August 6, 2019 - 6:00 AM EDT
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Genesis Energy, L.P. Reports Second Quarter 2019 Results

HOUSTON

Genesis Energy, L.P. (NYSE: GEL) today announced its second quarter results.

We generated the following financial results for the second quarter of 2019:

  • Net Income Attributable to Genesis Energy, L.P. of $40.1 million for the second quarter of 2019 compared to Net Income Attributable to Genesis Energy, L.P. of $11.0 million for the same period in 2018.
  • Cash Flows from Operating Activities of $81.6 million for the second quarter of 2019 compared to $64.5 million for the same period in 2018.
  • Total Segment Margin in the second quarter of 2019 of $184.1 million.
  • Available Cash before Reserves to common unitholders of $93.5 million for the second quarter of 2019, which provided 1.39X coverage for the quarterly distribution of $0.55 per common unit attributable to the second quarter.
  • We declared distributions on our preferred units in the form of a cash distribution of $0.7374 for each preferred unit, which equates to a cash distribution of approximately $18.7 million and is reflected as a reduction to Available Cash before Reserves to common unitholders.
  • Adjusted EBITDA of $174.1 million in the second quarter of 2019. Our bank leverage ratio, calculated consistent with our credit agreement, is 4.96X as of June 30, 2019 and is discussed further in this release.

Grant Sims, CEO of Genesis Energy, said, “We are pleased to announce a total Segment Margin of $184.1 million and a calculated bank leverage ratio of 4.96X for the second quarter. Despite several unexpected challenges over the previous twelve months, our diverse and market-leading businesses continue to perform, and we continue to naturally de-lever our balance sheet.

During the quarter, our offshore pipeline transportation segment saw consistent volumes across our asset footprint and continues to benefit from increasing activity in the deep water, including both in-field drilling and new standalone developments. The quarter was highlighted by first oil flow in late June from the LLOG operated Buckskin development. Buckskin is a subsea tie-back to the existing Lucius production platform and is 100% dedicated for the life of its lease term to our SEKCO system, our longest lateral in the Gulf of Mexico, and to our Poseidon system for ultimate transportation to shore. The development has an anticipated peak production rate of 30 kbd and we expect to see a meaningful financial impact as production ramps throughout the second half of 2019. Importantly, the Buckskin development required zero capital expenditures from us and highlights the significant operating leverage of our offshore footprint. It is also representative of the types of developments and opportunities we are seeing across our market leading asset base in the central Gulf of Mexico.

In early July, we experienced temporary throughput disruptions on our offshore systems as the producing community shut in production as Hurricane Barry made its way through the Gulf of Mexico. We experienced no permanent damage to our assets but do expect some negative financial impact to our third quarter results. Additional disruptions as we move through hurricane season could further negatively affect the third quarter.

Our onshore facilities and transportation segment performed as expected. Rail volumes delivered from Canada to our Baton Rouge complex resumed in April with increased volumes in May and June that exceeded the minimum take-or-pay volumes which allowed our main customer to utilize all of the pre-paid credits they accrued in the first quarter of 2019. We continue to monitor the easing of production curtailments by the government of Alberta and currently expect similar activity levels in the third quarter as we experienced in the second quarter. While there can be no guarantees, we believe based on current economic conditions, the incentive exists for rail volumes to return to fourth quarter 2018 levels by the end of 2019. The second quarter also benefited from a cash payment of $10 million associated with the resolution of a crude oil supply agreement.

Our soda ash operations experienced lower production volumes during the quarter due to a longer than anticipated planned move of our longwall mining machine. During the move, we proactively completed several additional debottlenecking projects and maintenance related items. The longwall move along with the additional work has successfully been completed and we are back running at full capacity. We remain on track in 2019 for our full year estimate in our soda ash business as we expect higher volumes along with stronger export pricing in the second half of the year. Our view of the international market supply/demand balance for the remainder of the year remains unchanged and we believe prices are likely to strengthen in the coming years. Our refinery services business performed as expected despite some unexpected challenges, including unplanned turnarounds and production issues at a number of our host refineries.

Our marine transportation segment continues to perform as expected and segment margin increased slightly for the sixth quarter in a row. As previously discussed, we continue to remain optimistic that we have seen the bottom for the quarterly segment contribution from our entire fleet of assets, and recent strength in near term day rates and utilization rates is reflective of an improving market.

