TULSA, Okla., July 29 /PRNewswire-FirstCall/ -- Williams
Partners L.P. (NYSE: WPZ) today announced unaudited second-quarter
2010 net income of $225 million,
compared with second-quarter 2009 net income of $215 million. Net income per common
limited-partner unit for second-quarter 2010 was $0.66, compared with $0.48 per unit for second-quarter 2009.
Summary Financial
Information
|
2Q
|
|
YTD
|
|
Amounts in millions, except
per-unit amounts.
|
2010
|
|
2009
|
|
2010
|
|
2009
|
|
(Unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
$225
|
|
$215
|
|
$538
|
|
$398
|
|
Net income per common L.P.
unit
|
$0.66
|
|
$0.48
|
|
$1.24
|
|
$0.84
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributable cash flow (DCF)
(1)
|
$316
|
|
$312
|
|
$732
|
|
$611
|
|
Less: Pre-partnership DCF
(2)
|
-
|
|
(281)
|
|
(143)
|
|
(550)
|
|
DCF attributable to partnership
operations
|
$316
|
|
$31
|
|
$589
|
|
$61
|
|
|
|
|
|
|
|
|
|
|
Cash distribution coverage ratio
(1)
|
1.43x
|
|
0.92x
|
|
1.57x
|
|
0.90x
|
|
|
|
|
|
|
|
|
|
|
(1) Distributable Cash Flow and
Cash Distribution Coverage Ratio are non-GAAP measures.
Reconciliations to the most relevant measures included in
GAAP are attached to this news release.
|
|
(2) For 2010, this amount
represents DCF for the contributed assets for January 2010 as the
partnership received cash flows from the contributed assets
beginning Feb. 1, 2010. For 2009, this amount represents all
of the DCF for the contributed assets since this entire period was
prior to the receipt of cash flows from the contributed
assets.
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|
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Year-to-date through June 30,
Williams Partners reported net income of $538 million, compared with $398 million for the same period in 2009.
Net income per common LP unit for the first half of the year
was $1.24, compared with $0.84 per unit in the first half of 2009.
Higher natural gas liquid (NGL) margins in the midstream
business drove the increase in net income for the second-quarter
and year-to-date periods. Results from the gas pipeline business
were steady as expected in both periods. There is a more detailed
discussion of the midstream and gas pipeline business results in
the business segment performance section below. Higher
interest expense associated with the asset contribution
transactions with Williams (NYSE: WMB), which closed in the first
quarter, substantially offset the improved operating results in the
midstream business in the second quarter.
The results throughout this release have been recast to reflect
the first-quarter 2010 asset contribution transactions.
In the recasting of the partnership's net income, all of the
contributed assets' net income occurring prior to the closing date
was allocated to Williams.
Asset Contributions Continue to Drive Substantial Increases
in Distributable Cash Flow
For second-quarter 2010, Williams Partners' distributable cash
flow attributable to partnership operations was $316 million, compared with $31 million for second-quarter 2009.
Year-to-date through June 30,
DCF attributable to partnership operations was $589 million, compared with $61 million for the same period in 2009.
The continued substantial increases in DCF attributable to
partnership operations are due to the growth of the partnership via
the first-quarter 2010 asset contribution transactions.
Partnership to Increase Ownership in Overland Pass, Plans New
Cryogenic Processing Facility in Colorado
Last week Williams Partners announced that it had notified ONEOK
Partners, L.P. (NYSE: OKS) that it is exercising its option to
increase its ownership of Overland Pass Pipeline Company, LLC to 50
percent. Williams Partners currently owns 1 percent of the
joint venture, while ONEOK Partners owns the remaining 99
percent.
The previously announced option price is estimated to be
approximately $425 million.
Subject to regulatory approvals, Williams Partners expects to close
the transaction in the third quarter with an effective date of
June 30, 2010. Williams Partners
plans to fund the purchase price with a combination of cash on hand
and/or borrowings from its existing credit facility.
The Overland Pass Pipeline includes a 760-mile NGL pipeline from
Opal, Wyo., to the Mid-Continent
NGL market center in Conway, Kan.,
along with 150- and 125-mile extensions into the Piceance and
Denver-Joules Basins in Colorado,
respectively. Williams Partners' equity NGL volumes from its
two Wyoming plants and its Willow
Creek facility in Colorado are
dedicated for transport on Overland Pass Pipeline under a long-term
shipping agreement.
Williams Partners is also planning a significant expansion of
its cryogenic processing capacity in the Piceance Basin. The
partnership intends to pursue construction of a 450 MMcf/d
cryogenic gas processing facility to be located at the Williams
Parachute, Colo., complex.
