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1
Forward Looking Statements
The matters discussed or incorporated by reference in this presentation may contain “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included in this presentation are forward-looking statements made in good faith by the Company and are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995. When used in this presentation or in any of the Company’s other documents or oral presentations, the words “anticipate,” “believes,” “estimate,” “expect,” “forecast,” “goal,” “intends,” “objective,” “plans” “projection,” “seek,” “strategy” or similar words are intended to identify forward-looking statements. Such forward-looking statements are subject to risks and uncertainties that could cause actual results to differ materially from those discussed in this presentation, including the Company’s acquisition of the operations of TXU Gas, the Company’s ability to continue to access the capital markets and the other factors discussed in the Company’s SEC filings. These factors include the risks and uncertainties discussed in the Company’s Form 10-K for the fiscal year ended September 30, 2005. Although the Company believes these forward-looking statements to be reasonable, there can be no assurance that they will approximate actual experience or that the expectations derived from them will be realized. The Company undertakes no obligation to update or revise forward-looking statements, whether as a result of new information, future events or otherwise.
2
Management Participants
Robert W. Best - Chairman, President & CEO
J. Patrick Reddy - Senior VP & CFO
R. Earl Fischer - Senior VP, Utility Operations
JD Woodward - Senior VP, Nonutility Operations
Mark H. Johnson – VP, Nonutility Operations
Laurie M. Sherwood - VP, Corporate Development,and Treasurer
Susan C. Kappes - VP, Investor Relations
3
Atmos Energy Today
Robert W. BestChairman, President & CEO
4
Overview
Company Profile
The nation’s largest pure-gas distribution companySolid financial foundationTrack record of creating shareholder value• Consistent earnings growth• 22 consecutive years of increasing dividends
Focused strategy over time• Maximize core natural gas utility earnings capability• Complement core utility business through select
nonutility operations• Grow through prudent acquisitions
5
OverviewScope of Operations
• Utility operates in 12 states (yellow)• Nonutility operates in 22 states (grey)
6
3.16
2.30
2.00
1.68
0.99 0.96
0.63 0.600.46
0.31
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
ATO ATG OKE SWX WGL PNY LG NWN NJR SJI
Overview
Largest Pure-Play LDC Based on Customers
(customers in millions)
7
17.4%
15.8%16.4%
14.5%
15.5%15.9%
10.0%
12.0%
14.0%
16.0%
18.0%
2001 2002 2003 2004 2005 5 Yr Avg
Overview
Return on Invested Capital (ROIC*) Remains Strong
*ROIC - Return on invested capital is calculated using the following GAAP financial measures: Income before interest expense and income taxes plus common stock dividends paid, divided by the average of the year’s beginning and ending long-term debt plus common equity. This measure is used to more precisely evaluate operational performance and management effectiveness.
8
Overview
Times Interest Earned Ratios*
2.83
2.552.75
3.05
2.592.76
1.5
2.0
2.5
3.0
3.5
2001 2002 2003 2004 2005 2006E*The times interest earned ratio measures the ability to satisfy annual interest costs
9
Overview
Weighted Average Cost of Debt Remains Low
7.46.9
6.46.0
5.6 5.7
1.0
2.0
3.0
4.0
5.0
6.0
7.0
8.0
2001 2002 2003 2004 2005 2006E
Perc
ent
10
Overview
Total Return to Shareholders is Competitive
Five year total return 9/30/00 – 9/30/05
Source: Bloomberg
12.3%
17.2%
29.4%
38.7%
51.6%
0%
10%
20%
30%
40%
50%
60%
S&P 500
Atmos Energy
S&P 600 Gas Utils
S&P 500 Utils
Dow Jones Utils(7.2%)
(1.9%)
31.5%
75.5%
107.9%
-15%
10%
35%
60%
85%
110%
S&P 500
S&P 500 Utils
Dow Jones Utils
Atmos Energy
S&P 600 Gas Utils
One year total return 9/30/04 – 9/30/05
11
Earnings Per Share Compared to Company Guidance Reflects Management’s Commitment to Shareholders
1.721.58
1.451.54
$0.50
$0.75
$1.00
$1.25
$1.50
$1.75
$2.00
2002 2003 2004 2005 2006E
$ pe
r sha
reOverview
$1.43-$1.60$1.52-$1.58 $1.55-$1.60
$1.65-$1.75
$1.80-$1.90
12
Overview
$0.00
$0.20
$0.40
$0.60
$0.80
$1.00
$1.20
'84 '85 '86 '87 '88 '89 '90 '91 '92 '93 '94 '95 '96 '97 '98 '99 '00 '01 '02 '03 '04 '05 '06E
Annual Dividend for the Years 1984 – 2006E
Note: Amounts are adjusted for mergers and acquisitions. For fiscal 2006, $1.26 is the indicated annual dividend.