Our businesses generated financial results that provided 1.39X coverage to our common unitholders, inclusive of a full quarter of cash distributions paid to our preferred unitholders, and a sequentially decreasing leverage ratio below 5.00X to 4.96X. Our target coverage ratio, including all preferred cash distributions, remains 1.4X to 1.6X and we expect our quarterly distribution rate will remain at $0.55 per common unit for the foreseeable future.

As we look towards the second half of the year, it is likely we will end up towards the lower end of our previous Adjusted EBITDA guidance for 2019 of $685-$715 million. Notwithstanding generally non-recurring challenges which can arise in any given quarter, the long term fundamentals across our businesses are strong and appear to us to be getting stronger. Therefore, we remain confident that the growth anticipated from our existing businesses keeps us on track to naturally de-lever our balance sheet and achieve our long-term leverage target of 4.00X in the coming years.

As always, we intend to be prudent, diligent and intelligent in achieving and maintaining the financial flexibility to allow the partnership to opportunistically build long-term value for all our stakeholders without ever losing our commitment to safe, reliable and responsible operations.”

Financial Results

Segment Margin

Variances between the second quarter of 2019 (the “2019 Quarter”) and the second quarter of 2018 (the “2018 Quarter”) in these components are explained below.

Segment margin results for the 2019 Quarter and 2018 Quarter were as follows:

 

Three Months Ended
June 30,

 

2019

 

2018

 

(in thousands)

Offshore pipeline transportation

$

76,528

 

 

$

71,602

 

Sodium minerals and sulfur services

57,705

 

 

64,542

 

Onshore facilities and transportation

35,920

 

 

25,744

 

Marine transportation

13,959

 

 

11,966

 

Total Segment Margin

$

184,112

 

 

$

173,854

 

Offshore pipeline transportation Segment Margin for the 2019 Quarter increased $4.9 million, or 7%, from the 2018 Quarter, primarily due to higher volumes on our crude oil pipeline systems. These increased volumes are the result of: (i) the continued receipt of additional volumes on our CHOPS and Poseidon systems due to deliveries from a third party pipeline that had insufficient capacity to deliver its committed volumes to shore, and (ii) first oil flow in the second half of the 2019 Quarter from the Buckskin and Hadrian North production fields, both of which are fully dedicated to our SEKCO pipeline and further downstream, our Poseidon oil pipeline system. As the Buckskin and Hadrian North volumes began near the end of the 2019 Quarter, contributions to segment margin were minimal in the period. However, we expect the contributions to increase throughout the remainder of 2019 and beyond. These increased volumes during the 2019 Quarter more than offset the approximately $3.9 million in platform fees, related to our interest in Poseidon Oil Pipeline, LLC ("Poseidon"), that we received during the 2018 Quarter. These minimum bill payments ended during June 2018.

Sodium minerals and sulfur services Segment Margin for the 2019 Quarter decreased $6.8 million, or 11% from the 2018 Quarter. This decrease is primarily due to lower volumes during the 2019 Quarter, including both our soda ash business (our "Alkali Business") and refinery services business. Soda ash volumes in the 2019 Quarter were negatively impacted by longer than expected mine downtime due to hoist maintenance and repairs performed during the move of our longwall mining machine to a different section of our mine. Our refinery services business continues to perform as expected. NaHS volumes slightly decreased during the 2019 Quarter due to lower demand from certain of our international customers, primarily located in South America, and our domestic pulp and paper customers.

Onshore facilities and transportation Segment Margin for the 2019 Quarter increased $10.2 million, or 40% from the 2018 Quarter. This increase is partially due to increased volumes at our Raceland and Scenic Station rail facilities during the 2019 Quarter. Our main customer associated with our Baton Rouge infrastructure exceeded the minimum take-or-pay volumes, including rail, terminal and pipeline movements, during the 2019 Quarter to a level that utilized and exceeded 100% of the prepaid transportation credits that accumulated during the first quarter of 2019. We also received a cash payment of $10 million during the 2019 Quarter associated with the resolution of a crude oil supply agreement. Additionally, while the volumes on our Texas system increased during the 2019 Quarter, we were only able to recognize our minimum volume commitment because our main customer utilized some of its prepaid transportation credits. This was partially offset by the margin recognized during the 2018 Quarter associated with our previously owned Powder River midstream assets that were divested in the fourth quarter of 2018.

