El Paso Corporation (NYSE: EP) is today reporting third quarter 2011
financial and operational results for the company. Key highlights
include:
-
$0.18 adjusted diluted earnings per share (EPS) for third quarter 2011
-
E&P production volumes were 827 million cubic feet equivalent per day
(MMcfe/d), including Four Star Oil & Gas Company (Four Star)
unconsolidated affiliate volumes, up 8 percent from the third quarter
of 2010
-
Third quarter 2011 domestic oil production, including Four Star, up 25
percent from the third quarter of 2010
-
Latest Wolfcamp shale well produced 1,369 barrels of oil equivalent
per day (BOE/d) in a 24-hour test
-
Eagle Ford oil production growing rapidly with completion of natural
gas gathering facilities
-
Tennessee Gas Pipeline (TGP) rate case settlement filed
-
$1.1 billion Gulf LNG regasification terminal (50 percent owned by El
Paso) placed in service October 1, on-time and on-budget
-
$0.7 billion TGP 300 Line expansion placed in-service November
1, on-time and on-budget
-
TGP added another Marcellus project - MPP pipeline expansion
"Our businesses are delivering excellent operational results," said Doug
Foshee, chairman, president and chief operating officer of El Paso
Corporation. "With the TGP 300 Line expansion now in service, we have
completed what was an $8 billion backlog of pipeline projects, the
largest in our company's history. And we continue to add new projects to
meet our customers' infrastructure needs. The latest is another
Marcellus-related expansion on TGP, bringing our total Marcellus
expansions to $1.3 billion. E&P continues to hit on all cylinders,
generating rapid oil production growth, through continued activity in
the Eagle Ford, Wolfcamp, Altamont, and South Louisiana Wilcox programs.
We expect this growth to continue given our leading positions in some of
the most exciting and prolific areas in North America. We're of course
very excited about our pending sale to Kinder Morgan, Inc. Our focus
between now and the successful conclusion of that transaction remains on
delivering excellent operational results."
Items Impacting Quarterly Results
|
|
|
|
|
|
|
|
|
|
Third Quarter 2011
|
|
|
|
|
|
|
|
|
|
($ millions, except per share
|
|
|
|
|
|
|
|
|
|
amounts)
|
|
|
Before Tax
|
|
|
After Tax
|
|
|
Diluted EPS
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to El
|
|
|
|
|
|
|
|
|
|
Paso Corp. (EPC) common stockholders
|
|
|
|
|
|
$
|
(368
|
)
|
|
|
$
|
(0.48
|
)
|
Adjustments(1)
|
|
|
|
|
|
|
|
|
|
Impact of E&P financial
|
|
|
|
|
|
|
|
|
|
derivatives(2)
|
|
|
$
|
(168
|
)
|
|
|
$
|
(107
|
)
|
|
|
$
|
(0.14
|
)
|
Ceiling test charges - Brazil
|
|
|
|
152
|
|
|
|
|
152
|
|
|
|
|
0.20
|
|
Change in fair value of legacy
|
|
|
|
|
|
|
|
|
|
indemnification and other legacy
|
|
|
|
|
|
|
|
|
|
items(3)
|
|
|
|
22
|
|
|
|
|
14
|
|
|
|
|
0.02
|
|
Loss on debt extinguishment
|
|
|
|
101
|
|
|
|
|
64
|
|
|
|
|
0.08
|
|
Deconsolidation of Ruby
|
|
|
|
|
|
|
|
|
|
Loss on Ruby investment(4)
|
|
|
|
475
|
|
|
|
|
297
|
|
|
|
|
0.39
|
|
Loss on recognition of interest
|
|
|
|
|
|
|
|
|
|
rate swaps(5)
|
|
|
|
125
|
|
|
|
|
78
|
|
|
|
|
0.10
|
|
Separation costs
|
|
|
|
7
|
|
|
|
|
4
|
|
|
|
|
-
|
|
Impact of estimated annual effective
|
|
|
|
|
|
|
|
|
|
tax rate(6)
|
|
|
|
-
|
|
|
|
|
8
|
|
|
|
|
0.01
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EPS(7)
|
|
|
|
|
|
|
|
|
$
|
0.18
|
|
(1) All individual adjustments assume a 36 percent statutory tax rate,
except for the ceiling test charges and loss on deconsolidation of Ruby,
and assume 764 million diluted shares
(2) Includes $251 million of gains on financial derivatives, adjusted
for $83 million of cash settlement proceeds
(3) Legacy items consist of change in fair value of legacy
indemnification and environmental remediation costs
(4) Reflects a non-cash loss based on the difference between the net
carrying value of Ruby and the estimated fair value of El Paso's net
investment
(5) Reflects a non-cash loss associated with the recognition of
mark-to-market losses related to Ruby's interest rate swaps previously
included in other comprehensive loss
(6) Reflects the impact on quarterly earnings using the company's
current estimate of its overall annual effective tax rate including the
effects of adjustments
(7) Reflects fully diluted shares of 775 million
Financial Results -- Third Quarter 2011 For the third quarter 2011, El
Paso reported a net loss attributable to EPC common stockholders of $368
million, or $0.48 per diluted share, compared with net income
attributable to EPC common stockholders of $133 million, or $0.19 per
diluted share, for the third quarter 2010. Earnings for third quarter
2011 and 2010, after adjusting for impacts of E&P financial derivatives
and other items, were $0.18 and $0.22 per diluted share, respectively.
