e8vk
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
Date of Report (Date of earliest event reported)
May 7, 2009
TARGA RESOURCES PARTNERS LP
(Exact name of registrant as specified in its charter)
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Delaware
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001-33303
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65-1295427 |
(State or other jurisdiction
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(Commission
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(IRS Employer |
of incorporation or organization)
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File Number)
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Identification No.) |
1000 Louisiana, Suite 4300
Houston, TX 77002
(Address of principal executive office and Zip Code)
(713) 584-1000
(Registrants telephone number, including area code)
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the
filing obligation of the registrant under any of the following provisions:
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Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) |
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Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) |
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Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR
240.14d-2(b)) |
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Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR
240.13e-4(c)) |
Item 2.02 Results of Operations and Financial Condition.
On May 7, 2009, Targa Resources Partners LP (the Partnership) issued a press release
regarding its financial results for the three months ended March 31, 2009. A conference call to
discuss these results is scheduled for 11:00 a.m. Eastern time on Thursday, May 7, 2009. The
conference call will be webcast live and a replay of the webcast will be available through the
Investors section of the Partnerships web site (http://www.targaresources.com) until May
21, 2009. A copy of the earnings press release is furnished as Exhibit 99.1 to this report, which
is hereby incorporated by reference into this Item 2.02.
The press release and accompanying schedules and/or the conference call discussions include
the non-generally accepted accounting principles, or non-GAAP, financial measures of distributable
cash flow, operating margin and Adjusted EBITDA. The press release provides reconciliations of
these non-GAAP financial measures to their most directly comparable financial measure calculated
and presented in accordance with generally accepted accounting principles in the United States of
America (GAAP). Our non-GAAP financial measures should not be considered as alternatives to GAAP
measures such as net cash provided by operating activities, net income (loss) or any other GAAP
measure of liquidity or financial performance.
Item 9.01 Financial Statements and Exhibits.
(d) Exhibits
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Exhibit |
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Number |
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Description |
Exhibit 99.1
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Targa Resources Partners LP Press Release dated May 7, 2009. |
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly
caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
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TARGA RESOURCES PARTNERS LP |
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By:
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Targa Resources GP LLC,
its general partner |
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Dated: May 7, 2009
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By:
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/s/ Jeffrey J. McParland |
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Jeffrey J. McParland
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Executive Vice President and Chief Financial Officer |
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EXHIBIT INDEX
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Exhibit |
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Number |
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Description |
Exhibit 99.1
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Targa Resources Partners LP Press Release dated May 7, 2009. |
exv99w1
Exhibit 99.1
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1000 Louisiana, Suite 4300
Houston, TX 77002
713.584.1000
www.targaresources.com |
Targa Resources Partners LP Reports First Quarter 2009 Financial Results
HOUSTON May 7, 2009 -Targa Resources Partners LP (Targa Resources Partners or the
Partnership) (NASDAQ: NGLS) today reported a $2.1 million net loss for the first quarter 2009
(which includes an $18.5 million non-cash hedge loss), or $0.09 loss per diluted limited partner
unit as compared to net income of $24.9 million, or $0.50 per diluted limited partner unit for the
first quarter of 2008. The Partnership reported earnings before interest, income taxes,
depreciation and amortization and non-cash income or loss related to derivative instruments
(Adjusted EBITDA) of $45.5 million for the first quarter of 2009 compared to Adjusted EBITDA of
$52.6 million for the first quarter of 2008.
Distributable cash flow for the first quarter of 2009 was $33.6 million which corresponds to
distribution coverage of approximately 1.3 times for the 47.2 million total units outstanding on
March 31, 2009 (see the section of this release entitled Non-GAAP Financial Measures for a
discussion of Adjusted EBITDA, operating margin and distributable cash flow, and reconciliations of
such measures to the comparable GAAP measures).