$1.26
13
Overview
Dividend Payout Continues to Improve
81%
78% 77%
72%
79%
68% E1.16 1.18 1.20 1.22
1.26E
1.24
60%
65%
70%
75%
80%
85%
2001 2002 2003 2004 2005 2006E$1.00
$1.10
$1.20
$1.30
$1.40
$1.50
Payout Dividend / Share
Current Indicated Dividend Yield Approximately 4.7%Average LDC Payout Ratio = 65%
14
Kentucky: 5.4%
Pipeline & Storage: 20.2%Mid-Tex: 24.5%
Colorado-Kansas: 7.2%
Marketing: 11.8%
West Texas: 8.0%
Mississippi: 5.5%
Mid-States: 10.3%
Louisiana: 7.1%
Overview
Diversified Operating Base – Geographically and Operationally
Fiscal 2005 Operating Income: $349 MM
Residential 39.4%
Commercial 22.5%
Transportation 27.9%
Irrigation 0.8%
Public Authority & Other 2.2%
Industrial 7.2%
Fiscal 2005 Utility Throughput by
Customer Type: 411 Bcf
15
Overview
Rate Design Issues
• Seek weather normalization in key jurisdictions• Shift more revenue from the commodity charge to base rates• Seek mechanism to mitigate declining use per customer• Recover the gas cost portion of bad debt expense
Regulatory Lag Issues
• Shift capital spending to jurisdictions with more timely recovery (short-term)
• Seek mechanisms in remaining jurisdictions to reduce regulatory lag on recovering capital expenditures (long-term)
• File rate cases to maintain actual returns close to allowed returns
Regulatory Strategy Remains Key Focus
16
18.6
16.2
6.3
15.0-25.0
$0.0
$5.0
$10.0
$15.0
$20.0
$25.0
2003 2004 2005 2006-2010E
($ in Millions)
Overview
Average Annual Rate Increases in the Utility Segment
17
Overview
Atmos Utility Gross Profit per Meter
271
293299
287
305-310
$240$250$260$270$280$290$300$310$320
2002 2003 2004 2005 2006E6%
warmer1%
colder4%
warmer11%
warmerAssumes
Normal Weather
$ pe
r met
er
18
$110
$209
$0
$50
$100
$150
$200
$250
Atmos Energy Peer Group Avg.
Note: Results are based on fiscal 2005 performance for Atmos and most recent information available for the peer group. Companies in the peer group include AGL Resources, KeySpan, Laclede, New Jersey Resources, Nisource, Northwest Natural Gas, Oneok, Piedmont Natural Gas, Southwest Gas and WGL Holdings.
Overview
Impressive Utility Efficiency Metrics vs. Peers
2005 Utility O&M Expense Per Customer
730
511
0
200
400
600
800
Atmos Energy Peer Group Avg.
Customers Served per Utility Employee
19
Gas MarketingUtilizes storage and transportation assets that are leased or managed to:
• provide bundled city gate services (including base load sales, peaking sales, risk management and demand based storage services), to municipal, industrial, power generator, LDC and affiliate utility customers and
• capture time and location price differentials (arbitrage) through various trading strategies
Pipeline & StorageOwns or leases storage and pipeline assets in Texas, Kentucky and Louisiana that are utilized to provide storage and transportation services to municipal, industrial, power generator and affiliate utility customers
Includes recently acquired pipeline and storage assets from TXU Gas (6,162 miles of intrastate pipelines and 5 storage facilities). Effective 10/1/04, these pipeline operations are functionally reporting under the nonutility businesses
Other NonutilityProvides gas supply services to Atmos utility divisions and peaking power construction services
Overview
Nonutility Business Segments Complement Atmos Energy
20
Overview
86%
6%
(1)%
9%
73%
5%
19%3%
60%
17%
23%
65%
14%
21%
-5%
15%
35%
55%
75%
95%
2003 2004 2005 2006E
Pipeline & StorageNatural Gas MarketingOther NonutilityUtility
Historical and Estimated Net Income Contribution by Segment
Perc
ent
21
1986 - Trans Louisiana Gas Company
1987 - Western Kentucky Gas Company
1993 - Greeley Gas Company
1997 - United Cities Gas Company
2000 - Associated Natural Gas Company (Missouri Assets)2000 - Acquired interest in Heritage Propane Partners
(sold in Fiscal 2004)
2001 - Acquisition of remaining interest in Woodward Marketing
2001 - Louisiana Gas Service and LGSN
2002 - Mississippi Valley Gas Company
2004 – TXU Gas Company
Successful Acquisition History
Overview
22
Cash price of $1.9 billion• 26 million common shares
issued @ $24.75• $1.4 billion senior unsecured
notes – initial weighted average interest rate of 4.76%
LDC Operations• Mid-Tex Division serves about
1.5 million customers, 92% residential
• Annual customer growth of 2%• Over 550 municipalities served
Pipeline Operations• Atmos Pipeline-Texas Division• 1,800 miles of backbone
intrastate pipeline• Integrated with LDC• Working storage capacity of
39 Bcf
Overview
West Texas Division
Mid-Tex Division
Atmos Pipeline-TexasAtmos Energy Headquarters
Acquisition of TXU Gas Provided Scale and Scope in Texas
23
17%83%
13% 19%
68%
2004 - $194 MM
69%
16%15%
2006E - $373 - $387 MM
Regulated LDCRegulated PipelineNon-Regulated
Growth Through Acquisitions
Increasing Regulated Operations – Operating Income Mix
2005 - $349 MM
24
YesMeeting Our Objectives -Could We:
In progress8. Continue to grow earnings in the 4-6% range?
