ] Other:

7.	SHIPPER'S ADDRESSES	NATURAL'S ADDRESSES
	General Correspondence:
	NORTH SHORE GAS COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	TOM ZACK	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVE.	ONE ALLEN CENTER, SUITE 1000
	39 ^TH FLOOR	500 DALLAS STREET
	CHICAGO, IL 60601-6207	HOUSTON, TEXAS 77002

	Statements/Invoices/Accounting Related Materials:
	NORTH SHORE GAS COMPANY	NATURAL GAS PIPELINE COMPANY OF AMERICA
	GAS ACCOUNTING DEPARTMENT	ATTENTION: ACCOUNT SERVICES
	150 N. MICHIGAN AVE.	ONE ALLEN CENTER, SUITE 1000
	39 ^TH FLOOR	500 DALLAS STREET
	CHICAGO, IL 60601-6207	HOUSTON, TEXAS 77002

	Payments:
		NATURAL GAS PIPELINE COMPANY OF AMERICA
		P. O. BOX 70605
		CHICAGO, ILLINOIS 60673-0605

		FOR WIRE TRANSFER OR ACH:
		DEPOSITORY INSTITUTION: THE CHASE
		MANHATTAN BANK, NEW YORK, NY
		WIRE ROUTING #: 021000021
		ACCOUNT #: 323-206042

AGREED TO BY:

NATURAL GAS PIPELINE COMPANY OF AMERICA		NORTH SHORE GAS COMPANY
"Natural"		"Shipper"

By: /s/ David J. Devine		By: /s/ William E. Morrow

Name: David J. Devine		Name: William E. Morrow

Title: Vice President, Financial Planning		Title: Executive Vice President

Contract No. 130629

EXHIBIT A
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130629

RECEIPT POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY RECEIPT POINT/S

4/1/2004 - 10/31/2004
1. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	9000
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

11/1/2004 - 3/31/2005
2. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	0
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

4/1/2005 - 10/31/2005
3. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	9000
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

11/1/2005 - 3/31/2006
4. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	0
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

4/1/2006 - 10/31/2006
5. LONE STR/NGPL FORT BEND	FORT BEND	TX	10789	04	9000
INTERCONNECT WITH LONE STAR PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST
MAINLINE IN THE JASON CONNER SURVEY, A-157,
FORT BEND COUNTY, TEXAS

SECONDARY RECEIPT POINT/S

All secondary receipt points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

RECEIPT PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

RATES

FUEL GAS AND GAS LOST AND UNACCOUNTED FOR PERCENTAGE (%)

Shipper will be assessed the applicable percentage for Fuel Gas and Gas Lost and Unaccounted For.

TRANSPORTATION OF LIQUIDS

Transportation of liquids may occur at permitted points identified in Natural's current Catalog of Receipt and Delivery Points, but only if the parties execute a separate liquids agreement.

EXHIBIT B
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130625

DELIVERY POINT/S

	County/Parish		PIN		MDQ
Name/Location	Area	State	No.	Zone	(Dth)

PRIMARY DELIVERY POINT/S

4/1/2004 - 10/31/2004
1. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	9000
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST MAINLINE
IN OR NEAR THE AUGUSTINE VIESCA SURVEY, A-77,
POLK COUNTY, TEXAS.

11/1/2004 - 3/31/2005
2. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	0
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST MAINLINE
IN OR NEAR THE AUGUSTINE VIESCA SURVEY, A-77,
POLK COUNTY, TEXAS.

4/1/2005 - 10/31/2005
3. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	9000
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST MAINLINE
IN OR NEAR THE AUGUSTINE VIESCA SURVEY, A-77,
POLK COUNTY, TEXAS.

11/1/2005 - 3/31/2006
4. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	0
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST MAINLINE
IN OR NEAR THE AUGUSTINE VIESCA SURVEY, A-77,
POLK COUNTY, TEXAS.

4/1/2006 - 10/31/2006
5. KMTP/NGPL GOODRICH TAP POLK	POLK	TX	5579	03	9000
INTERCONNECT WITH MIDCON TEXAS PIPELINE
COMPANY ON TRANSPORTER'S GULF COAST MAINLINE
IN OR NEAR THE AUGUSTINE VIESCA SURVEY, A-77,
POLK COUNTY, TEXAS.

SECONDARY DELIVERY POINT/S

All secondary delivery points, and the related priorities and volumes, as provided under the Tariff provisions governing this Agreement.

DELIVERY PRESSURE, ASSUMED ATMOSPHERIC PRESSURE

Natural gas to be delivered by Natural to Shipper, or for Shipper's account, at the Delivery Point(s) shall be at the pressures available in Natural's pipeline facilities from time to time; provided, however, that the delivery pressure shall not be less na . The measuring party shall use or cause to be used an assumed atmospheric pressure corresponding to the elevation at such Delivery Point(s).