The strong performance of our operations combined with our cost control efforts and hedge program
result in strong distribution coverage for the first quarter. These efforts along with our quarter
end liquidity of approximately $400 million and discipline regarding capital expenditures position
us to bridge the time required to determine what the long-term operating environment looks like for
our business, said Rene Joyce, Chief Executive Officer of the Partnerships general partner and of
Targa Resources, Inc. (Targa).
On April 23, 2009, the Partnership announced a cash distribution of 51.75¢ per common and
subordinated unit, or $2.07 per unit on an annualized basis, for the first quarter of 2009. This
cash distribution will be paid May 15, 2009 on all outstanding common and subordinated units to
holders of record as of the close of business on May 6, 2009. The distribution was equal to the
previous quarters distribution and reflects an increase of approximately 24% over the distribution
for the first quarter of 2008.
Review of First Quarter Results
Net loss for the first quarter of 2009 was $2.1 million compared to $24.9 million of net income for
the 2008 period. The decrease in net income was primarily attributable to an $18.5 million non-cash
hedge loss compared to a $0.5 million non-cash hedge loss for the comparable period in 2008. The
decrease in net income was also impacted by lower commodity prices and higher operating,
depreciation, G&A, and interest expenses, partially offset by lower deferred income tax expenses
and other income.
Revenues decreased $273.1 million, or 53%, to $239.0 million for the first quarter of 2009 from
$512.1 million for the first quarter of 2008, driven primarily by lower prices for natural gas, NGL
and condensate and lower natural gas, NGL and condensate sales volumes.
Gathering throughput (the volume of natural gas gathered and passed through natural gas gathering
pipelines) for the first quarter of 2009 decreased 7% to 429.4 MMcf/d compared to 462.9 MMcf/d for
the same period in 2008. Plant natural gas inlet volume (the volume of natural gas passing through
the meters located at the inlets of our processing plants) was 7% lower at 408.2 MMcf/d for the
first quarter of 2009 compared to 437.8 MMcf/d for the same period in 2008. These decreases result
primarily from the impact of processing economics on our purchases of lower-margin, discretionary
volumes at our LOU System from third party pipeline systems, somewhat offset by increases at our
North Texas and SAOU Systems.
Gross NGL production of 41.6 MBbl/d for the first quarter of 2009 was 6% lower than gross NGL
production of 44.4 MBbl/d for the first quarter of 2008. NGL sales of 37.2 MBbl/d for the first
quarter of 2009 were 2% lower than the 38.0 MBbl/d sold during the first quarter of 2008. The
decrease in NGL sales is primarily due to lower plant inlets. Natural gas sales volumes decreased
15% to 355.1 BBtu/d in the first quarter of 2009 compared to 418.4 BBtu/d during the first quarter
of 2008. The decrease in natural gas sales is primarily the result of a decrease in demand by our
industrial customers and a decrease in purchases from affiliates for resale.
The average realized natural gas price decreased by $3.46 per MMBtu, or 43%, to $4.56 per MMBtu for
the first quarter of 2009 compared to $8.02 per MMBtu for the same period in 2008. The average
realized price for NGLs decreased by $0.66 per gallon, or 55%, to $0.55 per gallon for the first
quarter of 2009 compared to $1.21 per gallon for the same period in 2008. The average realized
price for condensate decreased by $44.46 per barrel, or 52%, to $41.13 per barrel for the first
quarter of 2009 compared to $85.59 per barrel for the first quarter of 2008. Realized prices
reflect the impact of our hedging program.