Marine transportation Segment Margin for the 2019 Quarter increased $2.0 million, or 17%, from the 2018 Quarter. This increase in Segment Margin is primarily attributable to higher inland and offshore barge utilization during the 2019 Quarter along with an increase in average day rates in the market that have been advantageous in both spot and term contracts. While we have seen a slight uptick in day rates, we have continued to enter into short term contracts (less than a year) in both the inland and offshore markets because we believe the day rates currently being offered by the market are still near cyclical lows. This was partially offset by an increase in operating costs during the 2019 Quarter relative to the 2018 Quarter due to an increase in dry-docking costs in both our inland and offshore fleet.

Other Components of Net Income

In the 2019 Quarter, we recorded Net Income Attributable to Genesis Energy, L.P. of $40.1 million compared to Net Income Attributable to Genesis Energy, L.P. of $11.0 million in the 2018 Quarter. Net Income Attributable to Genesis Energy, L.P. in the 2019 Quarter benefited from an increase in segment margin of $10.3 million, positive changes in estimated abandonment costs for certain of our non-operating offshore gas assets of $15.7 million (which is included within "Offshore pipeline transportation operating costs" on the Unaudited Condensed Consolidated Statements of Operations), and an increase in equity in earnings of equity investees of $6.7 million. These were offset by higher depreciation, depletion, and amortization expense of $1.7 million and an unrealized loss from the valuation of the embedded derivative associated with our Class A Convertible Preferred units of $4.7 million during the 2019 Quarter compared to an unrealized loss of $0.2 million during the 2018 Quarter.

Earnings Conference Call

We will broadcast our Earnings Conference Call on Tuesday, August 6, 2019, at 8:30 a.m. Central time (9:30 a.m. Eastern time). This call can be accessed at www.genesisenergy.com. Choose the Investor Relations button. 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’ operations include offshore pipeline transportation, sodium minerals and sulfur services, onshore facilities and transportation and marine transportation. Genesis’ operations are primarily located in Texas, Louisiana, Arkansas, Mississippi, Alabama, Florida, Wyoming and the Gulf of Mexico.

GENESIS ENERGY, L.P.

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - UNAUDITED

(in thousands, except per unit amounts)

 

Three Months Ended
June 30,

 

Six Months Ended
June 30,

 

2019

 

2018

 

2019

 

2018

REVENUES

$

634,785

 

 

$

752,388

 

 

$

1,254,794

 

 

$

1,478,196

 

 

 

 

 

 

 

 

 

COSTS AND EXPENSES:

 

 

 

 

 

 

 

Costs of sales and operating expenses

455,072

 

 

600,279

 

 

923,728

 

 

1,180,077

 

General and administrative expenses

13,412

 

 

13,529

 

 

25,098

 

 

25,203

 

Depreciation, depletion and amortization

79,353

 

 

77,680

 

 

156,991

 

 

152,935

 

OPERATING INCOME

86,948

 

 

60,900

 

 

148,977

 

 

119,981

 

Equity in earnings of equity investees

15,046

 

 

8,324

 

 

28,043

 

 

18,896

 

Interest expense

(55,507

)

 

(57,909

)

 

(111,208

)

 

(114,045

)

Other expense

(4,692

)

 

(188

)

 

(7,668

)

 

(5,432

)

INCOME BEFORE INCOME TAXES

41,795

 

 

11,127

 

 

58,144

 

 

19,400

 

Income tax expense

(143

)

 

(256

)

 

(545

)

 

(631

)

NET INCOME

41,652

 

 

10,871

 

 

57,599

 

 

18,769

 

Net loss (income) attributable to noncontrolling interests

(1,532

)

 

126

 

 

(1,525

)

 

262

 

NET INCOME ATTRIBUTABLE TO GENESIS ENERGY, L.P.