Items Impacting Nine Month Results
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30, 2011
|
|
|
|
|
|
|
|
|
|
($ millions, except per share
|
|
|
|
|
|
|
|
|
|
amounts)
|
|
|
Before Tax
|
|
|
After Tax
|
|
|
Diluted EPS
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to EPC
|
|
|
|
|
|
|
|
|
|
common stockholders
|
|
|
|
|
|
$
|
(44
|
)
|
|
|
$
|
(0.06
|
)
|
Adjustments(1)
|
|
|
|
|
|
|
|
|
|
Impact of E&P financial
|
|
|
|
|
|
|
|
|
|
derivatives(2)
|
|
|
$
|
(51
|
)
|
|
|
$
|
(32
|
)
|
|
|
$
|
(0.04
|
)
|
Ceiling test charges - Brazil
|
|
|
|
152
|
|
|
|
|
152
|
|
|
|
|
0.20
|
|
Change in fair value of legacy
|
|
|
|
|
|
|
|
|
|
indemnification and other legacy
|
|
|
|
|
|
|
|
|
|
items(3)
|
|
|
|
33
|
|
|
|
|
21
|
|
|
|
|
0.03
|
|
Loss on debt extinguishment
|
|
|
|
169
|
|
|
|
|
108
|
|
|
|
|
0.14
|
|
Deconsolidation of Ruby
|
|
|
|
|
|
|
|
|
|
Loss on Ruby investment(4)
|
|
|
|
475
|
|
|
|
|
297
|
|
|
|
|
0.40
|
|
Loss on recognition of interest
|
|
|
|
|
|
|
|
|
|
rate swaps(5)
|
|
|
|
125
|
|
|
|
|
78
|
|
|
|
|
0.10
|
|
Separation costs
|
|
|
|
7
|
|
|
|
|
4
|
|
|
|
|
-
|
|
Impact of estimated annual effective
|
|
|
|
|
|
|
|
|
|
tax rate(6)
|
|
|
|
-
|
|
|
|
|
(24
|
)
|
|
|
|
(0.03
|
)
|
Effect of change in number of
|
|
|
|
|
|
|
|
|
|
diluted shares
|
|
|
|
-
|
|
|
|
|
-
|
|
|
|
|
(0.02
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EPS(7)
|
|
|
|
|
|
|
|
|
$
|
0.72
|
|
(1) All individual adjustments assume a 36 percent statutory tax rate,
except for the ceiling test charges and loss on deconsolidation of Ruby,
and assume 747 million diluted shares
(2) Includes $274 million of gains on financial derivatives, adjusted
for $223 million of cash settlement proceeds
(3) Legacy items consist of change in fair value of legacy
indemnification and environmental remediation costs
(4) Reflects a non-cash loss based on the difference between the net
carrying value of Ruby and the estimated fair value of El Paso's net
investment
(5) Reflects a non-cash loss associated with the recognition of mark-to-
market losses related to Ruby's interest rate swaps previously included
in other comprehensive loss
(6) Reflects the impact on quarterly earnings using the company's
current estimate of its overall annual effective tax rate including the
effects of adjustments
(7) Reflects fully diluted shares of 772 million
Financial Results -- Nine Months Ended September 30, 2011
For the nine months ended September 30, 2011, El Paso reported a net
loss attributable to EPC common stockholders of $44 million, or $0.06
per diluted share, compared with net income attributable to EPC common
stockholders of $659 million, or $0.90 per diluted share, for the first
nine months of 2010. Earnings for the first nine month periods of 2011
and 2010, after adjusting for impacts of E&P financial derivatives and
other items, were $0.72 and $0.77 per diluted share, respectively.
El Paso reported a tax benefit for the nine months ended September 30,
2011, due to a low level of pre-tax income resulting from non-cash
losses on the deconsolidation of Ruby and the Brazilian ceiling test
charge (which does not include a corresponding tax benefit) as well as
the favorable resolution of certain tax matters in the first half of
2011. Absent these items, the effective tax rate for the nine months
would have been 21 percent. The company's effective tax rate is expected
to remain well below the statutory tax rate due to the earnings
attributable to noncontrolling interests.
Business Unit Financial Results
|
|
|
|
|
|
|
|
|
|
|
|
|
Quarters Ended
|
|
|
Nine Months Ended
|
Segment EBIT
|
|
|
September 30,
|
|
|
September 30,
|
|
|
|
|
|
|
|
|
|
|
|
|
|
($ in millions)
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pipeline Group
|
|
|
$
|
(209
|
)
|
|
|
$
|
375
|
|
|
|
$
|
718
|
|
|
|
$
|
1,299
|
|
Exploration and
|
|
|
|
|
|
|
|
|
|
|
|
|
Production
|
|
|
|
183
|
|
|
|
|
261
|
|
|
|
|
402
|
|
|
|
|
754
|
|
Marketing
|
|
|
|
(10
|
)
|
|
|
|
(12
|
)
|
|
|
|
(45
|
)
|
|
|
|
(44
|
)
|
Other
|
|
|
|
(145
|
)
|
|
|
|
(111
|
)
|
|
|
|
(245
|
)
|
|
|
|
(96
|
)
|
|
|
|
$
|
(181
|
)
|
|
|
$
|
513
|
|
|
|
$
|
830
|
|
|
|
$
|
1,913
|
|
Pipeline Group
The Pipeline Group's Segment EBIT for the quarter ended September 30,
2011 was a loss of $209 million, compared with Segment EBIT of $375
million for the same period in 2010. Results for the 2011 period reflect
a non-cash loss of approximately $475 million based on the difference
between the net carrying value of Ruby and the estimated fair value of
El Paso's net investment as a result of the deconsolidation of Ruby. El
Paso also recorded an additional non-cash loss of $125 million upon
deconsolidation associated with the recognition of mark-to-market losses
related to Ruby's interest rate swaps previously included in other
comprehensive loss. Following deconsolidation, Ruby's interest rate
swaps continue to economically hedge Ruby's project level debt. Also
impacting the 2011 third quarter was a decline in the allowance for
equity funds used during construction on expansion projects that were
placed in service during the quarter, principally Ruby. Partially
offsetting these items were higher reservation revenues due to expansion
projects that went into service in 2010 and 2011, and higher
transportation rates on TGP that became effective June 1, 2011. Third
quarter 2010 results include a $21 million non-cash asset write down
based on a Federal Energy Regulatory Commission (FERC) order relating to
the 2009 sale of the Natural Buttes compressor station and gas
processing plant.