The new facility will be capable of recovering up to 25,000
barrels per day of NGLs. The new Parachute facility is expected to be in
service in 2013 and will process Williams' natural gas production
in the Piceance Basin, which currently exceeds the processing
capacity at Williams Partners' Willow Creek facility. The
proposed expansion of the Parachute plant is subject to certain final
approvals.
CEO Perspective
"Williams Partners continued its strong 2010 performance in the
second quarter, as higher NGL margins in the midstream business
drove our improved operating results," said Steve Malcolm, chief executive officer of the
general partner of Williams Partners. "We increased our
distribution for the second consecutive quarter and our cash
distribution coverage ratio remained robust at 1.43x.
"We are also taking advantage of the size and scope of Williams
Partners in seizing strategic growth opportunities, such as
increasing our stake in Overland Pass and the new cryogenic
processing facility at the Parachute plant," Malcolm said.
"In addition to these growth projects, we continue to be
actively engaged in many business development opportunities."
Earnings Guidance Updated, Capital Expenditure Guidance
Increased
The chart below shows Williams Partners' 2010-12 commodity price
assumptions and the related outlook for its financial results for
2010-12. Earnings guidance for 2010 has been updated to
reflect lower expected NGL margins and the delay in the startup of
Perdido Norte. Earnings
guidance for 2011-12 is unchanged from previous guidance.
Capital expenditure guidance has been increased for 2010-11 to
reflect the partnership's acquisition of the Overland Pass interest
and its planned expansion project at the Parachute gas processing facility.
While these new investments will be contributing profitability
during the 2010-12 guidance period, the positive earnings effect
will be most significant after 2012. During the guidance
period, the partnership expects that profitability from the new
investments will be largely offset by other factors, including the
projected negative effect of a six-month moratorium on deepwater
drilling and delays in the startup of Perdido Norte.
Commodity Price Assumptions and
Average NGL Margins
|
|
2010
|
|
|
2011
|
|
|
2012
|
|
|
As of July 29,
2010
|
|
|
|
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|
|
|
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Low
|
Mid
|
High
|
Low
|
Mid
|
High
|
Low
|
Mid
|
High
|
|
Natural Gas
($/MMBtu):
|
|
|
|
|
|
|
|
|
|
|
NYMEX
|
$4.00
|
$4.50
|
$5.00
|
$4.50
|
$5.50
|
$6.50
|
$4.80
|
$5.95
|
$7.10
|
|
Rockies
|
$3.75
|
$4.20
|
$4.65
|
$4.25
|
$5.20
|
$6.15
|
$4.50
|
$5.60
|
$6.70
|
|
San Juan
|
$3.85
|
$4.35
|
$4.85
|
$4.35
|
$5.30
|
$6.25
|
$4.65
|
$5.75
|
$6.85
|
|
|
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|
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|
Oil / NGL:
|
|
|
|
|
|
|
|
|
|
|
Crude Oil - WTI ($
per barrel)
|
$70
|
$77.50
|
$85
|
$71
|
$86
|
$101
|
$72
|
$87
|
$102
|
|
Crude to Gas
Ratio
|
17.0x
|
17.3x
|
17.5x
|
15.5x
|
15.7x
|
15.8x
|
14.4x
|
14.7x
|
15.0x
|
|
NGL to Crude Oil
Relationship (1)
|
54%
|
54%
|
54%
|
53%
|
54%
|
55%
|
52%
|
54%
|
55%
|
|
|
|
|
|
|
|
|
|
|
|
|
Average NGL Margins ($ per
gallon)
|
$0.50
|
$0.58
|
$0.65
|
$0.51
|
$0.65
|
$0.78
|
$0.47
|
$0.60
|
$0.72
|
|
|
|
|
|
|
|
|
|
|
|
|
Williams Partners
Guidance
|
|
|
|
|
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|
|
|
|
Amounts are in millions except
coverage ratio.