$

40,120

 

 

$

10,997

 

 

$

56,074

 

 

$

19,031

 

Less: Accumulated distributions attributable to Class A Convertible Preferred Units

(18,684

)

 

(17,257

)

 

(37,099

)

 

(34,145

)

NET INCOME (LOSS) AVAILABLE TO COMMON UNITHOLDERS

$

21,436

 

 

$

(6,260

)

 

$

18,975

 

 

$

(15,114

)

NET INCOME (LOSS) PER COMMON UNIT:

 

 

 

 

 

 

 

Basic and Diluted

$

0.17

 

 

$

(0.05

)

 

$

0.15

 

 

$

(0.12

)

WEIGHTED AVERAGE OUTSTANDING COMMON UNITS:

 

 

 

 

 

 

 

Basic and Diluted

122,579

 

 

122,579

 

 

122,579

 

 

122,579

 

GENESIS ENERGY, L.P.

OPERATING DATA - UNAUDITED

 

 

Three Months Ended
June 30,

 

Six Months Ended
June 30,

 

2019

 

2018

 

2019

 

2018

Offshore Pipeline Transportation Segment

 

 

 

 

 

 

 

Crude oil pipelines (barrels/day unless otherwise noted):

 

 

 

 

 

 

 

CHOPS

228,931

 

 

181,291

 

 

235,307

 

 

190,455

 

Poseidon (1)

264,802

 

 

225,559

 

 

259,167

 

 

232,090

 

Odyssey (1)

150,039

 

 

90,326

 

 

150,953

 

 

99,793

 

GOPL

11,990

 

 

9,110

 

 

10,173

 

 

9,431

 

Offshore crude oil pipelines total

655,762

 

 

506,286

 

 

655,600

 

 

531,769

 

 

 

 

 

 

 

 

 

Natural gas transportation volumes (MMbtus/d) (1)

445,734

 

 

431,853

 

 

432,888

 

 

453,910

 

 

 

 

 

 

 

 

 

Sodium Minerals and Sulfur Services Segment

 

 

 

 

 

 

 

NaHS (dry short tons sold)

34,527

 

 

38,090

 

 

70,270

 

 

75,304

 

Soda Ash volumes (short tons sold)

824,881

 

 

936,000

 

 

1,695,410

 

 

1,853,000

 

NaOH (caustic soda) volumes (dry short tons sold) (2)

20,525

 

 

27,573

 

 

41,327

 

 

57,833

 

 

 

 

 

 

 

 

 

Onshore Facilities and Transportation Segment

 

 

 

 

 

 

 

Crude oil pipelines (barrels/day):

 

 

 

 

 

 

 

Texas

47,229

 

 

20,643

 

 

45,117

 

 

25,060

 

Jay

10,171

 

 

13,004

 

 

10,823

 

 

14,947

 

Mississippi

6,032

 

 

6,367

 

 

5,974

 

 

6,986

 

Louisiana (3)

131,456

 

 

151,807

 

 

113,738

 

 

133,598

 

Wyoming

 

 

32,210

 

 

 

 

31,703

 

Onshore crude oil pipelines total

194,888

 

 

224,031

 

 

175,652

 

 

212,294

 

 

 

 

 

 

 

 

 

Free State- CO2 Pipeline (Mcf/day)

76,297

 

 

103,867

 

 

91,062

 

 

100,308

 

 

 

 

 

 

 

 

 

Crude oil and petroleum products sales (barrels/day)

30,788

 

 

49,278

 

 

32,262

 

 

50,818

 

 

 

 

 

 

 

 

 

Rail load/unload volumes (barrels/day) (4)

99,519

 

 

53,005

 

 

92,345

 

 

52,844

 

 

 

 

 

 

 

 

 

Marine Transportation Segment

 

 

 

 

 

 

 

Inland Fleet Utilization Percentage (5)

98.7

%

 

93.5

%

 

97.7

%

 

92.9

%

Offshore Fleet Utilization Percentage (5)

93.9

%

 

92.0

%

 

95.1

%

 

93.4

%

(1)

Volumes for our equity method investees are presented on a 100% basis. We own 64% of Poseidon and 29% of Odyssey, as well as equity interests in various other entities.

(2)

Caustic soda sales volumes also include volumes sold from our Alkali Business.

(3)

Total daily volume for the three and six months ended June 30, 2019 includes 64,574 and 58,472 barrels per day, respectively, of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines. Total daily volume for the three and six months ended June 30, 2018 includes 69,614 and 55,053 barrels per day, respectively, of intermediate refined products associated with our Port of Baton Rouge Terminal pipelines.

