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-- Net income for the second quarter of 2009 was $4.5 million, or $0.13 per unit. In the second quarter of 2008, Genesis had net income of $7.3 million, or $0.17 per unit.
-- For the second quarter of 2009, we generated total Available Cash before Reserves of $22.2 million as compared to $21.3 million in the first quarter of 2009 and $26.2 million for the second quarter of 2008. Available Cash before Reserves is a non-GAAP measure that is defined and reconciled later in this press release to its most directly comparable GAAP financial measure, net cash provided by operating activities. Net cash provided by operating activities was $15.9 million and $5.3 million for the second quarter of 2009 and 2008, respectively, and $3.2 million for the first quarter of 2009.
-- On August 14, 2009, we will pay a total quarterly distribution of $15.3 million attributable to our financial and operational results for the second quarter of 2009, including $13.6 million payable to our common unitholders based on our quarterly distribution rate of $0.345 per unit, and $1.7 million payable to our general partner, which includes its incentive distribution amount. Given the total Available Cash before Reserves generated for the second quarter of 2009, the coverage ratio for our total distribution was approximately 1.5 times.
-- The distribution for the second quarter of 2009 is our sixteenth consecutive quarter with an increase in the per unit distribution. The distribution of $0.345 per unit represents a 2.2% increase in the distribution paid relative to the previous quarter and an approximately 9.5% increase over the year earlier period.
Grant Sims, CEO, said, "We are quite pleased with our quarterly results, especially the improvement in segment margin and Available Cash before Reserves over the corresponding amounts we generated in the first quarter of 2009. We have worked hard to manage our costs and seek out incremental opportunities across all of our business segments to respond to the challenges posed by the current macroeconomic environment."
Sims added, "Comparisons to the 'year earlier' period are difficult because that economic environment doesn't exist anymore. While our challenges have not totally gone away, we feel more optimistic than we did just two months ago about our businesses' ability to produce financial results. Because of our employees' hard work and our belief in the sustainability of our results, we're very proud to have been able to continue our string of consecutive quarters of increasing our distribution to unitholders."
Financial Results - Second Quarter
To provide a view of current earnings trends, we will initially compare the second quarter of 2009 to the first quarter of 2009, and then follow that discussion with a comparison of the second quarter of 2009 to the same period in 2008.
Comparison Second Quarter 2009 to First Quarter 2009
Net income for the second quarter was $4.5 million, which decreased by $0.8 million from the first quarter of 2009. An increase in depreciation and amortization expense of $0.7 million accounted for most of this difference.
Segment Margin
Segment margin is defined and reconciled later in this press release to income before income taxes. As we integrated the acquisition we made in 2007, we changed our definition of segment margin and have reflected those changes in the discussions that follow. Segment margin now includes costs such as general and administrative costs that are directly incurred by the business segment. Segment margin also includes all payments received under direct financing leases. In order to improve comparability between periods, we exclude from segment margin the non-cash effects of our equity-based compensation plans that are impacted by the changes in market prices of our units. For the first two quarters of 2009, segment results were as follows:
Pipeline Refinery Supply & Industrial
Transportation Services Logistics Gases Total
(in thousands)
Segment margin (1)
Three months ended June 30, 2009 $ 10,347 $ 13,190 $ 6,600 $ 2,869 $ 33,006
Three months ended March 31, 2009 $ 10,225 $ 12,759 $ 5,956 $ 3,023 $ 31,963
(1) Segment margin was calculated as revenues less cost of sales,
operating expenses and segment general and administrative
expenses, plus our share of the distributable cash generated by
our joint ventures. Segment margin excludes the non-cash effects
of our stock-based compensation plans, and includes the non-income
portion of payments received under direct financing leases. A
reconciliation of segment margin to income before income taxes is
presented for periods presented in the table at the end of this
release.
Pipeline segment margin increased slightly between the first and second quarters of 2009, despite a drop in average volumes per day to 58,535 barrels for crude oil and 134,570 Mcf for CO2 on the Free State pipeline. The effects of the volumetric declines were offset by increased pipeline loss allowance revenue resulting primarily from higher market prices for crude oil. Volumes declined most on our Texas System which has the lowest average per barrel tariff of our crude oil pipeline systems.