|
|
|
|
|
|
|
|
|
|
|
|
Low
|
Mid
|
High
|
Low
|
Mid
|
High
|
Low
|
Mid
|
High
|
|
DCF attributable to partnership
ops. (2) (3)
|
$1,025
|
$1,150
|
$1,275
|
$1,200
|
$1,438
|
$1,675
|
$1,300
|
$1,525
|
$1,750
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Cash Distribution
(3)
|
$846
|
$846
|
$846
|
TBD
|
TBD
|
TBD
|
TBD
|
TBD
|
TBD
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash Distribution Coverage Ratio
(2) (3)
|
1.2x
|
1.4x
|
1.5x
|
1.3x
|
1.5x
|
1.8x
|
1.4x
|
1.6x
|
1.8x
|
|
|
|
|
|
|
|
|
|
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|
|
Recurring Segment
Profit:
|
|
|
|
|
|
|
|
|
|
|
Gas
Pipeline
|
$610
|
$635
|
$660
|
$650
|
$670
|
$690
|
$700
|
$720
|
$740
|
|
Midstream
|
775
|
888
|
1,000
|
800
|
1,025
|
1,250
|
825
|
1,050
|
1,275
|
|
Total Recurring Segment Profit
(2)
|
$1,385
|
$1,523
|
$1,660
|
$1,450
|
$1,695
|
$1,940
|
$1,525
|
$1,770
|
$2,015
|
|
|
|
|
|
|
|
|
|
|
|
|
Recurring Segment Profit +
DD&A:
|
|
|
|
|
|
|
|
|
|
|
Gas
Pipeline
|
$950
|
$985
|
$1,020
|
$1,000
|
$1,030
|
$1,060
|
$1,060
|
$1,090
|
$1,120
|
|
Midstream
|
990
|
1,113
|
1,235
|
1,035
|
1,270
|
1,505
|
1,060
|
1,295
|
1,530
|
|
Total Recurring Segment Profit +
DD&A
|
$1,940
|
$2,098
|
$2,255
|
$2,035
|
$2,300
|
$2,565
|
$2,120
|
$2,385
|
$2,650
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital Expenditures:
|
|
|
|
|
|
|
|
|
|
|
Maintenance
|
$315
|
$335
|
$355
|
$355
|
$390
|
$425
|
$310
|
$370
|
$430
|
|
Growth
|
1,095
|
1,210
|
1,325
|
475
|
615
|
755
|
495
|
610
|
725
|
|
Total Capital
Expenditures
|
$1,410
|
$1,545
|
$1,680
|
$830
|
$1,005
|
$1,180
|
$805
|
$980
|
$1,155
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) This is calculated as the
price of natural gas liquids as a percentage of the price of crude
oil on an equal volume basis.
|
|
(2) Distributable Cash Flow,
Cash Distribution Coverage Ratio and Recurring Segment Profit are
non-GAAP measures. Reconciliations to the most relevant
measures included in GAAP are attached to this news release.
Also, the Cash Distribution Coverage ratio in the chart for
2011-12 is based on the Cash Distribution per LP unit level for 2Q
2010 of $0.6725 per quarter.
|
|
(3) For 2010, this amount
includes distributable cash flow and total cash distributions for
the contributed assets for the period Feb. 1 through Dec. 31.
These numbers also assume cash distributions at the current
per-unit level.
|
|
|
|
|
|
|
|
|
|
|
|
Business Segment Performance
Williams Partners' operations are reported through two business
segments, Gas Pipeline and Midstream Gas & Liquids.
Gas Pipeline includes the partnership's interstate natural gas
pipelines and pipeline joint venture investments. Gas Pipeline also
includes the partnership's ownership interest in Williams Pipeline
Partners L.P. (NYSE: WMZ), a gas-pipeline focused master limited
partnership formed in 2007. Midstream Gas & Liquids
includes the partnership's natural gas gathering, treating and
processing business and is comprised of several wholly-owned and
partially-owned subsidiaries.
Consolidated Segment
Profit
|
2Q
|
|
YTD
|
|
Amounts in
millions
|
2010
|
|
2009
|
|
2010
|
|
2009
|
|
|
|
|
|
|
|
|
|
|
Gas Pipeline
|
$148
|
|
$155
|
|
$317
|
|
$327
|
|
Midstream Gas &
Liquids
|
198
|
|
130
|
|
443
|
|
210
|
|
Total Segment Profit
|
$346
|
|
$285
|
|
$760
|
|
$537
|
|
|
|
|
|
|
|
|
|
|
Non-recurring items
|
(16)
|
|
-
|
|
(21)
|
|
1
|
|
|
|
|
|
|
|
|
|
|
Recurring Segment
Profit*
|
$330
|
|
$285
|
|
$739
|
|
$538
|
|
|
|
|
|
|
|
|
|
|
* A schedule
reconciling segment profit to recurring
segment profit is attached to this press release.
|
|
|
|
|
|
|
|
|
|
Gas Pipeline
Williams Partners owns interests in three major interstate
natural gas pipeline systems – Transco, Northwest Pipeline and
Gulfstream. Transco and Northwest Pipeline have a combined total
annual throughput of approximately 2,700 trillion British Thermal
Units of natural gas, which is approximately 12 percent of the
natural gas consumed in the United
States. Combined peak-day delivery capacity is approximately
12 billion cubic feet per day.
Gas Pipeline reported segment profit of $148 million for second-quarter 2010, compared
with $155 million for second-quarter
2009.
For the first six months of 2010, Gas Pipeline reported segment
profit of $317 million, compared with
$327 million for the first six months
of 2009.
The slight declines in segment profit during second-quarter and
year-to-date 2010 periods were due to decreases in other service
revenues, partially offset by an increase in transportation
revenues from expansion projects placed into service during 2009.