In progress 7. Reduce debt as a percent of capital in 3-5 years?
In progress6. Achieve better rate design on these assets?
5. Take advantage of the pipeline opportunities?
4. Operate the new business more efficiently than the prior owner?
3. Integrate the new business within one year?
2. Fund the acquisition without pressuring the stock price or losing our investment grade credit ratings?
1. Close the TXU Gas acquisition in three months?
Overview
2005 Scorecard
25
86.2
135.8
$50.0
$100.0
$150.0
2004 2005
Fiscal 2005 Net Income and EPS Experienced Substantial Increases
Overview
Net Income ($ millions)
1.58
1.72
$1.00
$1.20
$1.40
$1.60
$1.80
2004 2005
Diluted Earnings Per Share
Net income reached a record level in 200524.6 million increase in weighted average outstanding shares year over year – primarilyto help fund the TXU Gas transaction
57%
9%
26
Financial Outlook
J. Patrick ReddySenior VP and Chief Financial Officer
27
Atmos Energy Holdings, Inc.(Nonutility Businesses)
Atmos Energy Holdings, Inc.(Nonutility Businesses)
KentuckyKentucky
Atmos Energy Corporation(Natural Gas Utility Divisions)
Atmos Energy Corporation(Natural Gas Utility Divisions)
West TexasWest Texas
Colorado-KansasColorado-Kansas
LouisianaLouisiana
Mid-StatesMid-States
Mid-Tex *Mid-Tex *
MississippiMississippi
Atmos Energy Marketing• Storage (Trading)• Transportation (Marketing)
Atmos Energy Marketing• Storage (Trading)• Transportation (Marketing)
Atmos Pipeline & Storage• Atmos Pipeline-Texas• Non-Texas Assets
Atmos Pipeline & Storage• Atmos Pipeline-Texas• Non-Texas Assets
Other Nonutility• Atmos Energy Services• Atmos Power Systems
Other Nonutility• Atmos Energy Services• Atmos Power Systems
* Effective 10/1/04, includes LDC and pipeline operations of former TXU Gas. Pipeline operations have functionally reported under the nonutility businesses beginning in Fiscal 2005.
