New York April 19-20, 2006
Analyst Meetings
www.sug.com
Analyst Meetings New York April 19-20, 2006 www.sug.com Safe - - PowerPoint PPT Presentation
Analyst Meetings New York April 19-20, 2006 www.sug.com Safe Harbor This present at ion and ot her Company report s and st at ement s issued or made from t ime t o t ime cont ain cert ain forward-looking st at ement s concerning proj
New York April 19-20, 2006
www.sug.com
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This present at ion and ot her Company report s and st at ement s issued or made from t ime t o t ime cont ain cert ain “ forward-looking st at ement s” concerning proj ect ed financial performance, expect ed plans or fut ure
from such proj ect ions or expect at ions. Invest ors should be aware of import ant fact ors t hat could cause act ual result s t o differ mat erially from t he forward-looking proj ect ions or expect at ions. These fact ors include, but are not limit ed t o: cost of gas; gas sales volumes; gas t hroughput volumes and available sources of nat ural gas; discount ing of t ransport at ion rat es due t o compet it ion; cust omer growt h; abnormal weat her condit ions in Sout hern Union’ s service areas; impact of relat ions wit h labor unions of bargaining-unit employees; t he receipt of t imely and adequat e rat e relief and t he impact of fut ure rat e cases or regulat ory rulings; t he out come of pending and fut ure lit igat ion; t he speed and degree t o which compet it ion is int roduced t o Sout hern Union’ s nat ural gas dist ribut ion businesses; new legislat ion and government regulat ions and proceedings involving or impact ing Sout hern Union; unant icipat ed environment al liabilit ies; abilit y t o compl y wit h or t o challenge successfully exist ing or new environment al regulat ions; changes in business st rat egy and t he success of new business vent ures, including t he risks t hat t he business acquired and any ot her business or invest ment t hat Sout hern Union has acquired or may acquire may not be successfully int egrat ed wit h t he business of Sout hern Union; exposure t o cust omer concent rat ion wit h a significant port ion of revenues realized from a relat ively small number of cust omers and any credit risks associat ed wit h t he financial posit ion of t hose cust omers; fact ors affect ing
Sout hern Union’ s or any of it s subsidiaries’ debt securit y rat ings; t he economic climat e and growt h in t he energy indust ry and service t errit ories and compet it ive condit ions of energy market s in general; inflat ionary t rends; changes in gas or ot her energy market commodit y prices and int erest rat es; current market condit ions causing more cust omer cont ract s t o be of short er durat ion, which may increase revenue volat ilit y; t he possibilit y of war or t errorist at t acks; t he nat ure and impact of any ext raordinary t ransact ions, such as any acquisit ion or divest it ure of a business unit or any asset . Cont act : Sout hern Union Company Jack Walsh, 800-321-7423 j ack.walsh@ sug.com
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S enior Vice President & CFO
President – S U Gas S ervices
S enior Vice President – S U Gas S ervices
Direct or of Invest or Relat ions
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tock Exchange (NYS E:S UG)
– Approximat ely $80 million in 1990
– Approximat ely $219 million in 1990
– Approximat ely $346 million in 1990
– Yield approximat ely 1.6%
– BBB – S tandard & Poor's – Baa3 – Moody’ s Investor S ervices – BBB – Fitch Ratings
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Metro Mobile Metro Mobile acquires Southern acquires Southern Union Gas Union Gas Acquisition of Acquisition of Pennsylvania Pennsylvania
Acquisition of Acquisition of Panhandle Panhandle
Acquisition of Acquisition of New England New England
Acquisition of Acquisition of Missouri Missouri
Sale of Texas Sale of Texas
1999 2000 2003 1994 1995 1996 1997 1998 2001 2002 2004 2005 2006
Acquisition of Sid Acquisition of Sid Richardson Richardson Acquisition of Acquisition of CrossCountry CrossCountry Energy Energy
1990
Actively manage portfolio of assets to increase shareholder value
Announced sale of Announced sale of PA operations PA operations Announced sale of Announced sale of RI operations RI operations
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$0 $5 $10 $15 $20 $25 $30
F e b
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$0 $5 $10 $15 $20 $25 $30
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u g
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F e b
CAGR = 14.7%
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Sid Richardson Energy Services Co. and relat ed companies
be replaced wit h proceeds from asset sales and appropriat e permanent financing wit hin t he calendar year
Services
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___________________________
Pipeline, El Paso Natural Gas Co, Energy Transfer Fuel LP, Enterprise Texas Pipeline, Transwestern Pipeline.