The gas pipeline business has a significant portfolio of
expansion projects to expand its services to key markets over the
next several years. Among those are the Mobile Bay South and
85 North expansions, which were recently placed into service.
The Sundance Trail expansion is also expected to be placed
into service during 2010.
The Mobile Bay South expansion includes a new compression
facility in Alabama allowing
natural gas pipeline transportation service to various southbound
delivery points. The cost of the project is estimated to be
$34 million. The expansion was placed
into service in May 2010, increasing
capacity by 253 Mdt/d.
The 85 North project is an expansion of the partnership's
existing natural gas transmission system from Alabama to various delivery points as far
north as North Carolina. The cost
of the project is estimated to be $241
million. Phase I was placed into service in July 2010 and increased capacity by 90 Mdt/d. A
second phase is expected to be placed into service in 2011 and will
increase capacity by an additional 218
Mdt/d.
Sundance Trail includes
approximately 16 miles of 30-inch pipeline between the
partnership's existing compressor stations in Wyoming. The project also includes an upgrade
to an existing compressor station and is estimated to cost
approximately $60 million. The
estimated in-service date is November
2010 and will increase capacity by 150 Mdt/d.
Midstream Gas & Liquids
Midstream provides natural gas gathering, treating, and
processing; deepwater production handling and oil transportation;
and NGL fractionation and storage services.
The business reported segment profit of $198 million for second-quarter 2010, compared
with segment profit of $130 million
for second-quarter 2009.
The 52-percent increase in segment profit during second-quarter
2010 is primarily the result of higher per-unit NGL margins
compared with the recession-driven, low NGL margins in
second-quarter 2009. Higher average NGL prices, partially
offset by higher natural gas prices, drove the increase in per-unit
NGL margins.
Year-to-date through June 30,
Midstream reported segment profit of $443
million, compared with $210
million for the same period in 2009.
The significant increase in year-to-date segment profit is due
to much higher per-unit NGL margins in 2010 compared with 2009.
Average per-unit NGL margins for the first six months of 2010 were
$0.57 per gallon – more than double
the average per-unit NGL margin of $0.27 per gallon for the same period in 2009.
NGL Margin Trend
|
2009
|
|
2010
|
|
|
1Q
|
2Q
|
3Q
|
4Q
|
|
1Q
|
2Q
|
|
|
|
|
|
|
|
|
|
|
NGL margins
(millions)
|
$58
|
$103
|
$142
|
$169
|
|
$193
|
$166
|
|
|
|
|
|
|
|
|
|
|
NGL equity volumes (gallons in
millions)
|
292
|
298
|
317
|
314
|
|
332
|
302
|
|
|
|
|
|
|
|
|
|
|
Per-unit NGL margins
($/gallon)
|
$0.20
|
$0.35
|
$0.45
|
$0.54
|
|
$0.58
|
$0.55
|
|
|
|
|
|
|
|
|
|
The decline in NGL margins from the first quarter to second
quarter of 2010 is due primarily to lower equity sales volumes and
lower NGL prices, partially offset by lower per-unit gas prices.
Equity sales volumes declined 9 percent in the same period,
including the effects of timing of inventory sales, while total NGL
production volumes declined 3 percent, including the effects of
certain deepwater well shut-ins.
Fee-based revenues at the Willow Creek plant, which began
processing Williams' natural gas production in the Piceance Basin
in third-quarter 2009, are also higher for the first six months of
2010. This increase is partially offset by lower deepwater
gathering and transportation volumes.
In addition to those mentioned earlier in this news release, the
midstream business continues to make progress on a number of
organic expansion projects during 2010 and to pursue certain
expansion and growth opportunities in its onshore and Gulf of Mexico businesses.
Progress continues on Williams Partners' major expansion
projects including additional processing and NGL production
facilities at the Echo Springs facility and related gathering
system expansions in the Wamsutter
area of Wyoming; a gas gathering
pipeline in the Marcellus Shale region and additions to the
gathering system infrastructure within the partnership's Laurel
Mountain Midstream joint venture.
Definitions of Non-GAAP Financial Measures
This press release includes certain financial measures,
Recurring Segment Profit and Distributable Cash Flow that are
non-GAAP financial measures as defined under the rules of the
Securities and Exchange Commission.
For Williams Partners L.P., Recurring Segment Profit excludes
items of income or loss that we characterize as unrepresentative of
our ongoing operations. Management believes Recurring Segment
Profit provides investors meaningful insight into Williams Partners
L.P.'s results from ongoing operations.
For Williams Partners L.P. we define Distributable Cash Flow as
net income plus depreciation, amortization and accretion and cash
distributions from our equity investments less our earnings from
our equity investments, distributions to noncontrolling interests
and maintenance capital expenditures. We also adjust for payments
and/or reimbursements under an omnibus agreement with Williams and
certain non-cash, non-recurring items. Total Distributable Cash
Flow is reduced by any amounts associated with operations, which
occurred prior to our ownership of the underlying assets to arrive
at Distributable Cash Flow attributable to partnership
operations.