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1,2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130629

EXHIBIT C
DATED: February 18, 2004
EFFECTIVE DATE: April 1, 2004

COMPANY: NORTH SHORE GAS COMPANY
CONTRACT: 130629

	Segment	Upstream	Forward/Backward	Flow Through
	Number	Segment	Haul (Contractual)	Capacity

4/1/2004 - 10/31/2004
1.	22	0	F	0
2.	26	22	F	9000

4/1/2005 - 10/31/2005
3.	22	0	F	0
4.	26	22	F	9000

4/1/2006 - 10/31/2006
5.	22	0	F	0
6.	26	22	F	9000

Exhibit 12

Peoples Energy Corporation and Subsidiary Companies

Statement Re: Computation of Ratio of Earnings to Fixed Charges
(Dollars in Thousands)


	12 months ended	Fiscal years ended September 30,
	6/30/2004	2003	2002	2001	2000	1999

Net Income Before Preferred
Stock Dividends, as reported	$ 93,316	$103,934	$ 89,071	$ 96,939	$ 82,942	$ 89,316

Undistributed earnings from equity investees	(6,140)	4,740	12,216	(7,587)	(11,545)	(8,672)

Add - Income Taxes	44,212	59,182	46,321	51,372	41,195	50,525
Fixed charges excluding capitalized interest	48,485	49,441	56,439	72,051	52,919	39,546

Earnings	$ 179,873	$217,297	$ 204,047	$ 212,775	$ 165,511	$ 170,715

Fixed charges including capitalized interest	$ 48,485	$ 49,441	$ 56,439	$ 72,051	$ 53,741	$ 42,153

Ratio of Earnings to Fixed Charges	3.71	4.40	3.62	2.95	3.08	4.05

EXHIBIT 31(a)

I, Thomas M. Patrick, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Peoples Energy Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(c) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 10, 2004

/s/ Thomas M. Patrick
Thomas M. Patrick
Chairman of the Board, President
and Chief Executive Officer

EXHIBIT 31(a)

I, Thomas M. Patrick, certify that:

1. I have reviewed this quarterly report on Form 10-Q of The Peoples Gas Light and Coke Company;

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 10, 2004

/s/ Thomas M. Patrick
Thomas M. Patrick
Chairman of the Board
and Chief Executive Officer

EXHIBIT 31(a)

I, Thomas M. Patrick, certify that:

1. I have reviewed this quarterly report on Form 10-Q of North Shore Gas Company;

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 10, 2004

/s/ Thomas M. Patrick
Thomas M. Patrick
Chairman of the Board
and Chief Executive Officer

EXHIBIT 31(b)

I, Thomas A. Nardi, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Peoples Energy Corporation;

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 10, 2004

/s/ Thomas A. Nardi
Thomas A. Nardi
Senior Vice President
and Chief Financial Officer

EXHIBIT 31(b)

I, Thomas A. Nardi, certify that:

1. I have reviewed this quarterly report on Form 10-Q of The Peoples Gas Light and Coke Company;

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 10, 2004

/s/ Thomas A. Nardi
Thomas A. Nardi
Senior Vice President
and Chief Financial Officer

EXHIBIT 31(b)

I, Thomas A. Nardi, certify that:

1. I have reviewed this quarterly report on Form 10-Q of North Shore Gas Company;

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date: August 10, 2004

/s/ Thomas A. Nardi
Thomas A. Nardi
Senior Vice President
and Chief Financial Officer

Exhibit 32(a)

PEOPLES ENERGY CORPORATION AND CONSOLIDATED AFFILIATES

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002

In connection with the combined Quarterly Report of Peoples Energy Corporation (the "Company"), The Peoples Gas Light and Coke Company ("Peoples Gas") and North Shore Gas Company ("North Shore Gas") on Form 10-Q for the period ending June 30, 2004 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Thomas M. Patrick, Chairman of the Board, President and Chief Executive Officer of the Company and Chairman of the Board and Chief Executive Officer of Peoples Gas and North Shore Gas, certify, pursuant to 18 U.S.C. ss. 1350, as adopted pursuant to ss. 906 of the Sarbanes-Oxley Act of 2002, that:

The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company, Peoples Gas and North Shore Gas.

/s/ THOMAS M. PATRICK			August 10, 2004
			Date

Thomas M. Patrick
Chairman of the Board,
President and Chief Executive Officer of
Peoples Energy Corporation

/s/ THOMAS M. PATRICK			August 10, 2004
			Date

Thomas M. Patrick
Chairman of the Board and Chief Executive Officer of
The Peoples Gas Light and Coke Company

/s/ THOMAS M. PATRICK			August 10, 2004
			Date

Thomas M. Patrick
Chairman of the Board and Chief Executive Officer of
North Shore Gas Company

Exhibit 32(b)

PEOPLES ENERGY CORPORATION AND CONSOLIDATED AFFILIATES

CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002

In connection with the combined Quarterly Report of Peoples Energy Corporation (the "Company"), The Peoples Gas Light and Coke Company ("Peoples Gas") and North Shore Gas Company ("North Shore Gas") on Form 10-Q for the period ending June 30, 2004 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Thomas A. Nardi, Senior Vice President and Chief Financial Officer of the Company, Peoples Gas and North Shore Gas, certify, pursuant to 18 U.S.C. ss. 1350, as adopted pursuant to ss. 906 of the Sarbanes-Oxley Act of 2002, that:

The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company, Peoples Gas and North Shore Gas.

/s/ THOMAS A. NARDI			August 10, 2004
			Date

Thomas A. Nardi
Senior Vice President
and Chief Financial Officer of
Peoples Energy Corporation

/s/ THOMAS A. NARDI			August 10, 2004
			Date

Thomas A. Nardi
Senior Vice President
and Chief Financial Officer of
The Peoples Gas Light and Coke Company

/s/ THOMAS A. NARDI			August 10, 2004
			Date

Thomas A. Nardi
Senior Vice President
and Chief Financial Officer of
North Shore Gas Company