Maximizing Core Utility Earnings
28
Favorable rate stabilization results in Mississippi effective 10/1/05• Establishes an earnings sharing mechanism• Provides calculated ROE plus performance adjuster, currently 9.8%• Shifts $10 million in annual margins from volumetric to customer charge• Adds about 4% more heating degree days to the WNA period• Reduces regulatory lag
Increased rates requested in Georgia• Filed for revenue increase of $4 million and rate design enhancements• Order was disappointing; currently reviewing options for “next steps”
Productive GRIP filings in the state of Texas• 2003 expenditure filings concluded; total of $8.5 million implemented in
Mid-Tex and Atmos Pipeline-Texas rates, with $6.7 million rate increase effective October 2005
• 2004 expenditure filings ongoing; expect approximately $12.5 million to be implemented in rates in first quarter of calendar 2006
o Results from Grip filings made on behalf of Mid-Tex and Atmos Pipeline-Texas Divisions, and West Texas and Lubbock jurisdictions
2005 Regulatory Activity Drives Top Line Revenue Stream for Fiscal 2006
Maximizing Core Utility Earnings
29
Earnings Grow Despite Warmer Weather
2,587
3,4733,368
4,124
$1.00
$1.15
$1.30
$1.45
$1.60
$1.75
$1.90
2001 2002 2003 2004 20052,000
2,500
3,000
3,500
4,000
EPS Degree Days*
$1.45$1.54
$1.58$1.72
* Adjusted for WNA
$1.47
Maximizing Core Utility Earnings
3,271
30
(25)
(20)
(15)
(10)
(5)
0MS CO / K
SMid-States
Kentucky
W. Texas
Louisiana
Mid-TexConsolidated
Actual / Normal Adjusted for WNA
Warmer Than Normal Weather is the Biggest Regulatory Challenge
22%
11%
20%
14%
% W
arm
er th
an N
orm
alMaximizing Core Utility Earnings
Fiscal 2005 Impact:
11 percent warmer than normal on a consolidated basis
Cost 29 cents per diluted share in fiscal 2005
Largest exposure is in Mid-Tex Division
31
36%51%
13%
2003–2004 Heating Season
Weather Normalized
Weather-Sensitive Margin
Nonweather-Sensitive Margin
48%35%
17%
2004–2006EHeating Seasons
Maximizing Core Utility Earnings
Utility Margin Sensitivity Increased with TXU Gas Acquisition
32($.16)
($.12)
($.09)
($.05)
($0.16)
($0.14)
($0.12)
($0.10)
($0.08)
($0.06)
($0.04)
($0.02)
$0.005% 10% 15% 20%
Mid-Tex Division Earnings Impact of Warmer Than Normal Weather
Percent Warmer than Normal
Maximizing Core Utility EarningsEP
S Im
pact
33
Ongoing discussions with the Louisiana Commission and staff for recovery of incremental O&M, lost gas and lost marginsTotal property damage and expenses estimated between $13 million and $15 million
• Property Related:o $10.6 million damage to distribution systemso $ 0.5 million damage to 3 buildings and equipment
• $ 1.8 million of lost gas (144,000 Mcf)• $ 1.5 million of incremental O&M related costs, included in fiscal 2005 results
Property Insurance Coverage• Self-insured for $1 million, included in fiscal 2005 results• Damage from $1.0 to $5.0 million - coverage with third-party provider• Damage greater than $5.0 million – coverage through OIL
Fiscal 2006 Guidance assumes lost margin between $10 million and $12 million
• Approximately 230,000 Louisiana customers affected by Hurricane Katrina • Estimate 40,000 customers semi-permanently lost (> 9 mos. to restore service,
if at all)We fully expect recovery for these losses. However, we are unsure of the timing and therefore, have conservatively assumed no recovery in our fiscal 2006 guidance.
Hurricane Katrina Rate Relief
Maximizing Core Utility Earnings
34
Maximizing Core Utility Earnings
Gas Supply Hedging for Winter 2005-2006
Market 54%
Storage 22%
Hedged 24%
53.7 Bcf
47.6 Bcf
116.8 Bcf
Hedging gas supply reduces effect of high gas prices
Customers pay a blended rate for gas
Provides some protection to Atmos’ customer receivables and working capital requirements
35
Nov-05Dec-05
Jan-06Feb-06
Mar-060.0
5.0
10.0
15.0
20.0
25.0
30.0
35.0
Nov-05Dec-05
Jan-06Feb-06
Mar-06
Storage
Futures
Fixed Forwards
$10.74 Weighted Average Cost of Futures and Fixed Forwards$ 7.17 Weighted Average Cost of Storage$ 9.11 Weighted Average Blended Cost of GasHedges Plus Storage = Approximately 46% of Winter Requirements
Bill
ion
Cub
ic F
eet
(Bcf
)Maximizing Core Utility EarningsGas Supply Hedging for Winter 2005-2006
36
1.86
0.0
0.83
0.29
0.58 0.64
0.0
0.5
1.0
1.5
2.0
2001 2002 2003 2004 2005 2006E
Perc
ent
Maximizing Core Utility Earnings
Utility Bad Debt Expense as a % of Revenues Well Below Industry Average
2006 estimated bad debt expense is $20 million
Reserve of $10 million was established as of September 30, 2005, with accruals throughout fiscal 2006
37
(in millions)
4.7
12.8
16.8
10.0
9.5
13.8
22.2
8.9
$0.0
$10.0
$20.0
$30.0
$40.0
$50.0
$60.0
2005 2006E
OtherMedical & DentalPost-retirementPension
$54.4
$44.3
2006 Assumptions8.50% return on plan assets5.00% discount rate4.00% wage increase