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Three Months Ended |
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March 31, |
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2009 |
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2008 |
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(In millions) |
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Revenues |
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$ |
239.0 |
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$ |
512.1 |
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Product purchases |
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194.5 |
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442.2 |
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Operating expense, excluding DD&A |
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12.9 |
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12.6 |
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Depreciation and amortization expense |
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18.9 |
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18.2 |
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General and administrative expense |
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5.3 |
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5.2 |
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Income from operations |
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7.4 |
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33.9 |
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Interest expense, net |
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(9.9 |
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(8.7 |
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Deferred income tax expense |
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(0.3 |
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(0.3 |
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Other |
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0.7 |
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Net income |
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$ |
(2.1 |
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$ |
24.9 |
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Financial data: |
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Operating margin |
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$ |
31.6 |
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$ |
57.3 |
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Adjusted EBITDA |
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45.5 |
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52.6 |
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Distributable cash flow |
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33.6 |
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39.9 |
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Operating data: |
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Gathering throughput, MMcf/d |
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LOU System |
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145.7 |
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196.1 |
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SAOU System |
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101.7 |
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97.8 |
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North Texas System |
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182.0 |
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169.0 |
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429.4 |
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462.9 |
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Plant natural gas inlet, MMcf/d |
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LOU System |
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140.6 |
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185.1 |
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SAOU System |
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91.4 |
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90.4 |
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North Texas System |
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176.2 |
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162.3 |
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408.2 |
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437.8 |
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Gross NGL production, MBbl/d |
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LOU System |
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7.6 |
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10.9 |
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SAOU System |
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14.3 |
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14.1 |
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North Texas System |
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19.7 |
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19.4 |
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41.6 |
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44.4 |
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Natural gas sales, BBtu/d |
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355.1 |
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418.4 |
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NGL sales, MBbl/d |
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37.2 |
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38.0 |
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Condensate sales, MBbl/d |
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3.4 |
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3.7 |
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Average realized prices: |
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Natural gas, $/MMBtu |
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4.56 |
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8.02 |
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NGLs, $/gal |
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0.55 |
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1.21 |
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Condensate, $/ Bbl |
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41.13 |
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85.59 |
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3
Capitalization and Liquidity Update
Total funded debt as of March 31, 2009 was approximately $697 million including approximately $488
million outstanding under our $850 million senior secured revolving credit facility and $209
million of senior unsecured notes. As of March 31, 2009, we had approximately $337 million in
capacity available under our credit facility after giving effect to the Lehman default and the
issuance of $15 million of letters of credit.
As of March 31, 2009, we had approximately $62 million of cash, bringing total liquidity to
approximately $400 million. In addition to our strong liquidity position, we are well within our
financial covenants and have no near term maturities under our credit facility or our senior
unsecured notes.
We are revising our capital expenditures estimate for 2009 to be more inline with the approximately
$55 million in 2008 due to cost control programs and cost savings. As we move through the year we
may see additional impacts from these programs. Maintenance capital expenditures account for
approximately 40% of the 2009 estimate.
Conference Call
Targa Resources Partners will host a conference call for investors and analysts at 11 a.m. Eastern
Time (10 a.m. Central Time) on May 7, 2009 to discuss first quarter 2009 financial results. The
conference call can be accessed via Webcast through the Investors section of the Partnerships
website at http://www.targaresources.com or by dialing 800-762-8795. The pass code is 4058507.
Please dial in ten minutes prior to the scheduled start time. A replay will be available
approximately two hours following completion of the Webcast through the Investors section of the
Partnerships website and will remain available until May 21, 2009. Replay access numbers are
303-590-3030 or 800-406-7325 with pass code 4058507.
4
About Targa Resources Partners
Targa Resources Partners was formed by Targa to engage in the business of gathering, compressing,
treating, processing and selling natural gas and fractionating and selling natural gas liquids and
natural gas liquids products. Targa Resources Partners owns an extensive network of integrated
gathering pipelines, seven natural gas processing plants and two fractionators and currently
operates in Southwest Louisiana, the Permian Basin in West Texas and the Fort Worth Basin in North
Texas. A subsidiary of Targa is the general partner of Targa Resources Partners.
Targa Resources Partners principal executive offices are located at 1000 Louisiana, Suite 4300,
Houston, Texas 77002 and its telephone number is 713-584-1000.
For more information, visit www.targaresources.com.
Non-GAAP Financial Measures
This press release and accompanying schedules include the non-GAAP financial measures Adjusted
EBITDA, operating margin and distributable cash flow. The accompanying schedules provide
reconciliations of these non-GAAP financial measures to their most directly comparable financial
measure calculated and presented in accordance with U.S. generally accepted accounting principles
(GAAP). Our non-GAAP financial measures should not be considered as alternatives to GAAP measures
such as net income, operating income, net cash flows provided by operating activities or any other
GAAP measure of liquidity or financial performance.
Distributable Cash Flow - Distributable cash flow is a significant performance metric used by us
and by external users of our financial statements, such as investors, commercial banks, research
analysts and others to compare basic cash flows generated by us (prior to the establishment of any
retained cash reserves by our general partner) to the cash distributions we expect to pay our
unitholders. Using this metric, management can quickly compute the coverage ratio of estimated cash
flows to planned cash distributions. Distributable cash flow is also an important non-GAAP
financial measure for our unitholders because it serves as an indicator of our success in providing
a cash return on investment. Specifically, this financial measure indicates to investors whether or
not we are generating cash flow at a level that can sustain or support an increase in our quarterly
distribution rates. Distributable cash flow is also a quantitative standard used throughout the
investment community with respect to publicly-traded partnerships and limited liability companies
because the value of a unit of such an entity is generally determined by the units yield (which in
turn is based on the amount of cash distributions the entity pays to a unitholder). The economic
substance behind our use of distributable cash flow is to measure the ability of our assets to
generate cash flows sufficient to make distributions to our investors.
The GAAP measure most directly comparable to distributable cash flow is net income (loss). Our
non-GAAP measure of distributable cash flow should not be considered as an alternative to GAAP net
income (loss). Distributable cash flow is not a presentation made in accordance with GAAP and has
important limitations as an analytical tool. You should not consider distributable cash flow in
isolation or as a substitute for analysis of our results as reported under GAAP. Because
distributable cash flow excludes some, but not all, items that affect net income (loss) and is
defined differently by different companies in our industry, our definition of distributable cash
flow may not be comparable to similarly titled measures of other companies, thereby diminishing its
utility. Management compensates for the
5
limitations of distributable cash flow as an analytical tool by reviewing the comparable GAAP
measures, understanding the differences between the measures and incorporating these learnings into
our decision-making processes.
The following table presents a reconciliation of net income (loss) to distributable cash flow for
the Partnership for the periods shown:
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Three Months Ended |
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March 31, |
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2009 |
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2008 |
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(In millions) |
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Reconciliation of net income (loss)
to distributable cash flow: |
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Net income (loss) |
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$ |
(2.1 |
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$ |
24.9 |
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Depreciation and amortization expense |
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18.9 |
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18.2 |
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Deferred income tax expense |
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0.3 |
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0.3 |
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Amortization in interest expense |
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0.6 |
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0.4 |
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Non-cash loss related to derivatives |
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18.5 |
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0.5 |
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Maintenance capital expenditures |
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(2.6 |
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(4.4 |
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Distributable cash flow |
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$ |
33.6 |
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$ |
39.9 |
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Adjusted EBITDA - We define Adjusted EBITDA as net income before interest, income taxes,
depreciation and amortization and non-cash income or loss related to derivative instruments.
Adjusted EBITDA is used as a supplemental financial measure by our management and by external users
of our financial statements such as investors, commercial banks and others, to assess: (1) the
financial performance of our assets without regard to financing methods, capital structure or
historical cost basis; (2) our operating performance and return on capital as compared to other
companies in the midstream energy sector, without regard to financing or capital structure; and (3)
the viability of acquisitions and capital expenditure projects and the overall rates of return on
alternative investment opportunities.