(4)

Indicates total barrels for which fees were charged for unloading at all rail facilities.

(5)

Utilization rates are based on a 365 day year, as adjusted for planned downtime and dry-docking.


GENESIS ENERGY, L.P.

CONDENSED CONSOLIDATED BALANCE SHEETS - UNAUDITED

(in thousands, except number of units)

 

June 30,
2019

 

December 31,
2018

ASSETS

 

 

 

Cash and cash equivalents

$

9,579

 

 

$

10,300

 

Accounts receivable - trade, net

297,847

 

 

323,462

 

Inventories

84,094

 

 

73,531

 

Other current assets

44,877

 

 

35,986

 

Total current assets

436,397

 

 

443,279

 

Fixed assets and mineral leaseholds, net

4,903,204

 

 

4,977,514

 

Investment in direct financing leases, net

112,428

 

 

116,925

 

Equity investees

344,583

 

 

355,085

 

Intangible assets, net

147,178

 

 

162,602

 

Goodwill

301,959

 

 

301,959

 

Right of use assets, net

191,497

 

 

 

Other assets, net

117,697

 

 

121,707

 

Total assets

$

6,554,943

 

 

$

6,479,071

 

LIABILITIES AND CAPITAL

 

 

 

Accounts payable - trade

$

132,026

 

 

$

127,327

 

Accrued liabilities

220,975

 

 

205,507

 

Total current liabilities

353,001

 

 

332,834

 

Senior secured credit facility

967,000

 

 

970,100

 

Senior unsecured notes, net of debt issuance costs

2,466,137

 

 

2,462,363

 

Deferred tax liabilities

12,911

 

 

12,576

 

Other long-term liabilities

397,690

 

 

259,198

 

Total liabilities

4,196,739

 

 

4,037,071

 

Mezzanine capital:

 

 

 

Class A convertible preferred units

790,115

 

 

761,466

 

Partners' capital:

 

 

 

Common unitholders

1,575,599

 

 

1,690,799

 

Accumulated other comprehensive income

939

 

 

939

 

Noncontrolling interests

(8,449

)

 

(11,204

)

Total partners' capital

1,568,089

 

 

1,680,534

 

Total liabilities, mezzanine capital and partners' capital

$

6,554,943

 

 

$

6,479,071

 

 

 

 

 

Common Units Data:

 

 

 

Total common units outstanding

122,579,218

 

 

122,579,218

 

GENESIS ENERGY, L.P.

RECONCILIATION OF NET INCOME TO SEGMENT MARGIN - UNAUDITED

(in thousands)

 

Three Months Ended
June 30,

 

2019

 

2018

Net income attributable to Genesis Energy, L.P.

$

40,120

 

 

$

10,997

 

Corporate general and administrative expenses

13,502

 

 

13,466

 

Depreciation, depletion, amortization and accretion

66,104

 

 

79,862

 

Interest expense, net

55,507

 

 

57,909

 

Income tax expense

143

 

 

256

 

Equity compensation adjustments

 

 

50

 

Provision for leased items no longer in use

(182

)

 

(47

)

Plus (minus) Select Items, net

8,918

 

 

11,361

 

Segment Margin (1)

$

184,112

 

 

$

173,854

 

(1)

See definition of Segment Margin later in this press release.

GENESIS ENERGY, L.P.

RECONCILIATIONS OF NET INCOME TO ADJUSTED EBITDA AND AVAILABLE CASH BEFORE RESERVES- UNAUDITED

(in thousands)

 

 

Three Months Ended
June 30,

 

2019

 

2018

 

(in thousands)

Net income attributable to Genesis Energy, L.P.

$

40,120

 

 

$

10,997

 

Interest expense, net

55,507

 

 

57,909

 

Income tax expense

143

 

 

256

 

Depreciation, depletion, amortization, and accretion

66,104

 

 

79,862

 

EBITDA

161,874

 

 

149,024

 

Plus (minus) Select Items, net

12,270

 

 

14,742

 

Adjusted EBITDA, net

174,144

 

 

163,766

 

Maintenance capital utilized(1)

(6,425

)

 

(4,700

)

Interest expense, net

(55,507

)

 

(57,909

)

Cash tax expense

(60

)

 

(150

)

Cash distributions to preferred unitholders(2)

(18,684

)

 

 

Other

 

 

(7

)

Available Cash before Reserves(3)

$

93,468

 

 

$

101,000

 

(1)

Maintenance capital expenditures in the 2019 Quarter and 2018 Quarter were $25.2 million and $22.2 million, respectively. Our maintenance capital expenditures are principally associated with our alkali and marine transportation businesses.