Managing Pension, Post-Retirement & Other Benefits Expense
Maximizing Core Utility Earnings
38
$0
$50
$100
$150
$200
$250
2001 2002 2003 2004 2005 2006E
Cap
ital E
xpen
ditu
res
$0
$50
$100
$150
$200
$250
Dep
reci
atio
n Ex
pens
e
Non-Growth Growth Depreciation
Maximizing Core Utility Earnings
Managing Capital Expenditures at the Utility($ in millions)
$90-94
$183-189
$174$52
39
Atmos Energy Holdings, Inc.(Nonutility Businesses)
Atmos Energy Holdings, Inc.(Nonutility Businesses)
KentuckyKentucky
Atmos Energy Corporation(Natural Gas Utility Divisions)
Atmos Energy Corporation(Natural Gas Utility Divisions)
West TexasWest Texas
Colorado-KansasColorado-Kansas
LouisianaLouisiana
Mid-StatesMid-States
Mid-Tex *Mid-Tex *
MississippiMississippi
Atmos Energy Marketing• Storage (Trading)• Transportation (Marketing)
Atmos Energy Marketing• Storage (Trading)• Transportation (Marketing)
Atmos Pipeline & Storage• Atmos Pipeline-Texas• Non-Texas Assets
Atmos Pipeline & Storage• Atmos Pipeline-Texas• Non-Texas Assets
Other Nonutility• Atmos Energy Services• Atmos Power Systems
Other Nonutility• Atmos Energy Services• Atmos Power Systems
* Effective 10/1/04, includes LDC and pipeline operations of former TXU Gas. Pipeline operations have functionally reported under the nonutility businesses beginning in Fiscal 2005.
Nonutility Operations
40
Storage Assets
• Optimize Value(trading to capture
time and location price differentials)
Transportation Assets• Support Customer Marketing
(optimize value of capacity)
Asset Management
• Customer obligation
• Partial optionality
Proprietary
• No customer obligation
• 100% optionality
Customer Sales• Base-load• Peaking• Balancing
The portfolio of assets that AEM manages is either acquired, leased or results from various asset management transactions with 3rd parties. Also, transportation and storage assets are contracted for (proprietary). These assets are utilized to capture value and create commercial opportunities.
Atmos Energy Marketing
Proprietary
• No customer obligation
• 100% optionality
Asset Management
• Customer obligation
• Partial optionality
Customer Sales• Full Requirements• Billable Plan• Other
Business Model
41
Cash Market to prompt (arbitrage opportunity)
Cash Market = $8.00 / dthPrompt futures = $8.40 / dth
AEM buys physical at $8.00 and injects in storageAEM sells prompt futures at $8.40 / dth
Spread captured $ 0.40 / dthLess: Injection & Storage fees (0.20) / dtUnit Margin $ 0.20 / dth
StorageCapture arbitrage spreads with storage
Cash market vs. prompt futures
Prompt futures vs. forward futures
Balance of month cash vs. prompt month futures
Transportation Capture arbitrage spreads on pipeline grid
Excess transport capacityPipeline segmentation
Transportation Capture arbitrage spreads on pipeline grid
Excess transport capacityPipeline segmentation
Example:
Trading Arbitrage Opportunities (Storage and Transportation)
Trading ParametersRun flat bookNo speculative trading
Atmos Energy Marketing
42
Margin Composition
Atmos Energy Marketing
Marketing
(Bundled gas deliveries &peaking sales)
Marketing
(Bundled gas deliveries &peaking sales)
Trading
(Storage & transportationmanagement)
Trading
(Storage & transportationmanagement)
Total AEMMarginsTotal AEMMargins
Impacted by customer volume demand Sales prices are:
• Cost plus profit margin• Cost plus demand charges
Margins: More predictable
Impacted by gas price spread values in the market (arbitrage opportunity)Physical storage capabilitiesAvailable storage and transport capacity Margins: More variable
Total margins reflect:Stability from marketing margins Upside from trading around storage and transportation assets to capture arbitrage value
Margins: Stable with potential upside
2006E
$40- $42 Million
$12 - $26 Million
$52 - $68 Million
=
43
Atmos Energy Holdings, Inc.(Nonutility Businesses)
Atmos Energy Holdings, Inc.(Nonutility Businesses)
KentuckyKentucky
Atmos Energy Corporation(Natural Gas Utility Divisions)
Atmos Energy Corporation(Natural Gas Utility Divisions)
West TexasWest Texas
Colorado-KansasColorado-Kansas
LouisianaLouisiana
Mid-StatesMid-States
Mid-Tex *Mid-Tex *
MississippiMississippi
Atmos Energy Marketing• Storage (Trading)• Transportation (Marketing)
Atmos Energy Marketing• Storage (Trading)• Transportation (Marketing)
Atmos Pipeline & Storage• Atmos Pipeline-Texas• Non-Texas Assets
Atmos Pipeline & Storage• Atmos Pipeline-Texas• Non-Texas Assets
Other Nonutility• Atmos Energy Services• Atmos Power Systems
Other Nonutility• Atmos Energy Services• Atmos Power Systems
* Effective 10/1/04, includes LDC and pipeline operations of former TXU Gas. Pipeline operations have functionally reported under the nonutility businesses beginning in Fiscal 2005.