Our refinery services segment margin increased $0.4 million between the 2009 quarterly periods. Several factors contributed to the increase in segment margin. While NaHS volumes decreased by 5,321 dry short tons (DST) from 26,229 DST to 20,908 DST, sales of caustic soda increased by 2,863 DST from 16,900 DST to 19,763 DST. We are a very large consumer of caustic soda, and our economies of scale and logistics capabilities allow us to effectively market caustic soda to third parties. Market prices for caustic soda continued to decline in the second quarter, which when coupled with additional measures to reduce costs, resulted in raw material and processing costs decreasing 13% as a percentage of revenue. Delivery costs increased as a percentage of revenue by 2% as market prices for fuel increased. Together these changes combined to result in the segment margin increase.
Supply and logistics segment margin increased by more than $0.6 million between the quarters as the availability of fuel oil volumes in our markets improved, and we were able to acquire more petroleum products for blending and sale. In the second quarter of 2009, volumes that we marketed increased by more than 16% over the 2009 first quarter. During the second quarter, we acquired access to 500,000 barrels of leased storage capacity on the lower Mississippi River (a portion of which is sublet to third parties). Our access to increased storage facilities and barge transportation through our DG Marine joint venture provided us additional opportunities to supply customers with fuel oil.
Our industrial gases segment was the only segment not reporting an increase in segment margin for the second quarter as compared to the first quarter of 2009. The contribution of our industrial gas joint ventures declined slightly in the second quarter due primarily to a planned turnaround (or maintenance operation) at one facility that started in the second quarter and is expected to be completed in the third quarter of 2009.
Other Components of Net Income
Depreciation and amortization increased $0.7 million as all of DG Marine's barges, push boats and other capital projects were completed and placed in service.
Increased interest costs of $0.3 million also reduced net income between the quarters. The increase in interest expense was primarily a function of additional borrowings by DG Marine to acquire the last of the barges it had under construction and by us to exploit opportunities to profit from increasing our short-term hedged crude oil inventory positions.
Available Cash
Several adjustments to net income are required to calculate Available Cash before Reserves. The calculation of Available Cash before Reserves for the quarters ended June 30, 2009 and March 31, 2009 is as follows:
Three Months Ended
June 30, 2009 March 31, 2009
(in thousands)
Net income attributable to Genesis Energy, L.P. $ 4,456 $ 5,290
Depreciation and amortization 16,133 15,419
Cash received from direct financing leases not included in income 929 907
Cash effects of sales of certain assets 52 405
Effects of available cash generated by equity method investees not 170 (1,289 )
included in income
Cash effects of stock appreciation rights plan (3 ) (4 )
Non-cash tax expense 627 460
Earnings of DG Marine in excess of distributable cash (904 ) (1,970 )
Other non-cash items, net, including equity-based compensation 2,222 3,072
Maintenance capital expenditures (1,474 ) (948 )
Available Cash before Reserves $ 22,208 $ 21,342
We generated Available Cash before Reserves (a non-GAAP measure) of $22.2 million during the second quarter of 2009, as compared to $21.3 million for the first quarter. Net cash flows provided by operating activities were $15.9 million for the second quarter period in 2009, and $3.2 million for the first quarter. (Please see the accompanying schedules for a reconciliation of Available Cash before Reserves, a non-GAAP measure, to net cash flow provided by operations, the GAAP measure.)
The increase in Available Cash before Reserves between the two 2009 quarters can be attributed to the increase in segment margin between periods, adjusted for the segment margin generated by DG Marine which we exclude from the calculation of Available Cash before Reserves (due to the requirement that DG Marine reduce its balance under its credit facility before distributions are made to its partners). These items were offset slightly by an increase in maintenance capital expenditures.
Comparison Second Quarter 2009 to Second Quarter 2008
Net income for the second quarter decreased by $2.9 million over the same period in the previous year, with $2.4 million of that decline due to a non-cash charge related to executive compensation.