Pipeline Group throughput for the nine months ended September 30, 2011,
excluding the company's equity investments, increased 3 percent from the
same 2010 period. The increase was primarily due to higher Marcellus
volumes on TGP, partially offset by declines on El Paso's pipelines in
the Rockies and El Paso Natural Gas. Overall throughput volumes have
minimal impact on near-term financial results, as approximately 90
percent of the Pipeline Group's revenues are derived from fixed
reservation charges. TGP's Marcellus volumes have grown to approximately
1.6 Bcf/d, making it the leading transporter of Marcellus natural gas
production.
Pipeline Expansions
With the recent completion of the TGP 300 Line expansion and the Gulf
LNG regasification terminal, El Paso has finished what was an $8 billion
project backlog in 2008. These projects in the aggregate are more than
90 percent subscribed under long-term contracts and were constructed
within 8 percent of budget.
TGP's superior position in the Marcellus shale has led to four expansion
projects to increase takeaway capacity from the Marcellus area. In
total, these four projects represent approximately $1.3 billion of
capital and 1.5 billion cubic feet per day of new capacity. All of these
projects are fully contracted under long-term agreements. The most
recently announced project is a 235 million cubic feet per day (MMcf/d)
expansion that includes approximately eight miles of 30" pipeline
looping and modifications to four existing compressor stations in
Pennsylvania. It will be placed into service in November 2013, subject
to regulatory approvals.
Rate Case Settlements
In the third quarter of 2011, the company's Pipeline Group successfully
settled one rate case and made significant progress toward settling
another. In August, the FERC approved the settlement of Colorado
Interstate Gas' rate case, which provides for the continuation of its
current tariff rates and contract extensions with its customers. In
September, TGP filed a settlement with the FERC on its rate case. The
proposed settlement increases base tariff rates, increases the
proportion of revenues from monthly demand charges, initiates a fuel
volume tracker and provides for contract extensions with customers. The
proposed settlement is uncontested by TGP's customers and is awaiting
certification to the FERC by the Administrative Law Judge hearing the
case.
Ruby Pipeline
Ruby was placed into service in the third quarter of 2011, and in
October its throughput has averaged approximately 800 MMcf/d. With this
and the satisfaction of conditions under its financing agreements, Ruby
was deconsolidated from El Paso's financial statements and reported as
an equity investment. The $1.4 billion of Ruby debt is no longer
included in El Paso's consolidated debt and is recourse only to the
project. In addition, the construction guarantee for Ruby has been
eliminated.
Pipeline Group Results
|
|
|
Quarters Ended September 30,
|
|
|
|
|
|
|
|
($ in millions)
|
|
|
2011
|
|
|
2010
|
|
|
|
|
|
|
|
Operating income (loss)
|
|
|
$
|
(254
|
)
|
|
|
$
|
290
|
Other income, net
|
|
|
|
45
|
|
|
|
|
85
|
|
|
|
|
|
|
|
|
|
|
Segment EBIT
|
|
|
$
|
(209
|
)
|
|
|
$
|
375
|
DD&A
|
|
|
$
|
136
|
|
|
|
$
|
111
|
Total throughput (BBtu/d)(1)
|
|
|
|
18,511
|
|
|
|
|
17,235
|
(1) Includes proportionate share of jointly-owned pipelines
Exploration and Production
The Exploration and Production segment reported $183 million of Segment
EBIT for the quarter ended September 30, 2011, compared with $261
million of Segment EBIT for the same 2010 period. The decline is due to
$152 million of non-cash ceiling test charges in the company's Brazilian
full cost pool, primarily due to the recent denial of a necessary
environmental permit for the Pinauna development project. El Paso has
filed an appeal and is awaiting a response. Excluding these charges,
Segment EBIT increased by $74 million from the same 2010 period,
primarily due to a $67 million increase in mark-to-market gains, higher
oil, condensate and NGL prices, and higher production volumes, partially
offset by higher DD&A expense.
Third quarter 2011 production volumes rose 8 percent from the third
quarter of 2010, averaging 827 MMcfe/d, including 60 MMcfe/d of Four
Star unconsolidated affiliate volumes. Third quarter 2010 production
volumes averaged 764 MMcfe/d, including 62 MMcfe/d of Four Star
unconsolidated affiliate volumes. El Paso's production is rising
sharply, and the company expects its full-year 2011 production to be
between 830 and 840 MMcfe/d, including Four Star. Fourth quarter 2011
production is expected to be between 850 and 890 MMcfe/d, including Four
Star, which would be a 7 to 12 percent increase from the fourth quarter
2010. Fourth quarter 2011 oil production, including Four Star, is
expected to rise to between 20 and 27 MBbls/d from 17 MBbls/d in the
third quarter 2011. El Paso continues to operate at its forecasted
levels with 13 operated rigs and staying within its $1.6 billion capital
program.