Nonutility Operations
44
Atmos Pipeline & Storage
Storage AssetsEast Diamond Reservoir2.2 bcf of storage in KY
Barnsley Reservoir 1.3 Bcf of storage in KY
25 % interest in Napoleonville0.4 Bcf of Salt storage in LA
5 Storage Fields in Texas39 Bcf of storage
Atmos Pipeline & Storage
Pipeline AssetsAtmos Pipeline –Texas6,162 miles of intrastate pipein Texas
Trans LA Gas Pipeline21 miles of 24” pipe in Louisiana
Ownership of Strategic Asset Base Provides Revenue Growth & Stability
Upstream pipeline services and storage-type services provided to Atmos Energy’s Mid-Tex Division, affiliates & third parties
45
Asset Description
Pipeline transports and stores gas, as well as provides other pipeline services for distribution, industrial, electric generation, cross haul and other shippers
• Approximately 6,162 miles of intrastate pipelineo Total projected transportation volume is approximately 591 Bcf
o Current average volume of approximately 1.6 Bcf/d.
o Demonstrated peak day deliveries of 3.5 Bcf/d
• The Dallas / Fort Worth Metroplex comprises approximately 75% of on-system distribution demand
Five Storage facilities (One salt cavern; four depleted reservoirs)• Working Gas Capacity: 39 Bcf• Maximum withdrawal: 1.2 Bcf/d• Maximum Injection: 270 MMcf/d
Atmos Pipeline - Texas
46
$15.0 million----
$13.7 million$1.3 millionKaty Capacity
Expansion/ Compression
----------------Devon Line/
Corridor Compression
$13.0 million
---
$13.0 million
2005
GRIP Filings *
$6.9 million
$4.0 million
$1.6 million
Actual2005
CAPEX
$73.1 million
$16.0 million
$43.4 million
Estimated 2006
$67.0 million
$20.0 million
$32.0 million
2006 Northside Loop JV with Energy
Transfer
Total:
Enbridge Line/Corridor Compression
Project
Project Update
Estimated total annual revenues are $15.0 million; of which $6.7 million are expected to occur in fiscal 2006.* Capital expenditures on a calendar year basis are Included in GRIP filings when the asset is operational
Atmos Pipeline - Texas
47
Financial Outlook - Nonutility OperationsNet Income by Nonutility Segment
2006E$51 - $58 million
2005$55 million
AEM AP&S Other AEM AP&S Other
$19-$24
$31-$32
$1-$2
$23
$31
$1
48
Atmos Energy expects earnings to be in the range of $1.80 - $1.90 per fully diluted share for the 2006 fiscal year
Base assumptions include:• Normal weather conditions in non-WNA jurisdictions• Continued execution of rate strategy and collections efforts• Irrigation volumes of 4.0 Bcf• Not less than $11.7 million of storage margin contribution• No material acquisitions• Average short-term interest rate @ 4.5 %• Bad debt expense of no more than $20 million• Adverse impact of Hurricane Katrina on margin between $10
million and $12 million
Financial Outlook – Consolidated
Earnings Guidance – 2006 Fiscal Year
49
56334768
140
603559
82
158
724264
87
205
86
5265
97
215
136
82
133
178
428
148-156
90-95
137-138
192-198
443-450
0
200
400
600
800
1000
1200
20012002
20032004
20052006E
Selected Income Statement Components($ in millions)
D & A $192 - $198Interest $137 - $138Income Tax $90 - $95Net Income $148 - $156
O & M $443 - $450
2006E Consolidated($ millions)
Financial Outlook - Consolidated
50
Net Income by Segment
UtilityNatural Gas Marketing Pipeline & StorageOtherTotalAvg. Diluted SharesEarnings Per Share
2005
$ 8123311
13679.0
$ 1.72
($ millions, except EPS)
2004
$ 631733
8654.4
$ 1.58
Financial Outlook - Consolidated
$ 97 - 9819 - 2431 - 32
1 - 2148 - 156
82.0$1.80 - $1.90
2006E2003
$ 62(1)
74
7246.5
$ 1.54
51
90
211
90-94
183-189
$0
$50
$100
$150
$200
$250
$300
$350
2005 2006E MaintenanceGrowth
Financial Outlook - Consolidated
Capital Expenditures – 2006 Fiscal Year
Utility CAPEX(in millions)
725
90-93
37-39
$0$20$40
$60$80
$100
$120$140
2005 2006E
Pipeline & Storage CAPEX (in millions)
Consolidated fiscal 2006 CAPEX projection is $400-$415 million
$301 $273-$283 $127-$132
$32
52
Cash flows from operationsMaintenance/Non-growth capital Dividend
Cash available for debt reductionand growth projects
2003 2005
$ 49(110)
(55)
$ (116)
$ 387 (243)
(99)
$ 45
2004
$ 271(126)
(67)
$ 78
Cash Flow($ millions)
Financial Outlook - Consolidated
Note: The company issued approximately $2.0 billion in debt and equity in 2004. Net cash proceeds exceeded the TXU Gas purchase price by approximately $56 million (after $43 million related to Treasury lock obligations) in anticipation of funding significant and attractive growth projects.