Segment Margin
The following table presents selected financial information by segment for the three-month reporting periods:
Pipeline Refinery Supply & Industrial
Transportation Services Logistics Gases Total
(in thousands)
Three Months Ended June 30, 2009
Segment margin (1) $ 10,347 $ 13,190 $ 6,600 $ 2,869 $ 33,006
Maintenance capital expenditures $ 476 $ 51 $ 947 $ - $ 1,474
Revenues:
External customers $ 10,883 $ 35,923 $ 291,607 $ 3,791 $ 342,204
Intersegment 1,572 (1,329 ) (243 ) - -
Total revenues of reportable segments $ 12,455 $ 34,594 $ 291,364 $ 3,791 $ 342,204
Three Months Ended June 30, 2008
Segment margin (1) $ 7,261 $ 16,279 $ 7,780 $ 3,686 $ 35,006
Maintenance capital expenditures $ - $ 208 $ - $ - $ 208
Revenues:
External customers $ 8,885 $ 55,727 $ 571,478 $ 4,450 $ 640,540
Intersegment 2,001 - (2,001 ) - -
Total revenues of reportable segments $ 10,886 $ 55,727 $ 569,477 $ 4,450 $ 640,540
(1) Segment margin was calculated as revenues less cost of sales,
operating expenses and segment general and administrative
expenses, plus our share of the distributable cash generated by
our joint ventures. Segment margin excludes the non-cash effects
of our stock-based compensation plans, and includes the non-income
portion of payments received under direct financing leases. A
reconciliation of segment margin to income before income taxes is
presented for periods presented in the table at the end of this
release.
Pipeline transportation segment margin for the second quarter of 2009 increased $3.1 million as compared to the second quarter of 2008. Two CO2 pipeline dropdown transactions from Denbury completed at the end of May 2008 contributed $4.6 million of additional segment margin for the second quarter of 2009 compared to the 2008 quarter. Throughput decreased on the crude oil pipeline systems by 13%, with that impact being mitigated partially by the relatively low tariff rate on our Texas System which experienced our largest volumetric decrease. Our Jay System volumes declined 2,521 barrels per day primarily because a producer connected to our Jay System curtailed production volumes. In addition, our pipeline loss allowance volumes declined 691 barrels from the second quarter of 2008. That decline in volumes, coupled with the decline in crude oil market prices, resulted in a decrease of $1.5 million from our pipeline loss allowance revenues. Operating costs were consistent quarter to quarter.
Refinery services segment margin was $13.2 million for the second quarter of 2009, a decrease of $3.1 million from the corresponding 2008 quarter. While we experienced a decrease in NaHS volumes of approximately 55%, we have taken advantage of our logistics capabilities and economies of scale to increase caustic sales to third parties. As a result, our caustic soda sales volumes increased by 18% to 19,763 dry short tons (DST). Raw material and processing costs related to providing our refinery services and supplying caustic soda as a percentage of our segment revenues declined 8% between the periods. As the market price of caustic soda has fluctuated in 2008 and 2009, we have managed our acquisition costs by controlling the timing of our purchases and our logistics costs. Market prices for caustic soda increased throughout 2008 to a high of approximately $1,000 per DST in the fourth quarter of 2008. Since that time market prices of caustic soda have decreased to approximately $325 per DST. Market prices for caustic soda averaged $547 per DST and $450 per DST in the second quarters of 2008 and 2009, respectively. The costs of delivering NaHS and caustic soda to our customers declined as a percentage of segment revenues by 5% between the two quarterly periods. Freight demand and fuel prices declined in the 2009 period as compared to the second quarter of 2008 as economic conditions reduced transportation needs in the market and the decline in crude oil prices reduced the cost of fuel used in transporting these products.