(2)

Distributions to preferred unitholders that is attributable to the 2019 Quarter and payable on August 14, 2019 to unitholders of record at the close of business on July 31, 2019.

(3)

Represents the Available Cash before Reserves to common unitholders.

GENESIS ENERGY, L.P.

RECONCILIATION OF NET CASH FLOWS FROM OPERATING ACTIVITIES TO ADJUSTED EBITDA - UNAUDITED

(in thousands)

 

 

Three Months Ended
June 30,

 

2019

 

2018

Cash Flows from Operating Activities

$

81,589

 

 

$

64,488

 

Adjustments to reconcile net cash flow provided by operating activities to Adjusted EBITDA:

 

 

 

Interest Expense, net

55,507

 

 

57,909

 

Amortization of debt issuance costs and discount

(2,688

)

 

(2,659

)

Effects of available cash from equity method investees not included in operating cash flows

5,386

 

 

8,551

 

Net effect of changes in components of operating assets and liabilities

41,107

 

 

30,373

 

Non-cash effect of long-term incentive compensation expense

(2,258

)

 

(1,551

)

Expenses related to acquiring or constructing growth capital assets

341

 

 

2,896

 

Differences in timing of cash receipts for certain contractual arrangements (1)

(9,848

)

 

(1,148

)

Other items, net

5,008

 

 

4,907

 

Adjusted EBITDA

$

174,144

 

 

$

163,766

 

(1)

Includes the difference in timing of cash receipts from customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. For purposes of our Non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.

GENESIS ENERGY, L.P.

ADJUSTED DEBT-TO-ADJUSTED CONSOLIDATED EBITDA RATIO - UNAUDITED

(in thousands)

 

 

 

June 30, 2019

Senior secured credit facility

 

$

967,000

 

Senior unsecured notes

 

2,466,137

 

Less: Outstanding inventory financing sublimit borrowings

 

(30,300

)

Less: Cash and cash equivalents

 

(9,579

)

Adjusted Debt (1)

 

$

3,393,258

 

 

 

 

 

 

Pro Forma LTM

 

 

June 30, 2019

Consolidated EBITDA (per our senior secured credit facility) (2)

 

$

689,428

 

Acquisitions, material projects and other Consolidated EBITDA adjustments (3)

 

(5,242

)

Adjusted Consolidated EBITDA (per our senior secured credit facility) (4)

 

$

684,186

 

 

 

 

Adjusted Debt-to-Adjusted Consolidated EBITDA

 

4.96X

(1)

We define Adjusted Debt as the amounts outstanding under our senior secured credit facility and senior unsecured notes (including any unamortized premiums or discounts) less the amount outstanding under our inventory financing sublimit, less cash and cash equivalents on hand at the end of the period.

(2)

Consolidated EBITDA for the four-quarter period ending with the most recent quarter, as calculated under our senior secured credit facility.

(3)

This amount reflects the adjustment we are permitted to make under our senior secured credit facility for purposes of calculating compliance with our leverage ratio. It includes a pro rata portion of projected future annual EBITDA from material projects (i.e. organic growth) and includes Adjusted EBITDA (using historical amounts and other permitted amounts) since the beginning of the calculation period attributable to each acquisition completed during such calculation period, regardless of the date on which such acquisition was actually completed. This adjustment may not be indicative of future results.

(4)

Adjusted Consolidated EBITDA for the four-quarter period ending with the most recent quarter, as calculated under our senior secured credit facility.

This press release includes forward-looking statements as defined under federal law. Although we believe that our expectations are based upon reasonable assumptions, we can give no assurance that our goals will be achieved. Actual results may vary materially. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that we expect, believe or anticipate will or may occur in the future, including but not limited to statements relating to future financial and operating results and our strategy and plans, are forward-looking statements, and historical performance is not necessarily indicative of future performance. