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 $1.4 billion
of Ruby debt is no longer included in El Paso's consolidated debt
and is recourse only to the project. In addition, the construction
guarantee for Ruby has been eliminated.
Quarters Ended
Pipeline Group Results September 30,
----------------------------
($ 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
Contacts Investor and Media Relations Bruce Connery Vice
President (713) 420-5855 Media Relations Bill Baerg Manager (713)
420-2906
El Paso (NYSE:EP)
Historical Stock Chart
From Jun 2024 to Jul 2024
El Paso (NYSE:EP)
Historical Stock Chart
From Jul 2023 to Jul 2024