Supply and logistics segment margin was $6.6 million in the second quarter of 2009 compared to $7.8 million in the second quarter of 2008. The DG Marine barge operations we acquired in July 2008 added approximately $2.5 million to our segment margin in the second quarter of 2009. Contango pricing in the crude oil market provided opportunities for us to hold more barrels in storage tanks to take advantage of higher oil prices for future deliveries. We hedge the future delivery price with the use of derivative contracts (principally NYMEX futures) and minimize price risk. During the second quarter of 2009, we averaged approximately 226,000 barrels of crude oil in inventory and recorded $0.9 million of segment margin related to storing and hedging crude oil. Offsetting these improvements in segment margin was a decrease in the margins in our crude oil gathering and petroleum products marketing operations. In 2009, we experienced some reduction in volumes as a result of crude oil producers' choices to reduce operating expenses or postpone development activities that could have enhanced or maintained existing production levels. Also, market inefficiencies developed in the heavy-end refined products in the 2008 quarter as crude oil and light-end products experienced sharp increases. Due to our logistics equipment, we were able to benefit from improved blending opportunities during the 2008 period. In the 2009 quarter, gasoline demand had declined significantly and refiners reduced their production rates. Our blending economics narrowed as volatility in prices declined in correlation to decreased demand. Somewhat offsetting these declines were the additional opportunities to handle the heavy end of the refined barrel due to our access to the additional leased heavy products storage and to barge transportation capabilities through our DG Marine joint venture. However as a result of all of the above factors, our crude oil and petroleum products marketing activities contributed $4.6 million less to segment margin in 2009 than in the second quarter of 2008.
Segment margin from our industrial gases segment declined between the second quarter periods as sales of CO2 to our industrial gases customers were affected by macroeconomic conditions. Our customers process the CO2 for further sale to beverage and food processing customers and to parties who use the gases in tertiary oil recovery and other industrial processes. In addition, a planned turnaround that started at the facility of our syngas joint venture reduced the contribution of that venture in the second quarter of 2009.
Other Components of Net Income
The amount we recorded as depreciation and amortization expense declined in the second quarter of 2009 as compared to the second quarter of 2008 by $0.6 million. We are amortizing our intangible assets over the period during which the intangible asset is expected to contribute to future cash flows. As a result, amortization is generally greater in the initial years after an acquisition. The decline in intangible asset amortization was partially offset by depreciation on DG Marine's barge fleet, acquired in July 2008.
Corporate general and administrative expenses increased $1.8 million between the second quarter periods. The non-cash charge in the second quarter of 2009 related to the compensation arrangement between our senior executives and our general partner resulted in $2.4 million of this change. Our general partner will bear the cash cost of this arrangement. Slightly offsetting the increase from the compensation arrangement were declines in bonus expense and professional services expenses.
Although our average debt balance was greater in the second quarter of 2009 than the same period in 2008, lower market interest rates substantially offset the effect. Our average interest rate under our credit facility during the second quarter of 2009 was approximately 2.2% less than in the second quarter of 2008. Our average outstanding debt balance under the facility was approximately $183 million more in the second quarter of 2009. The increase in average debt resulted primarily from the CO2 pipeline dropdown transactions in May 2008.
Income tax expense is based on the non-qualified income generated in the period, and Texas margin tax on our operations in Texas. In the second quarter of 2009, non-qualified income from our corporate subsidiaries decreased, resulting in a decrease in income tax expense. As the majority of our operations are not taxable to us, income tax expense is not expected to be significant.
Available Cash
The calculation of Available Cash before Reserves for the quarters ended June 30, 2009 and 2008 is as follows:
Three Months Ended
June 30, 2009 June 30, 2008
(in thousands)
Net income attributable to Genesis Energy, L.P. $ 4,456 $ 7,328
Depreciation and amortization 16,133 16,721
Cash received from direct financing leases not included in income 929 397
Cash effects of sales of certain assets 52 181
Effects of available cash generated by equity method investees not 170 643
included in income
Cash effects of stock appreciation rights plan (3 ) (113 )
Non-cash tax expense 627 700
Earnings of DG Marine in excess of distributable cash (904 ) -
Other non-cash items, net, including equity-based compensation 2,222 536
Maintenance capital expenditures (1,474 ) (208 )
Available Cash before Reserves $ 22,208 $ 26,185
We generated Available Cash before Reserves (a non-GAAP measure) of $22.2 million during the second quarter of 2009. Net cash flows provided by operating activities were $15.9 million for the second quarter period in 2009. (Please see the accompanying schedules for a reconciliation of Available Cash before Reserves, a non-GAAP measure, to net cash flow provided by operating activities, the GAAP measure.)