The economic substance behind managements use of Adjusted EBITDA is to measure the ability of our
assets to generate cash sufficient to pay interest costs, support our indebtedness and make
distributions to our investors. The GAAP measure most directly comparable to Adjusted EBITDA is net
income. Our non-GAAP financial measure of Adjusted EBITDA should not be considered as an
alternative to GAAP net income. Adjusted EBITDA is not a presentation made in accordance with GAAP
and has important limitations as an analytical tool. You should not consider Adjusted EBITDA in
isolation or as a substitute for analysis of our results as reported under GAAP. Because Adjusted
EBITDA excludes some, but not all, items that affect net income and is defined differently by
different companies in our industry, our definition of Adjusted EBITDA may not be comparable to
similarly titled measures of other companies, thereby diminishing its utility. Management
compensates for the limitations of Adjusted EBITDA as an analytical tool by reviewing the
comparable GAAP measures, understanding the differences between the measures and incorporating
these learnings into managements decision-making processes.
6
Operating Margin - We define operating margin as total operating revenues (which consist of natural
gas and NGL sales plus service fee revenues) less product purchases (which consist primarily of
producer payments and other natural gas purchases) and operating expense. Management reviews
operating margin monthly for consistency and trend analysis. Based on this monthly analysis,
management takes appropriate action to maintain positive trends or to reverse negative trends.
Management uses operating margin as an important performance measure of the core profitability of
our operations.
The GAAP measure most directly comparable to operating margin is net income. Our non-GAAP financial
measure of operating margin should not be considered as an alternative to GAAP net income.
Operating margin is not a presentation made in accordance with GAAP and has important limitations
as an analytical tool. You should not consider operating margin in isolation or as a substitute for
analysis of our results as reported under GAAP. Because operating margin excludes some, but not
all, items that affect net income and is defined differently by different companies in our
industry, our definition of operating margin may not be comparable to similarly titled measures of
other companies, thereby diminishing its utility. Management compensates for the limitations of
operating margin as an analytical tool by reviewing the comparable GAAP measures, understanding the
differences between the measures and incorporating these learnings into managements
decision-making processes.
7
Reconciliation of Non-GAAP Measures
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Three Months Ended |
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March 31, |
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2009 |
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2008 |
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(In millions) |
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Reconciliation of net income (loss) to Adjusted EBITDA: |
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Net income (loss) |
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$ |
(2.1 |
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$ |
24.9 |
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Add: |
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Interest expense, net |
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9.9 |
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8.7 |
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Deferred income tax expense |
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0.3 |
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0.3 |
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Depreciation and amortization expense |
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18.9 |
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18.2 |
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Non-cash loss related to derivatives |
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18.5 |
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0.5 |
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Adjusted EBITDA |
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$ |
45.5 |
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$ |
52.6 |
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Three Months Ended |
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March 31, |
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2009 |
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2008 |
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(In millions) |
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Reconciliation of net cash provided by
operating activities to Adjusted EBITDA: |
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Net cash provided by operating activities |
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$ |
22.0 |
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$ |
52.8 |
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Interest expense, net |
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9.3 |
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8.3 |
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Changes in operating working capital
which used (provided) cash: |
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Accounts receivable and other assets |
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(6.3 |
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5.4 |
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Accounts payable and other liabilities |
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20.5 |
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(13.9 |
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Adjusted EBITDA |
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$ |
45.5 |
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$ |
52.6 |
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Three Months Ended |
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March 31, |
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2009 |
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2008 |
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(In millions) |
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Reconciliation of net income (loss) to operating margin: |
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Net income (loss) |
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$ |
(2.1 |
) |
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$ |
24.9 |
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Add: |
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Depreciation and amortization expense |
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18.9 |
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18.2 |
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Deferred income tax expense |
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0.3 |
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0.3 |
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Interest expense, net |
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9.9 |
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8.7 |
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General and administrative and other expense |
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4.6 |
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5.2 |
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Operating margin |
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$ |
31.6 |
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$ |
57.3 |
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8
Forward-Looking Statements
Certain statements in this release 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. All statements, other than statements of historical facts, included in this
release that address activities, events or developments that the Partnership expects, believes or
anticipates will or may occur in the future are forward-looking statements. These forward-looking
statements rely on a number of assumptions concerning future events and are subject to a number of
uncertainties, factors and risks, many of which are outside Targa Resources Partners control,
which could cause results to differ materially from those expected by management of Targa Resources
Partners. Such risks and uncertainties include, but are not limited to, weather, political,
economic and market conditions, including declines in the production of natural gas or in the price
and market demand for natural gas and natural gas liquids, the timing and success of business
development efforts, the credit risk of customers and other uncertainties. These and other
applicable uncertainties, factors and risks are described more fully in the Partnerships reports
and other filings with the Securities and Exchange Commission. Targa Resources Partners undertakes
no obligation to update or revise any forward-looking statement, whether as a result of new
information, future events or otherwise.