2006E
$ 393 - 403 (220 - 228)
(103)
$ 70 - 72
53
267149 574
214
505
156529
505
$0
$200
$400
$600
$800
$1,000
$1,200
2003 2004 2005 2006E
Atmos Energy Corp. Atmos Energy Holdings
Net Liquidity Position Is Solid With Existing Credit Lines*
1,034
416
786661
$ m
illio
nsFinancial Outlook - Consolidated
* Subject to internal borrowing strategy and collateral limitations primarily at AEH
54
Investment Grade Credit Ratings
Moody’s RatingSenior Unsecured Debt: Baa3Commercial Paper: P-3Outlook: stable
Standard & Poor’sSenior Unsecured Debt: BBBCommercial Paper: A-2Outlook: stable
FitchSenior Unsecured Debt: BBB+Commercial Paper: F-2Outlook: negative
Financing Activities
55
Summary
18.1
14.913.8
8.0
12.0
16.0
20.0
S&P 500 Peer GroupAvg.
AtmosEnergy
Compelling Valuation
4.7
5.9
3.0
6.0
9.0
12.0
Peer GroupAvg.
AtmosEnergy
S&P 500
Forward P/E Estimates 5 Year Growth Estimates
Companies in the peer group include AGL Resources, KeySpan, Laclede, New Jersey Resources, Nisource, Northwest Natural Gas, Oneok, Piedmont Natural Gas, Southwest Gas and WGL Holdings.
12.4
Source: Bloomberg
56
Summary
Company Profile
The nation’s largest pure-gas distribution companySolid financial foundationTrack record of creating shareholder value• Consistent earnings growth• 22 consecutive years of increasing dividends
Focused strategy over time• Maximize core natural gas utility earnings capability• Complement core utility business through select
nonutility operations• Grow through prudent acquisitions
57
Appendix
58
11.3
10.5-11.5 10.1
11.611.0
12.2
9.5-10.5
10.0 9.8
12.0
11.3
10.5
5.0
6.0
7.0
8.0
9.0
10.0
11.0
12.0
13.0
CO LA GA IL IA MO VA
Mid-TX/PL MS
Amarillo
LubbockW. T
X
Perc
ent
Authorized Regulatory Returns
Authorized Regulatory Return on Equity (ROE) by Division *
Consolidated GAAP Average ROE at 9/30/05 was 9.0%
* ROE not stated in state commission’s decision in Kansas, Kentucky and Tennessee
59
Storage Trading Margin - Economic Value vs. GAAP Reported Results
Atmos Energy Marketing - Storage
Reported GAAPValue
- Physical and FinancialPositions
($14.8 MM)
Reported GAAPValue
- Physical and FinancialPositions
($14.8 MM)
Economic Value*(Commercial Value)(Embedded Value)
- Physical and FinancialPositions
$13.1 MMStorage
Trading Margin
Embedded margindifference
$27.9 MM * Realizing Economic Value is dependent on ability toexecute – deliver physical gas & close financial hedges
At September 30, 2005
60
Atmos Energy Marketing - Storage
We commercially manage our storage assets by capturing arbitrage value through optimization strategies that create embedded (forward) value in the portfolio. We financially report the transactions for external reporting purposes in accordance with GAAP.
GAAP Reported Value is the period to period net change in fair value of the portfolio reported in the income statement that results from the process of marking to market the physical storage volumes and corresponding financial instruments in an interim period.
Economic Value is the period to period forward margin of our storage portfolio that results from the process of calculating our weighted average cost of inventory (WACOG), and our weighted average sales price of our forward financials (WASP), then multiplying the difference times inventory volumes. This margin will be realized in cash when the hedged transaction is executed or when financials are settled and then reset to stay hedged against physical volumes.