The decline in Available Cash before Reserves between the second quarter periods can be attributed primarily to the decrease in segment margin between periods and an increase in maintenance capital expenditures.
Distributions
Over the last four quarters, we have increased the distribution rate on our common units by a total of $0.03 per unit, or 9.5%. Distributions paid over the last four quarters, and the distribution to be paid for the second quarter of 2009, are as follows:
Per Unit Distribution For Date Paid Amount Second quarter 2009 August 2009 $ 0.3450 First quarter 2009 May 2009 $ 0.3375 Fourth quarter 2008 February 2009 $ 0.3300 Third quarter 2008 November 2008 $ 0.3225 Second quarter 2008 August 2008 $ 0.3150
The second quarter 2009 distribution will be paid August 14, 2009 to unitholders of record on August 4, 2009.
Liquidity
Our bank credit agreement has provisions that allow us to increase our borrowing base for material acquisitions. Upon the completion of four full quarters of operations including the acquired operations, the EBITDA multiple used to determine the borrowing base is reduced from 4.75 times to 4.25 times. In mid-August upon reporting to our lenders our fourth full quarter of operations including the pipelines dropped down from Denbury in 2008, our borrowing base calculated upon 4.25 times our last four quarters of EBITDA will be $419 million. This level of available credit provides us with sufficient liquidity to run our current business. Should we want to grow through acquisitions, we have additional committed capital available up to $500 million in the form of the higher multiple and the inclusion of an agreed upon amount of pro-forma EBITDA associated with the acquisition.
Earnings Conference Call
We will broadcast our Earnings Conference Call on Thursday, August 6, 2009, at 9:00 a.m. Central time. This call can be accessed at www.genesisenergylp.com. Choose the Investor Relations button. Listeners should go to this website at least fifteen minutes before this event to download and install any necessary audio software. For those unable to attend the live broadcast, a replay will be available beginning approximately one hour after the event and remain available on our website for 30 days. There is no charge to access the event.
Genesis Energy, L.P. is a diversified midstream energy master limited partnership headquartered in Houston, Texas. Genesis engages in four business segments. The Pipeline Transportation Division is engaged in the pipeline transportation of crude oil and, to a lesser extent, natural gas and carbon dioxide. The Refinery Services Division primarily processes sour gas streams to remove sulfur at refining operations, principally located in Texas, Louisiana, and Arkansas. The Supply and Logistics Division is engaged in the transportation, storage and supply of energy products, including crude oil and refined products. The Industrial Gases Division produces and supplies industrial gases such as carbon dioxide and syngas. Genesis' operations are primarily located in Texas, Louisiana, Arkansas, Mississippi, Alabama, and Florida.
This press release includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Although we believe that our expectations are based upon reasonable assumptions, we can give no assurance that our goals will be achieved. Important factors that could cause actual results to differ materially from those in the forward-looking statements herein include the timing and extent of changes in commodity prices for oil, ability to obtain adequate credit facilities, managing operating costs, completion of capital projects on schedule and within budget, consummation of accretive acquisitions, capital spending, environmental risks, government regulation, our ability to meet our stated business goals and other risks noted from time to time in our Securities and Exchange Commission filings. Actual results may vary materially. We undertake no obligation to publicly update or revise any forward-looking statement.
Genesis Energy, L.P.
Summary Consolidated Statements of Operations - Unaudited
(in thousands except per unit amounts and volumes)
Three Months Ended Three Months Ended
June 30, 2009 June 30, 2008
Revenues $ 342,204 $ 640,540
Costs of sales 309,957 603,545
General and administrative expenses 8,306 9,166
Depreciation and amortization expense 16,133 16,721
Loss from disposal of surplus assets 60 76
OPERATING INCOME 7,748 11,032
Equity in earnings (losses) of joint ventures 264 (16 )
Interest expense, net (3,373 ) (2,039 )
Income before income taxes 4,639 8,977
Income tax expense (817 ) (1,648 )
NET INCOME 3,822 7,329
Noncontrolling interests 634 (1 )
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P. $ 4,456 $ 7,328
NET INCOME PER COMMON UNIT - BASIC AND DILUTED $ 0.13 $ 0.17
Volume data:
Crude oil pipeline barrels per day (total) 58,535 67,434
Mississippi Pipeline System barrels per day 24,159 24,873
Jay Pipeline System barrels per day 9,307 11,828
Texas Pipeline System barrels per day 25,069 30,733
Free State CO2 System Mcf per day (1) 134,570 152,191
NaHS dry short tons sold 20,908 46,655
NaOH (caustic soda) dry short tons sold 19,763 16,758
Crude oil and petroleum products barrels per day 47,941 47,757
CO2 sales Mcf per day 70,621 79,968
(1) 2008 volume is for one month
Genesis Energy, L.P.