Total per-unit cash operating costs increased to an average of $1.82 per
Mcfe in the third quarter 2011 up from $1.62 per Mcfe for the same
period in 2010, due mainly to temporary higher costs in the Eagle Ford
and Wolfcamp programs due to infrastructure delays, higher maintenance
and repair costs in Altamont and higher expenses in Brazil.
Exploration and Production Operational Update
Wolfcamp - El Paso has completed seven Wolfcamp horizontal wells, the
most recent being the UL-43-17-1H, which tested at a 24-hour rate of
1,270 barrels of oil and 591 Mcf of natural gas, or 1,369 BOE/d. This
well had a 7,500 foot lateral and was completed with 25 stages. El Paso
continues to optimize its completion processes as well as its flow-back
procedures in order to maximize fluid recovery. The company will operate
two rigs in this area for the remainder of the year.
Eagle Ford - El Paso's Midstream Group has completed the natural gas
gathering system for the Eagle Ford Central area, which eliminates what
had been a major production constraint caused by limited natural gas
takeaway capacity. Gross daily Eagle Ford production for the third
quarter 2011 was approximately 10,500 BOE/d. Fourth quarter 2011 gross
production is expected to rise significantly to 17,000 to 18,000 BOE/d.
El Paso expects to operate three rigs in this area for the remainder of
the year.
S. Louisiana Wilcox - El Paso controls 140,000 net acres in this new
oil-focused program. Gross production has already reached approximately
2,500 BOE/d from 9 wells. Given the success to date and the premium
pricing for production -- Louisiana Light Sweet for oil and
approximately $3.00 per Mcf above Henry Hub pricing for natural gas, El
Paso recently increased its activity to two rigs, and continues to
appraise 3-D seismic in this area. The company expects that at year-end
2011 it will have 250 undrilled locations with approximately 55 MMBOE of
net risked resource potential. More information about this program is
available by clicking the following link. South Louisiana Wilcox Slides
Divestiture Update
In the second quarter 2011, El Paso announced that it would raise its
2011 capital program from $1.3 billion to $1.6 billion and fund that
increase with non-core asset sales. The company recently completed the
divestiture of natural gas properties in the Arklatex and the Black
Warrior Basin, a Powder River oil asset and other properties from which
El Paso received proceeds that totaled approximately $570 million,
surpassing its original $400 million to $500 million estimate. These
properties were producing a total of 36 MMcfe/d and had approximately
200 Bcfe of estimated proved reserves.
Exploration and Production Results
|
|
|
Quarters Ended
|
|
|
|
September 30,
|
($ in millions, except price and unit
|
|
|
|
|
|
|
|
|
|
|
cost amounts)
|
|
|
2011
|
|
|
2010
|
|
|
|
|
|
|
|
Physical sales--natural gas, oil,
|
|
|
|
|
|
|
condensate, and NGL revenue
|
|
|
$
|
402
|
|
|
|
$
|
334
|
|
Realized and unrealized gains on financial
|
|
|
|
|
|
|
derivatives
|
|
|
|
251
|
|
|
|
|
184
|
|
Other revenues
|
|
|
|
-
|
|
|
|
|
1
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating revenues
|
|
|
$
|
653
|
|
|
|
$
|
519
|
|
Operating expenses(1)
|
|
|
|
(463
|
)
|
|
|
|
(254
|
)
|
Other (expenses) income
|
|
|
|
(7
|
)
|
|
|
|
(4
|
)
|
|
|
|
|
|
|
|
|
|
|
|
Segment EBIT
|
|
|
$
|
183
|
|
|
|
$
|
261
|
|
DD&A
|
|
|
$
|
157
|
|
|
|
$
|
117
|
|
Consolidated volumes:
|
|
|
|
|
|
|
Natural gas sales volumes (MMcf/d)
|
|
|
|
652
|
|
|
|
|
601
|
|
Oil and condensate sales volumes
|
|
|
|
|
|
|
(MBbls/d)
|
|
|
|
16.4
|
|
|
|
|
13.5
|
|
NGL sales volumes (MBbls/d)
|
|
|
|
2.9
|
|
|
|
|
3.4
|
|
Total consolidated equivalent sales volumes
|
|
|
|
|
|
|
(MMcfe/d)
|
|
|
|
767
|
|
|
|
|
702
|
|
Four Star total equivalent sales volumes
|
|
|
|
|
|
|
(MMcfe/d)(2)
|
|
|
|
60
|
|
|
|
|
62
|
|
|
|
|
|
|
|
|
|
|
|
|
Total combined
|
|
|
|
827
|
|
|
|
|
764
|
|
Weighted average realized price on physical
|
|
|
|
|
|
|
sales:
|
|
|
|
|
|
|
Natural gas ($/Mcf)
|
|
|
$
|
4.27
|
|
|
|
$
|
4.31
|
|
Oil and condensate ($/Bbl)
|
|
|
$
|
86.73
|
|
|
|
$
|
68.00
|
|
NGL ($/Bbl)
|
|
|
$
|
56.03
|
|
|
|
$
|
39.21
|
|
Weighted average realized price, including
|
|
|
|
|
|
|
financial derivative settlements:
|
|
|
|
|
|
|
Natural gas ($/Mcf)
|
|
|
$
|
5.60
|
|
|
|
$
|
5.93
|
|
Oil and condensate ($/Bbl)
|
|
|
$
|
88.95
|
|
|
|
$
|
68.51
|
|
Transportation costs:
|
|
|
|
|
|
|
Natural gas ($/Mcf)
|
|
|
$
|
0.32
|
|
|
|
$
|
0.30
|
|
Oil and condensate ($/Bbl)
|
|
|
$
|
0.07
|
|
|
|
$
|
0.10
|
|
NGL ($/Bbl)
|
|
|
$
|
3.04
|
|
|
|
$
|
3.56
|
|
Per-unit costs ($/Mcfe):
|
|
|
|
|
|
|
DD&A
|
|
|
$
|
2.22
|
|
|
|
$
|
1.81
|
|
Cash operating costs(3)
|
|
|
$
|
1.82
|
|
|
|
$
|
1.62
|
|
(1) 2011 and 2010 include $152 million and $14 million of non-cash
ceiling test charges, respectively
(2) Four Star is an equity investment; volumes disclosed represent the
company's proportionate share
(3) Includes direct lifting costs, production taxes, G&A expenses, and
taxes other than production and income
Hedge Positions
The company actively manages its exposure to commodity prices using
various hedging strategies. During the third quarter, the company
entered into additional natural gas hedges for the remainder of 2011.