For Williams Partners L.P. we also calculate the ratio of
Distributable Cash Flow attributable to partnership operations to
the total cash distributed (cash distribution coverage ratio). This
measure reflects the amount of Distributable Cash Flow relative to
our cash distribution. We have also provided this ratio calculated
using the most directly comparable GAAP measure, net income.
This press release is accompanied by a reconciliation of these
non-GAAP financial measures to their nearest GAAP financial
measures. Management uses these financial measures because they are
accepted financial indicators used by investors to compare company
performance. In addition, management believes that these measures
provide investors an enhanced perspective of the operating
performance of the Partnership's assets and the cash that the
business is generating. Neither Recurring Segment Profit nor
Distributable Cash Flow are intended to represent cash flows for
the period, nor are they presented as an alternative to net income
or cash flow from operations. They should not be considered in
isolation or as substitutes for a measure of performance prepared
in accordance with United States
generally accepted accounting principles.
Today's Analyst Call
Management will discuss the second-quarter results and outlook
during a live webcast beginning at 11 a.m.
EDT today. Participants are encouraged to access the webcast
and slides for viewing, downloading and printing at
www.williamslp.com.
A limited number of phone lines also will be available at (888)
634-7543. International callers should dial (719) 325-2269. Replays
of the second-quarter webcast in both streaming and downloadable
podcast formats will be available for two weeks following the event
at www.williamslp.com.
Form 10-Q
The partnership plans to file its Form 10-Q with the Securities
and Exchange Commission today. The document will be available on
both the SEC and Williams Partners web sites.
About Williams Partners L.P. (NYSE: WPZ)
Williams Partners L.P. is a leading diversified master limited
partnership focused on natural gas transportation; gathering,
treating, and processing; storage; natural gas liquid (NGL)
fractionation; and oil transportation. The partnership owns
interests in three major interstate natural gas pipelines that,
combined, deliver 12 percent of the natural gas consumed in
the United States. The
partnership's gathering and processing assets include large-scale
operations in the U.S. Rocky Mountains and both onshore and
offshore along the Gulf of Mexico.
Williams (NYSE: WMB) owns approximately 84 percent of Williams
Partners, including the general-partner interest. More information
is available at www.williamslp.com. Go to
http://www.b2i.us/irpass.asp?BzID=1296&to=ea&s=0 or
http://www.b2i.us/irpass.asp?BzID=1296&to=ea&s=0 to join
our email list.
Williams Partners L.P. is a limited partnership formed by The
Williams Companies, Inc. (Williams). Our reports, filings, and
other public announcements may contain or incorporate by reference
statements that do not directly or exclusively relate to historical
facts. Such statements are "forward-looking statements" within the
meaning of Section 27A of the Securities Act of 1933, as amended,
and Section 21E of the Securities Exchange Act of 1934, as amended.
You typically can identify forward-looking statements by
various forms of words such as "anticipates," "believes," "seeks,"
"could," "may," "should," "continues," "estimates," "expects,"
"forecasts," "intends," "might," "goals," "objectives," "targets,"
"planned," "potential," "projects," "scheduled," "will," or other
similar expressions. These forward-looking statements are based on
management's beliefs and assumptions and on information currently
available to management and include, among others, statements
regarding:
- Amounts and nature of future capital expenditures;
- Expansion and growth of our business and
operations;
- Financial condition and liquidity;
- Business strategy;
- Cash flow from operations or results of operations;
- The levels of cash distributions to unitholders;
- Seasonality of certain business segments; and
- Natural gas and natural gas liquids prices and
demand.
Forward-looking statements are based on numerous assumptions,
uncertainties and risks that could cause future events or results
to be materially different from those stated or implied in this
announcement. Many of the factors that will determine these results
are beyond our ability to control or predict. Specific factors that
could cause actual results to differ from results contemplated by
the forward-looking statements include, among others, the
following:
- Whether we have sufficient cash from operations to enable us
to maintain current levels of cash distributions or to pay the
minimum quarterly distribution following establishment of cash
reserves and payment of fees and expenses, including payments to
our general partner;
- Availability of supplies (including the uncertainties
inherent in assessing and estimating future natural gas reserves),
market demand, volatility of prices, and the availability and cost
of capital;
- Inflation, interest rates and general economic conditions
(including future disruptions and volatility in the global credit
markets and the impact of these events on our customers and
suppliers);
- The strength and financial resources of our
competitors;
- Development of alternative energy sources;
- The impact of operational and development hazards;
- Costs of, changes in, or the results of laws, government
regulations (including proposed climate change legislation and/or
potential additional regulation of drilling and completion of
wells), environmental liabilities, litigation and rate
proceedings;
- Our allocated costs for defined benefit pension plans and
other postretirement benefit plans sponsored by our
affiliates;
- Changes in maintenance and construction costs;
- Changes in the current geopolitical situation;
- Our exposure to the credit risks of our customers;
- Risks related to strategy and financing, including
restrictions stemming from our debt agreements, future changes in
our credit ratings and the availability and cost of
credit;
- Risks associated with future weather conditions;
- Acts of terrorism; and
- Additional risks described in our filings with the
Securities and Exchange Commission (SEC).
Given the uncertainties and risk factors that could cause our
actual results to differ materially from those contained in any
forward-looking statement, we caution investors not to unduly rely
on our forward-looking statements. We disclaim any obligations to
and do not intend to update the above list or to announce publicly
the result of any revisions to any of the forward-looking
statements to reflect future events or developments.
In addition to causing our actual results to differ, the
factors listed above may cause our intentions to change from those
statements of intention set forth in this report. Such changes in
our intentions may also cause our results to differ. We may change
our intentions, at any time and without notice, based upon changes
in such factors, our assumptions, or otherwise.
Limited partner interests are inherently different from the
capital stock of a corporation, although many of the business risks
to which we are subject are similar to those that would be faced by
a corporation engaged in a similar business. Investors are urged to
closely consider the disclosures and risk factors in our annual
report on Form 10-K filed with the SEC on February 25, 2010,
and our quarterly reports on Form 10-Q available from our offices
or from our website at www.williamslp.com.
|
|
MEDIA CONTACT:
|
INVESTOR
CONTACTS:
|
|
|
|
Jeff Pounds
(918) 573-3332
|
Travis Campbell
(918) 573-2944
|
Sharna Reingold
(918) 573-2078
|
David Sullivan
(918) 573-9360
|
|
|
|
|
|
|
|
(UNAUDITED)
|
|
This press release includes
certain financial measures, Recurring Segment Profit and
Distributable Cash Flow, that are non-GAAP financial measures as
defined under the rules of the Securities and Exchange
Commission.
|
|
|
|
For Williams Partners L.P.,
Recurring Segment Profit excludes items of income or loss that we
characterize as unrepresentative of our ongoing operations.
Management believes Recurring Segment Profit provides
investors meaningful insight into Williams Partners L.P.'s results
from ongoing operations.
|
|
|
|
For Williams Partners L.P. we
define Distributable Cash Flow as net income plus depreciation,
amortization and accretion and cash distributions from our equity
investments less our earnings from equity investments,
distributions to noncontrolling interests and maintenance capital
expenditures. We also adjust for payments and/or
reimbursements under an omnibus agreement with Williams and certain
non-cash, non-recurring items. Total Distributable Cash Flow
is reduced by any amounts associated with operations, which
occurred prior to our ownership of the underlying assets to arrive
at Distributable Cash Flow attributable to partnership
operations.
|
|
|
|
For Williams Partners L.P. we
also calculate the ratio of Distributable Cash Flow attributable to
partnership operations to the total cash distributed (cash
distribution coverage ratio). This measure reflects the
amount of Distributable Cash Flow relative to our cash
distribution. We have also provided this ratio calculated
using the most directly comparable GAAP measure, net
income.
|
|
|
|
This press release is
accompanied by a reconciliation of these non-GAAP financial
measures to their nearest GAAP financial measures. Management
uses these financial measures because they are accepted financial
indicators used by investors to compare company performance.
In addition, management believes that these measures provide
investors an enhanced perspective of the operating performance of
the Partnership’s assets and the cash that the business is
generating. Neither Recurring Segment Profit nor
Distributable Cash Flow are intended to represent cash flows for
the period, nor are they presented as an alternative to net income
or cash flow from operations. They should not be considered
in isolation or as substitutes for a measure of performance
prepared in accordance with United States generally accepted
accounting principles.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2009 (a)
|
|
2010
|
|
(Millions)
|
1st Qtr
|
2nd Qtr
|
3rd Qtr
|
4th Qtr
|
Full
Year
|
|
1st Qtr
|
2nd Qtr
|
Year
|
|
|
|
|
|
|
|
|
|
|
|
|
Williams Partners
L.P.