Summary Consolidated Statements of Operations - Unaudited
(in thousands except per unit amounts and volumes)
Six Months Ended Six Months Ended
June 30, 2009 June 30, 2008
Revenues $ 595,697 $ 1,126,725
Costs of sales 532,474 1,062,640
General and administrative expenses 17,060 17,690
Depreciation and amortization expense 31,552 33,510
(Gain) loss from disposal of surplus assets (158 ) 94
OPERATING INCOME 14,769 12,791
Equity in earnings of joint ventures 2,170 162
Interest expense, net (6,408 ) (3,708 )
Income before income taxes 10,531 9,245
Income tax expense (1,408 ) (271 )
NET INCOME 9,123 8,974
Noncontrolling interests 623 (1 )
NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P. $ 9,746 $ 8,973
NET INCOME PER COMMON UNIT - BASIC AND DILUTED $ 0.29 $ 0.20
Volume data:
Crude oil pipeline barrels per day (total) 61,562 66,733
Mississippi Pipeline System barrels per day 24,758 23,864
Jay Pipeline System barrels per day 9,369 13,222
Texas Pipeline System barrels per day 27,435 29,647
Free State CO2 System Mcf per day (1) 152,830 152,191
NaHS dry short tons sold 47,137 88,397
NaOH (caustic soda) dry short tons sold 36,663 32,663
Crude oil and petroleum products barrels per day 45,257 47,611
CO2 sales Mcf per day 70,229 76,515
(1) 2008 volume is for one month
Genesis Energy, L.P.
Consolidated Balance Sheets - Unaudited
(in thousands)
June 30, 2009 December 31, 2008
ASSETS
Cash $ 6,929 $ 18,985
Accounts receivable 120,701 115,104
Inventories 38,594 21,544
Other current assets 16,649 12,494
Total current assets 182,873 168,127
Property, net 292,882 282,105
CO2 contracts, net 22,350 24,379
Joint ventures and other investments 20,857 19,468
Investment in direct financing leases 175,163 177,203
Intangible assets, net 152,989 166,933
Goodwill 325,046 325,046
Other assets 15,922 15,413
Total Assets $ 1,188,082 $ 1,178,674
LIABILITIES AND PARTNERS' CAPITAL
Accounts payable $ 102,020 $ 99,559
Accrued liabilities 23,415 26,713
Total current liabilities 125,435 126,272
Long-term debt 399,400 375,300
Deferred tax liabilities 17,030 16,806
Other liabilities 3,169 2,834
Partners' Capital:
Genesis Energy, L.P. partners' capital 618,764 632,658
Noncontrolling interests 24,284 24,804
Total partners' capital 643,048 657,462
Total Liabilities and Partners' Capital $ 1,188,082 $ 1,178,674
Units Data:
Common units held by general partner and affiliates 4,028,096 4,028,096
Common units held by Davison family 11,785,979 11,781,379
Common units held by others 23,665,699 23,647,299
Total common units outstanding 39,479,774 39,456,774
SEGMENT DATA - SIX MONTH PERIODS
Pipeline Refinery Supply & Industrial
Transportation Services Logistics Gases Total
(in thousands)
Six Months Ended June 30, 2009
Segment margin (1) $ 20,572 $ 25,949 $ 12,556 $ 5,892 $ 64,969
Capital expenditures $ 2,458 $ 1,982 $ 21,497 $ 21 $ 25,958
Maintenance capital expenditures $ 750 $ 544 $ 1,128 $ - $ 2,422
Revenues:
External customers $ 22,198 $ 85,828 $ 480,151 $ 7,520 $ 595,697
Intersegment 2,665 (2,940 ) 275 - -
Total revenues of reportable segments $ 24,863 $ 82,888 $ 480,426 $ 7,520 $ 595,697
Six Months Ended June 30, 2008
Segment margin (1) $ 11,922 $ 28,709 $ 11,841 $ 6,885 $ 59,357
Capital expenditures $ 78,524 $ 1,710 $ 4,603 $ 2,210 $ 87,047
Maintenance capital expenditures $ 165 $ 489 $ 330 $ - $ 984
Revenues:
External customers $ 15,673 $ 99,639 $ 1,003,093 $ 8,320 $ 1,126,725
Intersegment 3,498 - (3,498 ) - -
Total revenues of reportable segments $ 19,171 $ 99,639 $ 999,595 $ 8,320 $ 1,126,725
(1) Segment margin was calculated as revenues less cost of sales,
operating expenses and segment general and administrative
expenses, plus our share of the distributable cash generated by
our joint ventures. Segment margin excludes the non-cash effects
of our stock-based compensation plans, and includes the non-income
portion of payments received under direct financing leases. A
reconciliation of segment margin to income before income taxes is
presented for periods presented in the table at the end of this
release.