After adding these positions, approximately 70 percent of the company's
fourth quarter 2011 domestic natural gas production is hedged at an
average floor price of $6.06 per MMBtu. Approximately 65 percent of the
company's fourth quarter 2011 oil production is hedged with a floor of
$85.99 and a ceiling of $91.88. Further information on the company's
hedging activities will be available in El Paso's Financial and
Operational Reporting Package for Third Quarter 2011, which can be found
in the Investors section of El Paso's website.
Marketing
Marketing reported a Segment EBIT loss of $10 million for the quarter
ended September 30, 2011 compared with a loss of $12 million for the
same period in 2010. Results for both periods were impacted by losses on
transportation-related contracts and changes in the fair value of the
company's legacy power contracts.
Other Operations
During the third quarter of 2011, Segment EBIT from Other Operations was
a loss of $145 million, compared with a loss of $111 million for the
same period in 2010. Third quarter 2011 results include a $101 million
loss, associated with the repurchase of approximately $650 million of
debt, compared with a loss of $104 million in the third quarter 2010
associated with a notes exchange. Also impacting third quarter 2011 and
2010 results were changes to legal and environmental reserves, foreign
currency fluctuations and other items.
Midstream
The Midstream Group (Midstream) has successfully completed its natural
gas gathering system in the Eagle Ford area in south Texas. The system
includes 83 miles of pipeline with a capacity of 150 MMcf/d. Also,
Midstream is developing a 68-mile oil gathering system with a capacity
of 80,000 Bbls/d in the Eagle Ford area, which is expected to be
operational before year-end. Midstream reported that it did not receive
adequate commitments for its Marcellus Ethane Pipeline System (MEPS)
project to proceed at this time.
Detailed financial and operational information for the company will be
posted at www.elpaso.com in the Investors section.
Disclosure of Non-GAAP Financial Measures
The Securities and Exchange Commission's Regulation G applies to any
public disclosure or release of material information that includes a
non-GAAP financial measure. In the event of such a disclosure or
release, Regulation G requires (i) the presentation of the most directly
comparable financial measure calculated and presented in accordance with
GAAP and (ii) a reconciliation of the differences between the non-GAAP
financial measure presented and the most directly comparable financial
measure calculated and presented in accordance with GAAP. The required
presentations and reconciliations are attached, or included in the body
of this release. Additional detail regarding non-GAAP financial measures
can be reviewed in El Paso's Financial and Operational Reporting
Package, which will be posted at www.elpaso.com in the Investors section.
On January 1, 2011, El Paso began using the non-GAAP financial measure
"segment earnings before interest expense and income taxes" or "Segment
EBIT" to assess the operating results and effectiveness of the company
and its business segments. The company believes that Segment EBIT is
useful to its investors because it allows them to use the same
performance measure analyzed internally by our management to evaluate
the performance of our businesses and investments without regard to the
manner in which they are financed or the company's capital structure.
The company defines Segment EBIT as net income (loss) adjusted for
interest and debt expense and income taxes. Segment EBIT does not
reflect a reduction for any amounts attributable to noncontrolling
interests. The 2010 amounts have been conformed to reflect the company's
current performance measure.
Adjusted EPS is defined as diluted earnings per share adjusted for
certain items that the company considers to be significant to
understanding our underlying performance for a given period. Adjusted
EPS is useful in analyzing the company's on-going earnings potential and
understanding certain significant items impacting the comparability of
El Paso Corporation's results. For 2011, Adjusted EPS is earnings per
share attributable to El Paso Corporation common stockholders adjusted
for the impact of E&P financial derivatives, ceiling test charges,
changes in fair value of legacy indemnification and other legacy items,
a loss on debt extinguishment, a loss on the deconsolidation of Ruby,
separation costs, the impact of the estimated annual effective tax rate,
and the effect of the change in the number of diluted shares. For 2010,
Adjusted EPS is earnings per share attributable to El Paso Corporation
common stockholders adjusted for the impact of E&P financial
derivatives, ceiling test charges, changes in legacy derivative
contracts and other legacy items, the gain on sale of Mexican pipeline
assets, the loss on debt extinguishment, the impact of health care
legislation, the tax benefit from liquidation or foreign entities and
the impact of the estimated annual effective tax rate.