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of Non-GAAP
"Distributable Cash Flow" to GAAP "Net income"
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
$183
|
$215
|
$279
|
$354
|
$1,031
|
|
$313
|
$225
|
$538
|
|
Depreciation and
amortization
|
131
|
131
|
133
|
136
|
531
|
|
134
|
134
|
268
|
|
Non-cash amortization of debt
issuance costs included in interest expense
|
2
|
3
|
2
|
3
|
10
|
|
4
|
5
|
9
|
|
Equity earnings from
investments
|
(5)
|
(16)
|
(30)
|
(30)
|
(81)
|
|
(26)
|
(27)
|
(53)
|
|
Distributions to noncontrolling
interests
|
(6)
|
(6)
|
(6)
|
(6)
|
(24)
|
|
(6)
|
(6)
|
(12)
|
|
Gain on sale of
assets
|
-
|
-
|
-
|
(40)
|
(40)
|
|
-
|
-
|
-
|
|
Involuntary conversion gain
resulting from Ignacio fire
|
1
|
-
|
(5)
|
-
|
(4)
|
|
-
|
(4)
|
(4)
|
|
Involuntary conversion gain
resulting from Hurricane Ike
|
-
|
-
|
-
|
-
|
-
|
|
-
|
(7)
|
(7)
|
|
Reimbursements (payments)
from/(to) Williams under omnibus agreement
|
-
|
1
|
1
|
-
|
2
|
|
-
|
(1)
|
(1)
|
|
Maintenance capital
expenditures
|
(15)
|
(31)
|
(103)
|
(109)
|
(258)
|
|
(32)
|
(46)
|
(78)
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributable Cash Flow
excluding equity investments
|
291
|
297
|
271
|
308
|
1,167
|
|
387
|
273
|
660
|
|
Plus: Equity investments cash
distributions to Williams Partners L.P.
|
8
|
15
|
27
|
37
|
87
|
|
29
|
43
|
72
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributable Cash
Flow
|
299
|
312
|
298
|
345
|
1,254
|
|
416
|
316
|
732
|
|
Less: Pre-partnership
Distributable Cash Flow
|
269
|
281
|
236
|
277
|
1,063
|
|
143
|
-
|
143
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributable cash flow
attributable to partnership operations
|
$30
|
$31
|
$62
|
$68
|
$191
|
|
$273
|
$316
|
$589
|
|
|
|
|
|
|
|
|
|
|
|
|
Total cash
distributed:
|
$34
|
$34
|
$34
|
$34
|
$137
|
|
$155
|
$221
|
$376
|
|
|
|
|
|
|
|
|
|
|
|
|
Coverage ratios:
|
|
|
|
|
|
|
|
|
|
|
Distributable cash flow
attributable to partnership operations divided by Total cash
distributed
|
0.88
|
0.92
|
1.80
|
1.97
|
1.39
|
|
1.76
|
1.43
|
1.57
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income divided by Total cash
distributed
|
5.35
|
6.32
|
8.16
|
10.35
|
7.55
|
|
2.02
|
1.02
|
1.43
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) Amounts reported above
for 2009 have been recast to reflect the impact of the February
2010 dropdown of certain assets from The Williams Companies to
Williams Partners L.P.
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of GAAP "Segment
Profit" to Non-GAAP "Recurring Segment Profit"
|
|
(UNAUDITED)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2009*
|
|
2010
|
|
(Dollars in
millions)
|
1st Qtr
|
|
2nd Qtr
|
|
3rd Qtr
|
|
4th Qtr
|
|
Year
|
|
1st Qtr
|
|
2nd Qtr
|
|
Year
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas Pipeline
|
$ 172
|
|
$ 155
|
|
$ 148
|
|
$ 160
|
|
$ 635
|
|
$ 169
|
|
$ 148
|
|
$ 317
|
|
Midstream Gas &
Liquids
|
80
|
|
130
|
|
199
|
|
264
|
|
673
|
|
245
|
|
198
|
|
443
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment Profit
|
$ 252
|
|
$ 285
|
|
$ 347
|
|
$ 424
|
|
$ 1,308
|
|
$ 414
|
|
$ 346
|
|
$ 760
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Nonrecurring
items:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas Pipeline
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Unclaimed property
assessment accrual - TGPL
|
-
|
|
-
|
|
-
|
|
3
|
|
3
|
|
-
|
|
(1)
|
|
(1)
|
|
Unclaimed property
assessment accrual - NWP
|
-
|
|
-
|
|
-
|
|
1
|
|
1
|
|
-
|
|
(1)
|
|
(1)
|
|
Gain on sale of base gas
from Hester storage field
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
(5)
|
|
(3)
|
|
(8)
|
|
Total Gas Pipeline nonrecurring
items
|
-
|
|
-
|
|
-
|
|
4
|
|
4
|
|
(5)
|
|
(5)
|
|
(10)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Midstream Gas &
Liquids
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Involuntary conversion
gain related to Ignacio
|
1
|
|
-
|
|
(5)
|
|
-
|
|
(4)
|
|
-
|
|
(4)
|
|
(4)
|
|
Involuntary conversion
gain related to Hurricane Ike
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
(7)
|
|
(7)
|
|
Gain on sale of Cameron
Meadows
|
-
|
|
-
|
|
-
|
|
(40)
|
|
(40)
|
|
-
|
|
-
|
|
-
|
|
Restructuring transaction
costs
|
-
|
|
-
|
|
-
|
|
1
|
|
1
|
|
-
|
|
-
|
|
-
|
|
Total Midstream Gas &
Liquids nonrecurring items
|
1
|
|
-
|
|
(5)
|
|
(39)
|
|
(43)
|
|
-
|
|
(11)
|
|
(11)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total nonrecurring items
included in segment profit
|
1
|
|
-
|
|
(5)
|
|
(35)
|
|
(39)
|
|
(5)
|
|
(16)
|
|
(21)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Recurring segment
profit
|
$ 253
|
|
$ 285
|
|
$ 342
|
|
$ 389
|
|
$ 1,269
|
|
$ 409
|
|
$ 330
|
|
$ 739
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Amounts reported above for
2009 have been recast to reflect the
impact of the February 2010 dropdown of certain assets from The
Williams Companies to Williams Partners L.P.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Williams Partners
L.P.