Investor contact info:
Phone: 713-584-1133
Anthony Riley
Senior Manager Finance/Investor Relations
Matt Meloy
Vice President Finance and Treasurer
9
TARGA RESOURCES PARTNERS LP
FINANCIAL SUMMARY (unaudited)
CONSOLIDATED BALANCE SHEET DATA
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
March 31, |
|
|
December 31, |
|
|
|
2009 |
|
|
2008 |
|
ASSETS |
|
|
|
|
|
|
|
|
Current assets |
|
|
|
|
|
|
|
|
Cash and cash equivalents |
|
$ |
62,310 |
|
|
$ |
81,768 |
|
Assets from risk management activities |
|
|
90,796 |
|
|
|
91,816 |
|
Other current assets |
|
|
75,724 |
|
|
|
81,926 |
|
|
|
|
|
|
|
|
Total current assets |
|
|
228,830 |
|
|
|
255,510 |
|
|
|
|
|
|
|
|
Property, plant and equipment, net |
|
|
1,233,221 |
|
|
|
1,244,337 |
|
Long-term assets from risk management activities |
|
|
63,339 |
|
|
|
68,296 |
|
Other assets |
|
|
13,196 |
|
|
|
12,763 |
|
|
|
|
|
|
|
|
Total assets |
|
|
1,538,586 |
|
|
|
1,580,906 |
|
|
|
|
|
|
|
|
LIABILITIES AND PARTNERS CAPITAL |
|
|
|
|
|
|
|
|
Accounts payable and accrued liabilities |
|
$ |
66,930 |
|
|
$ |
94,840 |
|
Liabilities from risk management activities |
|
|
12,259 |
|
|
|
11,664 |
|
|
|
|
|
|
|
|
Total current liabilities |
|
|
79,189 |
|
|
|
106,504 |
|
|
|
|
|
|
|
|
Long-term debt |
|
|
696,845 |
|
|
|
696,845 |
|
Long term liabilities from risk management activities |
|
|
16,250 |
|
|
|
9,679 |
|
Other long-term liabilities |
|
|
5,908 |
|
|
|
5,514 |
|
|
|
|
|
|
|
|
Total liabilities |
|
|
798,192 |
|
|
|
818,542 |
|
Partners capital |
|
|
740,394 |
|
|
|
762,364 |
|
|
|
|
|
|
|
|
Total liabilities and partners capital |
|
$ |
1,538,586 |
|
|
$ |
1,580,906 |
|
|
|
|
|
|
|
|
10
TARGA RESOURCES PARTNERS LP
FINANCIAL SUMMARY (unaudited)
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per unit data)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
March 31, |
|
|
|
2009 |
|
|
2008 |
|
REVENUES |
|
$ |
239,034 |
|
|
$ |
512,069 |
|
|
|
|
|
|
|
|
|
|
COSTS AND EXPENSES: |
|
|
|
|
|
|
|
|
Product purchases |
|
|
194,564 |
|
|
|
442,150 |
|
Operating expenses |
|
|
12,903 |
|
|
|
12,570 |
|
Depreciation and amortization expense |
|
|
18,878 |
|
|
|
18,248 |
|
General and administrative expense |
|
|
5,321 |
|
|
|
5,201 |
|
Gain on sale of assets |
|
|
|
|
|
|
(74 |
) |
|
|
|
|
|
|
|
Total costs and expenses |
|
|
231,666 |
|
|
|
478,095 |
|
|
|
|
|
|
|
|
INCOME FROM OPERATIONS |
|
|
7,368 |
|
|
|
33,974 |
|