Exploration and Production per-unit total cash operating costs is a
non-GAAP measure calculated on a per Mcfe basis equal to total operating
expenses less DD&A, transportation costs, costs of products and
services, ceiling test charges, and other non-cash charges, divided by
total consolidated equivalent production. It is a valuable measure used
by oil and gas companies and analysts to evaluate operating performance
and efficiency.
El Paso believes that the non-GAAP financial measures described above
are also useful to investors because these measurements are used by many
companies in the industry as a measurement of operating and financial
performance and are commonly employed by financial analysts and others
to evaluate the operating and financial performance of the company and
its business segments and to compare it with the performance of other
companies within the industry. These non-GAAP financial measures may not
be comparable to similarly titled measures used by other companies and
should not be used as a substitute for net income, earnings per share or
other measures of financial performance presented in accordance with
GAAP.
El Paso Corporation provides natural gas and related energy products in
a safe, efficient, and dependable manner. The company owns North
America's largest interstate natural gas pipeline system, one of North
America's largest independent exploration & production companies and an
emerging midstream business. El Paso owns a 42 percent limited partner
interest, and the 2 percent general partner interest in El Paso Pipeline
Partners, L.P. On October 16, 2011, El Paso Corporation announced that
it has entered into a definitive agreement whereby Kinder Morgan, Inc.
will acquire all of the outstanding shares of El Paso Corporation. For
more information, visit www.elpaso.com.
IMPORTANT ADDITIONAL INFORMATION WILL BE FILED WITH THE SEC
Kinder Morgan, Inc. ("KMI") plans to file with the SEC a Registration
Statement on Form S-4 in connection with the proposed transaction, and
KMI and El Paso Corporation ("EP") plan to file with the SEC and mail to
their respective stockholders a Joint Proxy/Information
Statement/Prospectus in connection with the proposed transaction. THE
REGISTRATION STATEMENT AND THE JOINT PROXY/INFORMATION
STATEMENT/PROSPECTUS WILL CONTAIN IMPORTANT INFORMATION ABOUT KMI, EP,
THE PROPOSED TRANSACTION AND RELATED MATTERS. INVESTORS AND SECURITY
HOLDERS ARE URGED TO READ THE REGISTRATION STATEMENT AND THE JOINT
PROXY/INFORMATION STATEMENT/PROSPECTUS CAREFULLY WHEN THEY BECOME
AVAILABLE. Investors and security holders will be able to obtain free
copies of the Registration Statement and the Joint Proxy/Information
Statement/Prospectus and other documents filed with the SEC by KMI and
EP through the web site maintained by the SEC at www.sec.gov. In
addition, investors and security holders will be able to obtain free
copies of the Registration Statement and the Joint Proxy/Information
Statement/Prospectus by phone, e-mail or written request by contacting
the investor relations department of KMI or EP at the following:
|
|
|
Kinder Morgan, Inc.
|
|
|
El Paso Corporation
|
Address:
|
|
|
500 Dallas Street, Suite 1000
|
|
|
1001 Louisiana Street
|
|
|
|
Houston, Texas 77002
|
|
|
Houston, Texas 77002
|
|
|
|
Attention: Investor Relations
|
|
|
Attention: Investor Relations
|
Phone:
|
|
|
(713) 369-9490
|
|
|
(713) 420-5855
|
E-mail:
|
|
|
kmp_ir@kindermorgan.com
|
|
|
investorrelations@elpaso.com
|
PARTICIPANTS IN THE SOLICITATION
KMI and EP, and their respective directors and executive officers, may
be deemed to be participants in the solicitation of proxies in respect
of the proposed transactions contemplated by the merger agreement.
Information regarding KMI's directors and executive officers is
contained in KMI's Form 10-K for the year ended December 31, 2010, which
has been filed with the SEC. Information regarding EP's directors and
executive officers is contained in EP's Form 10-K for the year ended
December 31, 2010 and its proxy statement dated March 29, 2011, which
are filed with the SEC. A more complete description will be available in
the Registration Statement and the Joint Proxy/Information
Statement/Prospectus.
SAFE HARBOR FOR FORWARD-LOOKING STATEMENTS
Statements in this document regarding the proposed transaction between
KMI and EP, the expected timetable for completing the proposed
transaction, future financial and operating results, benefits and
synergies of the proposed transaction, future opportunities for the
combined company, the sale of EP's exploration and production assets,
the possible drop-down of assets and any other statements about KMI or
EP managements' future expectations, beliefs, goals, plans or prospects
constitute forward looking statements within the meaning of the Private
Securities Litigation Reform Act of 1995. Any statements that are not
statements of historical fact (including statements containing the words
"believes," "plans," "anticipates," "expects," estimates and similar
expressions) should also be considered to be forward looking statements.
There are a number of important factors that could cause actual results
or events to differ materially from those indicated by such forward
looking statements, including: the ability to consummate the proposed
transaction; the ability to obtain the requisite regulatory, shareholder
approvals and the satisfaction of other conditions to consummation of
the transaction; the possibility that financing might not be available
on the terms committed; the ability to consummate contemplated asset
sales; the ability of KMI to successfully integrate EP's operations and
employees; the ability to realize anticipated synergies and cost
savings; the potential impact of announcement of the transaction or
consummation of the transaction on relationships, including with
employees, suppliers, customers and competitors; the ability to achieve
revenue growth; national, international, regional and local economic,
competitive and regulatory conditions and developments; technological
developments; capital and credit markets conditions; inflation rates;
interest rates; the political and economic stability of oil producing
nations; energy markets, including changes in the price of certain
commodities; weather conditions; environmental conditions; business and
regulatory or legal decisions; the pace of deregulation of retail
natural gas and electricity and certain agricultural products; the
timing and success of business development efforts; terrorism; and the
other factors described in KMI's and EP's Annual Reports on Form 10-K
for the year ended December 31, 2010 and their most recent quarterly
reports filed with the SEC. KMI and EP disclaim any intention or
obligation to update any forward looking statements as a result of
developments occurring after the date of this document.
Appendix to El Paso Corporation November 2, 2011 Earnings Press Release
A summary of reported financial results for the quarters and nine months
ended September 30, 2011 and 2010 is as follows:
Financial Results
|
|
|
Quarters Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
($ in millions, except per
|
|
|
|
|
|
|
|
|
|
|
|
|
share amounts)
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to
|
|
|
|
|
|
|
|
|
|
|
|
|
EPC
|
|
|
$
|
(368
|
)
|
|
|
$
|
142
|
|
|
$
|
(44
|
)
|
|
|
$
|
687
|
Preferred stock dividends
|
|
|
|
-
|
|
|
|
|
9
|
|
|
|
-
|
|
|
|
|
28
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to
|
|
|
|
|
|
|
|
|
|
|
|
|
EPC common stockholders
|
|
|
$
|
(368
|
)
|
|
|
$
|
133
|
|
|
$
|
(44
|
)
|
|
|
$
|
659
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic per common share amounts
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to
|
|
|
|
|
|
|
|
|
|
|
|
|
EPC common stockholders
|
|
|
$
|
(0.48
|
)
|
|
|
$
|
0.19
|
|
|
$
|
(0.06
|
)
|
|
|
$
|
0.95
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted per common share amounts
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributable to
|
|
|
|
|
|
|
|
|
|
|
|
|
EPC common stockholders
|
|
|
$
|
(0.48
|
)
|
|
|
$
|
0.19
|
|
|
$
|
(0.06
|
)
|
|
|
$
|
0.90
|
Items Impacting Quarterly Results
|
|
|
|
|
|
|
|
|
|
Third Quarter 2010
|
|
|
|
|
|
|
|
|
|
($ millions, except per share
|
|
|
|
|
|
|
|
|
|
amounts)
|
|
|
Before Tax
|
|
|
After Tax
|
|
|
Diluted EPS
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to EPC common
|
|
|
|
|
|
|
|
|
|
stockholders
|
|
|
|
|
|
$
|
133
|
|
|
|
$
|
0.19
|
|
Adjustments(1)
|
|
|
|
|
|
|
|
|
|
Impact of E&P financial
|
|
|
|
|
|
|
|
|
|
derivatives(2)
|
|
|
$
|
(94
|
)
|
|
|
$
|
(61
|
)
|
|
|
$
|
(0.08
|
)
|
Ceiling test charges - Egypt
|
|
|
|
14
|
|
|
|
|
14
|
|
|
|
|
0.02
|
|
Change in legacy derivative
|
|
|
|
|
|
|
|
|
|
contracts and other legacy items(3)
|
|
|
|
14
|
|
|
|
|
10
|
|
|
|
|
0.01
|
|
Loss on debt extinguishment
|
|
|
|
104
|
|
|
|
|
66
|
|
|
|
|
0.09
|
|
Tax benefit from liquidation of
|
|
|
|
|
|
|
|
|
|
foreign entities
|
|
|
|
-
|
|
|
|
|
(9
|
)
|
|
|
|
(0.01
|
)
|
Impact of estimated annual effective
|
|
|
|
|
|
|
|
|
|
tax rate(4)
|
|
|
|
-
|
|
|
|
|
2
|
|
|
|
|
-
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EPS(5)
|
|
|
|
|
|
|
|
|
$
|
0.22
|
|
(1) All individual adjustments assume a 36 percent statutory tax rate,
except for the ceiling test charges, and assume 762 million diluted
shares
(2) Includes $184 million of gains on financial derivatives, adjusted
for $90 million of cash settlement proceeds. Cash proceeds on
settlements do not reflect $48 million, or $0.04 per share, of option
premiums paid in 2009 for financial derivatives settled during the third
quarter 2010
(3) Legacy items consist of changes in the value of power contracts, an
environmental remediation reserve and the resolution of indemnifications
(4) Reflects the impact on quarterly earnings using the company's
current estimate of its overall annual effective tax rate including the
effects of adjustments
(5) Reflects fully diluted shares of 762 million and includes a $9
million income impact from dilutive securities
Items Impacting Nine Month Results
|
|
|
|
|
|
|
|
|
|
Nine Months Ended September 30, 2010
|
|
|
|
|
|
|
|
|
|
($ millions, except per share
|
|
|
|
|
|
|
|
|
|
amounts)
|
|
|
Before Tax
|
|
|
After Tax
|
|
|
Diluted EPS
|
|
|
|
|
|
|
|
|
|
|
Net income attributable to EPC common
|
|
|
|
|
|
|
|
|
|
stockholders
|
|
|
|
|
|
$
|
659
|
|
|
|
$
|
0.90
|
|
Adjustments(1)
|
|
|
|
|
|
|
|
|
|
Impact of E&P financial
|
|
|
|
|
|
|
|
|
|
derivatives(2)
|
|
|
$
|
(227
|
)
|
|
|
$
|
(146
|
)
|
|
|
$
|
(0.19
|
)
|