Economic Value represents the “forward” economic margin of the transactions, while GAAP reported results reflect that portion of our “forward” margin that has been recorded in the income statement. Volatility in earnings includes the impact of the accounting treatment of our storage portfolio and is reflective of relatively high price volatility of the prompt month, and the relatively low volatility of the offsetting forward months.
Trading Margin Description
61
$0.0
$2.0
$4.0
$6.0
$8.0
$10.0
$12.0
$14.0
$16.0
Sep-04Dec-04
Mar-05Jun-05
Sep-05
($ in
Mill
ions
)
$.25 Price Move $.50 Price Move $1 Price Move
Storage Volumes:
Atmos Energy Marketing - Storage
Storage Margin Volatility (Potential Impact of Change in GAAP Reported Spread Values)
Sep-04 Dec-04 Mar-05 Jun-05 Sep-05BCF 5.5 6.4 12.5 14.7 6.9
62
Atmos Energy Marketing
Natural Gas Marketing Segment 2005 2004 Change
Storage Activities Realized margin $28,008 ($1,900) $29,908
Unrealized margin (14,007) 357 (14,364)Total Storage Activities 14,001 (1,543) 15,544
Marketing Activities Realized margin 59,971 51,347 8,624
Unrealized margin (11,999) (3,173) (8,826)Total Marketing Activities 47,972 48,174 (202)
GROSS PROFIT $61,973 $46,631 $15,342
Ending storage balance (Bcf) 6.9 5.5 1.4
Year Ended September 30
(In thousands, except storage balances)
63
Atmos Pipeline - Texas
64
Atmos Pipeline - Texas
Northside Loop Agreement – Energy TransferJoint Venture with Energy Transfer Fuel to construct and operate approximately 45 miles of 30" pipeline extending from Justin to Frisco, in the northern part of the DFW Metroplex, creating incremental capacity of 225 MMcf/d. Initial investment approximately $45 million, contributed over a two-year period with final Atmos contribution made in April 2006 Justin to Line F segment expected in-service by end of December 2005, remaining segment by February 2006Compression is ordered and anticipated to be in-service by March 2006CAPEX: approximately $1.6 million in fiscal 2005; $43.4 million in fiscal 2006
Enbridge - Line (Corridor Compression Project)Executed agreement in May 2005 to install compression to enhance re-injection capabilities at Bethel and to transport up to 100 MMcf/d into Enbridge’s new 36” Carthage pipeline at Bethel. Start date anticipated early-2006CAPEX: approximately $4 million in fiscal 2005; $16 million in fiscal 2006. GRIP eligible in calendar 2006 filing when the line becomes operational
Devon – Line (Corridor Compression Project)Executed agreement in July 2005 to transport up to 50 MMcf/d into Enbridge. Start date anticipated early-2006
Katy Capacity Expansion (Compression Project)Signed agreements in July 2005 with 3 shippers to transport an additional 50 MMcf/d of capacity to the Katy area. Project is expected to come online in June 2006CAPEX: approximately $1.3 million in fiscal 2005 and $13.7 million fiscal 2006.
Project Update
65
Atmos Pipeline-Texas Project Map
North SideLoop
EnbridgeCompression
66
Metropolitan New Orleans AreaTLGP Transmission / TLGP Sales Points
Metropolitan New Orleans AreaTLGP Transmission / TLGP Sales Points
St. Cha
rles P
arish
Jeffe
rson
Par
ish
Orle
ans
Par
ish
N
S
EW
October 26, 2001
TLGP 24”
Bridgeline Gas(Paradis)
S39,T14S,R20E
Bridgeline Gas(Paradis)
S39,T14S,R20EFuture Interconnect
Columbia GulfFuture Interconnect
Columbia Gulf
B’line 14”
Acadian Gas PipelineS48,T13S,R21E
Acadian Gas PipelineS48,T13S,R21E
Gulf South PipelineS48,T13S,R21E
Gulf South PipelineS48,T13S,R21E
TLGP 16”
AEL 18”
Entergy Louisiana(TLGP Sales)S5,T13S,R20E
Entergy Louisiana(TLGP Sales)S5,T13S,R20E
Atmos Energy LouisianaS5,T13S,R23E
Atmos Energy LouisianaS5,T13S,R23E
S24,T13S,R23E
21 Miles of 24” TLGP Pipe.95 Miles of 12” TLGP Pipe
Storage is held on upstream pipelines
• Bridgeline
• Acadian
• Gulf South
TLGP PipelineTLGP Pipeline
Trans Louisiana Gas Pipeline