realized for residual gas and NGL product ion
– Residue gas: (1) California, Mid-con, Texas – NGLs: (2) Mont Belvieu
team
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SU Gas Services SU Gas Services – Area of Operations Area of Operations
Pipelines Tot al Miles 4,750 Producer Delivery Point s 1,754 Current Throughput 596 Bbtu/ d (1) Field Compression HP 104,840/ 54,250 Gas Processing Plants Active Plants (2) 4 Processing Capacit y
(3)
470/ 410 MMcfd Processing Throughput 388 MMcf/ d (1) Field Compression HP 127,520/ 82,000 Treating Plants Active Plants 6 Treating Capacity 765/ 590 MMcfd Treat ing Throughput 426 MMcf/ d (1) Compression HP (4) 7,200/ 2,200
__________________________
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ervices
ervices
ervices
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allows flexibility to transfer volumes between plants – Creates the opportunity to fully realize capacities throughout the system regardless of where production activity occurs – By transferring the volumes to different plants there is the ability to take advantage of pricing point differentials throughout the system – Allows the blending of rich and lean gas from various parts of the system to effectively bypass processing
UGS to realize arbitrages within its own system
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Well Permits and Production West Texas and SE New Mexico Operating Area(1)
2,000 2,500 3,000 3,500 4,000 4,500 5,000 1Q99 2Q00 3Q01 4Q02 1Q04 2Q05 MMcf/d 100 200 300 400 500 600 700 800 900 1,000 1,100 1,200 # of Permits Gas Production Permits
S
. Historical and PI/ Dwight s Plus. (1) Represents well permits and production from the 16 counties in which S id Richardson operates. (2) 2Q proj ection is April and May normalized.
(2)
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These multiple take away options take advantage of pricing point differentials and help to maximize price realizations
Major Pipeline Interconnects Major Liquid Pipeline Interconnects
Current Meter Capacity Entity Number Status Mcf/ D ATMOS Pipeline - Texas (Lone Star) 3 Delivery 236,000 El Paso Nat ural Gas Co. 3 Delivery 330,000 El Paso Nat ural Gas Co. 1 Receipt 53,000 Energy Transfer Fuel LP (TUFCO) 2 Delivery 161,000 Enterprise Texas Pipeline (Gulft erra Texas) 1 Delivery 126,000 Enterprise Texas Pipeline (GTTX/ Duke Grey Ranch) 1 Delivery 180,000 Kinder Morgan - Rancho (under const ruct ion) 1 Delivery 50,000 Northern Natural Gas Co. 2 Delivery 120,000 Northern Natural Gas Co. 1 Receipt 100,000 Oasis Pipeline, L.P. 5 Delivery 328,000 OneOk WesTex Transmission (Westar ) 1 Delivery 53,000 OneOk WesTex Transmission (Red River) 1 Delivery 35,000 OneOk WesTex Transmission (Red River) 1 Receipt 35,000 Transwest ern Pipeline Co. 1 Delivery 118,000 Total 1,925,000 Entity Facility West Texas LPG Pipeline (Chevron) Tippet t Chaparral (TEPPCO) Jal, Keyst one Louis Dreyfus (former ExxonMobil Pipeline) Coyanosa, Keystone Huntsman - Odessa Chemical Plant via REM owned pipeline (idle) Jal
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UGS ’ contract mix helps reduce fluctuations in cash flows associated with volatile commodity prices
POP/ Fee Based representing over 96%
– Fee-based represents no commodity price exposure – Percent -of-proceeds results in long gas/ long liquids position – Minimal exposure to keep- whole contracts (short gas/ long liquids position)
2005 Total System Profile
Percent of Proceeds, 45% Fee Based, 37% Wellhead Purchases, 4% Conditioning Fee, 14%
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by volume
by margin
in cont ract
– 55% by volume – 15 – 20% by margin – Cont ract s cont ain fixed fees for service – Depending on gas qualit y cont ract s may cont ain upside for processing and no downside risk below base fee – Creat es exposure t o diverse producer base wit h no downside commodit y risk
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approximately 60%
with no one customer accounting for as much as 10%
developed as companies pursue new growt h
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– Diversified inter-connected assets – S trong reliable operations
– Fixed recovery contract structure – Gas rej ection – Blending
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100 200 300 400 500 600 700 800 900
10 20 30 40
Processing Spread (Cents/Gal) SUGS Total & Net Processing Margin (M$/Day)
Data from Nov/ Dec 2005 Daily Processing Model
Gas price averaged for the period
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and reduce exposure t o commodit y price risk – $11 floor for 2006 on 85%
– $10 floor for 2007 on 50%
appropriat e inflect ion point s
due t o fixed recovery cont ract st ruct ure; eliminat es exposure t o NGL’s and t o basis risk
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enhance its operating systems without increasing O&M expenses
throughout system
excess processing/ treating plant and pipeline capacity in response to market conditions
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unaccountable volumes
syst ems for leaks
efficiencies
plant by recapture or redirection
compet it ive advant age
equally
relationships
ecure acreage dedications
ahead of well completion
NGLs
risk
processing upside, fee protection
NGLs, opt ion t o by-pass processing
long gas & NGLs
high processing spreads
processing spreads dictate
appropriate gas quality
between plants and compressors
margins
tied to commodity prices
portion using gas
convert to NGLs when profitable
st rat egy
spread exposure at plants
capability
use of t echnology
each plant
t ransport at ion and fract ionat ion
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– Panhandle Energy
– CrossCount ry Energy (50% equit y int erest )
)
)
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– S
ervices
– Missouri Gas Energy – New England Gas Company (RI under contract for sale) – PG Energy (under contract for sale)
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Line (PEPL)
–6,500 mile 4-line syst em –2.8 Bcf/ d capacit y
–3,500 mile 2-line syst em –1.5 Bcf/ d capacit y
–450 mile offshore syst em –1.0 Bcf/ d capacit y
–2,400 mile bi-direct ional flow syst em –2.1 Bcf/ d capacity (1.2 Bcf/ d west ; 800 MMcf/ d east ) –1.2 Bcf/ d San Juan to mainline capacit y
–5,000 mile syst em –2.1 Bcf/ d capacit y
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Trunkline LNG is a Leading Player in LNG Sector
largest operating facilities
credit quality counterparty— BG Group— until 2028
end out capacity to be expanded to 1.8 Bcf/ d by mid 2006
and NGL extraction to be in service by 2008
Above: Art ist 's rendering of expanded facilit y.
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Wilkes-Barre, PA
160,000 cust omers
nort heast ern and central PA
Pennsylvania PUC
PA assets to UGI for $580 million
Providence, RI
300,000 cust omers
Rhode Island and SE Massachuset t s
and t he Massachuset t s DT&E
assets to National Grid for $575 million including assumed debt
Missouri Gas Energy Missouri Gas Energy PG Energy PG Energy New England Gas Co. New England Gas Co.
Kansas Cit y, MO
500,000 cust omers
t hroughout MO
Missouri PS C
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Filed with FERC 25% Mid 2007 $6 - $14 $60 - $100 100 – 160 MMcf/ d Florida Gas Phase VII Filed with FERC 100% Mid 2008 $35-$40 $250 Vaporization & NGL extraction Trunkline LNG IEP Under construction 100% Mid 2006 $16 $82 600 MMcf/ d Trunkline LNG Phase II Complete 100% April 4, 2006 $28 $137 570 MMcf/ d 2.7 Bcf storage Trunkline LNG Phase I
Comments SUG % In Service
($MM)
($MM) Capacity Project Name
* Note: EBIT is equivalent to operating income under GAAP.
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Under Negot iat ion Under Negot iat ion
($MM)
Early 2008 $500 - $600 500 MMcf/ d Phoenix Lateral Late 2007 $90 - $110 600 MMcf/ d Trunkline North Texas
In Service
($MM) Capacity Project Name
Note: All data shown above is subj ect to revision based upon final proj ect specifications.
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$0.00 $0.50 $1.00 $1.50 $2.00 FY 2003 FY 2004 CY 2005 CY 2006E
Diluted EPS $0.66 $1.24 $1.58*
* - 2005 Diluted EPS excludes a non-cash charge of $175 million related to the impairment of goodwill for the distribution properties expected to be sold in 2006. Reported EPS was $.03 per share. Note: Prior period EPS amounts have been adj usted to reflect the 5% stock dividend paid to shareholders on S eptember 1, 2005. Previously issued 2006 GAAP guidance included contributions from S U Gas S ervices for ten months, closing of the LDC sales prior to the end of the third quarter, and excludes proj ected one-time charges related to the announced LDC sales.
$1.70 - $1.90
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$0 $50,000 $100,000 $150,000 $200,000 $250,000 $300,000 $350,000 $400,000 ($000) 2003 2004 2005 CFFO
Cash Flow From Operations
(Before Changes in Working Capit al)
Cash Flow From Operations Cash Flow From Operations
(Before Changes in Working Capit al) (Before Changes in Working Capit al)
Note: Data shown represents fiscal year ended June 30, 2003 and calendar years ended December 31, 2004 and 2005. Note: Data shown represents fiscal year ended June 30, 2003 and Note: Data shown represents fiscal year ended June 30, 2003 and calendar years ended December 31, calendar years ended December 31, 2004 and 2005. 2004 and 2005.
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$0 $50,000 $100,000 $150,000 $200,000 $250,000 $300,000 ($000) 2002 2003 2004 2005 Distribution Transportation
Note: Data shown represents fiscal years ended June 30, 2002 and 2003 and calendar years ended December 31, 2004 and 2005. 2005 data excludes a non-cash charge of $175 million related to the impairment of goodwill for the Company’ s distribution businesses under contract to be sold in 2006. Reported operating income for the distribution segment was a loss of $42.5 million.
As we have changed our asset focus, we have demonstrated measured growth…
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35% 65% 37% 63% 47% 53% 0% 20% 40% 60% 80% 100% 2003 2004 2005
Equity Debt
… and improved our balance sheet. We have accomplished this with a combination
and strong internal equity formation.
Note: Debt/ Cap ratio as of December 31 for periods shown; provides 100% equity credit for preferred stock and convertible equity units.
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