Ceiling test charges - Egypt
|
|
|
|
16
|
|
|
|
|
16
|
|
|
|
|
0.02
|
|
Change in legacy derivative
|
|
|
|
|
|
|
|
|
|
contracts and other legacy items(3)
|
|
|
|
25
|
|
|
|
|
17
|
|
|
|
|
0.02
|
|
Gain on sale of Mexican pipeline
|
|
|
|
|
|
|
|
|
|
assets
|
|
|
|
(80
|
)
|
|
|
|
(59
|
)
|
|
|
|
(0.08
|
)
|
Loss on debt extinguishment
|
|
|
|
104
|
|
|
|
|
66
|
|
|
|
|
0.09
|
|
Impact of heath care legislation
|
|
|
|
-
|
|
|
|
|
18
|
|
|
|
|
0.02
|
|
Tax benefit from liquidation of
|
|
|
|
|
|
|
|
|
|
foreign entities
|
|
|
|
-
|
|
|
|
|
(9
|
)
|
|
|
|
(0.01
|
)
|
Impact of estimated annual effective
|
|
|
|
|
|
|
|
|
|
tax rate(4)
|
|
|
|
-
|
|
|
|
|
(6
|
)
|
|
|
|
-
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted EPS(5)
|
|
|
|
|
|
|
|
|
$
|
0.77
|
|
(1) All individual adjustments assume a 36 percent statutory tax rate,
except for the ceiling test charges and gain on the sale of Mexican
pipeline assets, and assume 761 million diluted shares
(2) Includes $468 million of gains on financial derivatives, adjusted
for $241 million of cash settlement proceeds. Cash proceeds on
settlements do not reflect $148 million, or $0.12 per share, of option
premiums paid in 2009 for financial derivatives settled during the first
nine months of 2010
(3) Legacy items consist of changes in the value of power contracts, an
environmental remediation reserve and the resolution of indemnifications
(4) Reflects the impact on year-to-date earnings using the company's
current estimate of its overall annual effective tax rate including the
effects of adjustments
(5) Reflects fully diluted shares of 761 million and includes a $28
million income impact from dilutive securities
Reconciliation of Segment EBIT to Net Income (Loss)
|
|
|
|
Quarters Ended
|
|
|
Nine Months Ended
|
|
|
|
September 30,
|
|
|
September 30,
|
($ in millions)
|
|
|
2011
|
|
|
2010
|
|
|
2011
|
|
|
2010
|
Segment EBIT
|
|
|
$
|
(181
|
)
|
|
|
$
|
513
|
|
|
|
$
|
830
|
|
|
|
$
|
1,913
|
|
Interest and debt expense
|
|
|
|
(242
|
)
|
|
|
|
(255
|
)
|
|
|
|
(721
|
)
|
|
|
|
(782
|
)
|
Income tax benefit
|
|
|
|
|
|
|
|
|
|
|
|
|
(expense)
|
|
|
|
130
|
|
|
|
|
(75
|
)
|
|
|
|
73
|
|
|
|
|
(343
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
|
(293
|
)
|
|
|
|
183
|
|
|
|
|
182
|
|
|
|
|
788
|
|
Net income attributable
|
|
|
|
|
|
|
|
|
|
|
|
|
to noncontrolling
|
|
|
|
|
|
|
|
|
|
|
|
|
interests
|
|
|
|
(75
|
)
|
|
|
|
(41
|
)
|
|
|
|
(226
|
)
|
|
|
|
(101
|
)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
|
|
|
|
|
|
|
|
|
|
attributable to EPC
|
|
|
$
|
(368
|
)
|
|
|
$
|
142
|
|
|
|
$
|
(44
|
)
|
|
|
$
|
687
|
|
|
Reconciliation of Cash Operating Costs
|
|
|
|
Quarter Ended
|
|
|
Quarter Ended
|
|
|
|
September 30, 2011
|
|
|
September 30, 2010
|
|
|
|
|
|
|
Per Unit
|
|
|
|
|
|
Per Unit
|
|
|
|
Total ($MM)
|
|
|
($/Mcfe)
|
|
|
Total ($MM)
|
|
|
($/Mcfe)
|
Total operating expenses
|
|
|
$
|
463
|
|
|
|
$
|
6.56
|
|
|
|
$
|
254
|
|
|
|
$
|
3.93
|
|
Depreciation, depletion,
|
|
|
|
|
|
|
|
|
|
|
|
|
and amortization
|
|
|
|
(157
|
)
|
|
|
|
(2.22
|
)
|
|
|
|
(117
|
)
|
|
|
|
(1.81
|
)
|
Transportation costs
|
|
|
|
(20
|
)
|
|
|
|
(0.28
|
)
|
|
|
|
(18
|
)
|
|
|
|
(0.28
|
)
|
Ceiling test charges
|
|
|
|
(152
|
)
|
|
|
|
(2.15
|
)
|
|
|
|
(14
|
)
|
|
|
|
(0.22
|
)
|
Other
|
|
|
|
(6
|
)
|
|
|
|
(0.09
|
)
|
|
|
|
-
|
|
|
|
|
-
|
|
Total cash operating
|
|
|
|
|
|
|
|
|
|
|
|
|
costs and per unit
|
|
|
|
|
|
|
|
|
|
|
|
|
cash costs(1)
|
|
|
$
|
128
|
|
|
|
$
|
1.82
|
|
|
|
$
|
105
|
|
|
|
$
|
1.62
|
|
Total equivalent volumes
|
|
|
|
|
|
|
|
|
|
|
|
|
(MMcfe)(1)
|
|
|
|
|
|
|
70,598
|
|
|
|
|
|
|
|
64,575
|
|
(1) Excludes volumes and costs associated with equity investment in Four
Star