Other income (expense): |
|
|
|
|
|
|
|
|
Interest expense, net |
|
|
(9,924 |
) |
|
|
(8,718 |
) |
Other |
|
|
726 |
|
|
|
16 |
|
|
|
|
|
|
|
|
Income (loss) before income taxes |
|
|
(1,830 |
) |
|
|
25,272 |
|
Income tax expense |
|
|
(300 |
) |
|
|
(337 |
) |
|
|
|
|
|
|
|
NET INCOME (LOSS) |
|
|
(2,130 |
) |
|
|
24,935 |
|
Net income attributable to general partner |
|
|
1,890 |
|
|
|
1,846 |
|
|
|
|
|
|
|
|
Net income (loss) available to limited partners |
|
$ |
(4,020 |
) |
|
$ |
23,089 |
|
|
|
|
|
|
|
|
Basic and diluted net income (loss) per limited partner unit |
|
$ |
(0.09 |
) |
|
$ |
0.50 |
|
|
|
|
|
|
|
|
Basic and diluted average limited partner units outstanding |
|
|
46,205 |
|
|
|
46,165 |
|
11
TARGA RESOURCES PARTNERS LP
FINANCIAL SUMMARY (unaudited)
CONSOLIDATED CASH FLOW INFORMATION
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
|
|
March 31, |
|
|
|
2009 |
|
|
2008 |
|
CASH FLOWS FROM OPERATING ACTIVITIES |
|
|
|
|
|
|
|
|
Net income (loss) |
|
$ |
(2,130 |
) |
|
$ |
24,935 |
|
Adjustments to reconcile net income (loss) to net cash
provided by operating activities: |
|
|
|
|
|
|
|
|
Depreciation, amortization and accretion |
|
|
19,657 |
|
|
|
18,751 |
|
Deferred income tax expense |
|
|
300 |
|
|
|
337 |
|
Risk management activities |
|
|
18,511 |
|
|
|
478 |
|
Gain on sale of assets |
|
|
|
|
|
|
(74 |
) |
Changes in operating assets and liabilities |
|
|
(14,325 |
) |
|
|
8,360 |
|
|
|
|
|
|
|
|
Net cash provided by operating activities |
|
|
22,013 |
|
|
|
52,787 |
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES |
|
|
|
|
|
|
|
|
Purchases of property, plant and equipment |
|
|
(15,102 |
) |
|
|
(7,381 |
) |
Other |
|
|
|
|
|
|
(4,167 |
) |
|
|
|
|
|
|
|
Net cash used in investing activities |
|
|
(15,102 |
) |
|
|
(11,548 |
) |
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES |
|
|
|
|
|
|
|
|
Repayments on credit facility |
|
|
|
|
|
|
(50,000 |
) |
Distributions |
|
|
(26,374 |
) |
|
|
(18,792 |
) |
General partner contributions |
|
|
5 |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in financing activities |
|
|
(26,369 |
) |
|
|
(68,792 |
) |
|
|
|
|
|
|
|
Net change in cash and cash equivalents |
|
|
(19,458 |
) |
|
|
(27,553 |
) |
Cash and cash equivalents, beginning of period |
|
|
81,768 |
|
|
|
50,994 |
|
|
|
|
|
|
|
|
Cash and cash equivalents, end of period |
|
$ |
62,310 |
|
|
$ |
23,441 |
|
|
|
|
|
|
|
|
12