|
|
(UNAUDITED)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Full Year Forecasted
2010
|
|
Full Year Forecasted
2011
|
|
Full Year Forecasted
2012
|
|
(Millions)
|
Low
|
|
Midpoint
|
|
High
|
|
Low
|
|
Midpoint
|
|
High
|
|
Low
|
|
Midpoint
|
|
High
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of Non-GAAP
"Distributable Cash Flow attributable to partnership operations" to
GAAP "Net income"
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
$ 925
|
|
$ 1,063
|
|
$ 1,200
|
|
$ 940
|
|
$ 1,195
|
|
$ 1,450
|
|
$ 1,025
|
|
$ 1,288
|
|
$ 1,550
|
|
Depreciation and
amortization
|
555
|
|
575
|
|
595
|
|
585
|
|
605
|
|
625
|
|
595
|
|
615
|
|
635
|
|
Other
|
(140)
|
|
(153)
|
|
(165)
|
|
30
|
|
28
|
|
25
|
|
(10)
|
|
(8)
|
|
(5)
|
|
Maintenance capital
expenditures
|
(315)
|
|
(335)
|
|
(355)
|
|
(355)
|
|
(390)
|
|
(425)
|
|
(310)
|
|
(370)
|
|
(430)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributable cash flow
attributable to partnership operations
|
$ 1,025
|
|
$ 1,150
|
|
$ 1,275
|
|
$ 1,200
|
|
$ 1,438
|
|
$ 1,675
|
|
$ 1,300
|
|
$ 1,525
|
|
$ 1,750
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total cash to be
distributed
|
$ 846
|
|
$ 846
|
|
$ 846
|
|
TBD
|
|
TBD
|
|
TBD
|
|
TBD
|
|
TBD
|
|
TBD
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Coverage ratios:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributable cash flow
attributable to partnership operations divided by Total cash
distributed *
|
1.2
|
|
1.4
|
|
1.5
|
|
1.3
|
|
1.5
|
|
1.8
|
|
1.4
|
|
1.6
|
|
1.8
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income divided by Total cash
distributed *
|
1.1
|
|
1.3
|
|
1.4
|
|
1.0
|
|
1.3
|
|
1.5
|
|
1.1
|
|
1.4
|
|
1.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Calculations based on
announced current 2010 cash distribution amount of $.6725/per
unit.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Reconciliation of Non-GAAP
"Recurring Segment Profit" to GAAP "Segment Profit"
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Segment Profit:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Midstream
|
$ 786
|
|
$ 899
|
|
$ 1,011
|
|
$ 800
|
|
$ 1,025
|
|
$ 1,250
|
|
$ 825
|
|
$ 1,050
|
|
$ 1,275
|
|
Gas Pipeline
|
620
|
|
645
|
|
670
|
|
650
|
|
670
|
|
690
|
|
700
|
|
720
|
|
740
|
|
Total Segment Profit
|
1,406
|
|
1,544
|
|
1,681
|
|
1,450
|
|
1,695
|
|
1,940
|
|
1,525
|
|
1,770
|
|
2,015
|
|
Nonrecurring items:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gas Pipeline - Gain on
sale of Hester gas
|
(8)
|
|
(8)
|
|
(8)
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
Gas Pipeline - Unclaimed
property assessment accrual
|
(2)
|
|
(2)
|
|
(2)
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
Midstream - Involuntary
conversion gain related to Ignacio
|
(4)
|
|
(4)
|
|
(4)
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
Midstream - Involuntary
conversion gain related to Hurricane Ike
|
(7)
|
|
(7)
|
|
(7)
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
-
|
|
Recurring segment
profit
|
$ 1,385
|
|
$ 1,523
|
|
$ 1,660
|
|
$ 1,450
|
|
$ 1,695
|
|
$ 1,940
|
|
$ 1,525
|
|
$ 1,770
|
|
$ 2,015
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
SOURCE Williams Partners L.P.