SEGMENT MARGIN RECONCILIATION TO INCOME BEFORE INCOME TAXES
Three Months Ended
June 30, 2009 June 30, 2008
(in thousands)
Segment margin $ 33,006 $ 35,006
Corporate general and administrative expenses (7,576 ) (5,757 )
Depreciation and amortization (16,133 ) (16,721 )
Net loss from disposal of surplus assets (60 ) (76 )
Interest expense, net (3,373 ) (2,039 )
Non-cash expenses not included in segment margin (126 ) (396 )
Other non-cash items affecting segment margin (1,099 ) (1,040 )
Income before income taxes $ 4,639 $ 8,977
Six Months Ended
June 30, 2009 June 30, 2008
(in thousands)
Segment margin $ 64,969 $ 59,357
Corporate general and administrative expenses (15,077 ) (10,986 )
Depreciation and amortization (31,552 ) (33,510 )
Net gain (loss) from disposal of surplus assets 158 (94 )
Interest expense, net (6,408 ) (3,708 )
Non-cash expenses not included in segment margin (842 ) (204 )
Other non-cash items affecting segment margin (717 ) (1,610 )
Income before income taxes $ 10,531 $ 9,245
CALCULATION OF NET INCOME PER COMMON UNIT
(in thousands, except per unit amounts)
Three Months Ended
June 30, 2009 June 30, 2008
Numerators for basic and diluted net income per common unit:
Net income attributable to Genesis Energy, L.P. $ 4,456 $ 7,328
Less: General partner's incentive distribution to be paid for the (1,427 ) (633 )
period
Add: Expense for Class B Membership Awards 2,353 -
Subtotal 5,382 6,695
Less: General partner 2% ownership (108 ) (134 )
Income available for common unitholders $ 5,274 $ 6,561
Denominator for basic per common unit:
Common Units 39,464 38,675
Denominator for diluted per common unit:
Common Units 39,464 38,675
Phantom Units 154 56
39,618 38,731
Basic net income per common unit $ 0.13 # $ 0.17 (1)
Diluted net income per common unit $ 0.13 $ 0.17 (1)
Six Months Ended
June 30, 2009 June 30, 2008
Numerators for basic and diluted net income per common unit:
Net income attributable to Genesis Energy, L.P. $ 9,746 $ 8,973
Less: General partner's incentive distribution to be paid for the (2,552 ) (1,062 )
period
Add: Expense for Class B Membership Awards 4,499 -
Subtotal 11,693 7,911
Less: General partner 2% ownership (234 ) (158 )
Income available for common unitholders $ 11,459 $ 7,753
Denominator for basic per common unit:
Common Units 39,460 38,464
Denominator for diluted per common unit:
Common Units 39,460 38,464
Phantom Units 132 50
39,592 38,514
Basic net income per common unit $ 0.29 $ 0.20 (1)
Diluted net income per common unit $ 0.29 $ 0.20 (1)
(1) Amounts have been adjusted to reflect the adoption of EITF
07-4, which requires the subtraction in this calculation of the
incentive distributions to be paid with respect to the quarter
rather than incentive distributions paid in the quarter.
Previously reported basic and diluted net income per common unit
was $0.17 and $0.21 for the three and six month periods,
respectively.
GAAP to Non-GAAP Financial
Measure Reconciliation
AVAILABLE CASH BEFORE RESERVES RECONCILIATION TO NET CASH FLOWS
FROM OPERATING ACTIVITIES
Three Months Ended
June 30, 2009 June 30, 2008 March 31, 2009
(in thousands)
Net cash flows from operating activities (GAAP measure) $ 15,909 $ 5,313 $ 3,157
Adjustments to reconcile net cash flow provided by operating
activities to Available Cash before reserves:
Maintenance capital expenditures (1,474 ) (208 ) (948 )
Proceeds from asset sales 52 181 405
Amortization and write-off of credit facility issuance costs (481 ) (267 ) (480 )
Effects of available cash from joint ventures not included in 34 329 217
operating cash flows
DG Marine earnings in excess of distributable cash (904 ) - (1,970 )
Other items affecting Available Cash 443 1,722 750
Net effect of changes in operating accounts not included in 8,629 19,115 20,211
calculation of Available Cash
Available Cash before Reserves (Non-GAAP measure) $ 22,208 $ 26,185 $ 21,342
CHANGES IN OPERATING ACCOUNTS NOT INCLUDED IN CALCULATION OF
AVAILABLE CASH BEFORE RESERVES
Three Months Ended
June 30, 2009 June 30, 2008 March 31, 2009
(in thousands)
Decrease (increase) in:
Accounts receivable $ (11,577 ) $ (36,495 ) $ 3,971
Inventories (10,534 ) (868 ) (2,851 )
Other current assets (3,491 ) 295 (2,373 )
Increase (decrease) in:
Accounts payable 13,409 13,491 (10,099 )
Accrued liabilities 3,564 4,462 (8,859 )
Net changes in components of operating assets and liabilities $ (8,629 ) $ (19,115 ) $ (20,211 )
This press release and the accompanying schedules include a non-generally accepted accounting principle ("non-GAAP") financial measure of available cash. The accompanying schedule provides a reconciliation of this non-GAAP financial measure to its most directly comparable financial measure calculated in accordance with generally accepted accounting principles in the United States of America ("GAAP"). Our non-GAAP financial measure should not be considered as an alternative to GAAP measures of liquidity or financial performance. We believe that investors benefit from having access to the same financial measures being utilized by management, lenders, analysts and other market participants.
Available cash. Available Cash before Reserves is a liquidity measure used by management to compare cash flows generated by us to the cash distribution paid to our limited partners and general partner. This is an important financial measure to the external users of financial statements, such as investors, commercial banks, research analysts and rating agencies, to assess: (1) the financial performance of our assets without regard to financing methods, capital structures, or historical cost basis; (2) the ability of our assets to generate cash sufficient to pay interest cost and support our indebtedness; (3) our operating performance and return on capital as compared to those of other companies in the midstream energy industry, without regard to financing and capital structure; and (4) the viability of projects and the overall rates of return on alternative investment opportunities. Lastly, Available Cash before Reserves (also referred to as distributable cash flow) is the quantitative standard used throughout the investment community with respect to publicly-traded partnerships. Available Cash before Reserves data presented in this press release may not be comparable to similarly titled measures of other companies as Available Cash before Reserves excludes some, but not all items that affect net income or loss and because these measures may vary among other companies.
We define available cash as net income or loss as adjusted for specific items, the most significant of which are the addition of non-cash expenses (such as depreciation), the substitution of cash generated by our joint ventures in lieu of our equity income attributable to such joint ventures, the elimination of gains and losses on asset sales (except those from the sale of surplus assets) and the subtraction of maintenance capital expenditures, which are expenditures that are necessary to sustain existing (but not to provide new sources of) cash flows.
SOURCE: Genesis Energy, L.P.
Genesis Energy, L.P. Bob Deere, 713-860-2516 Chief Financial Officer
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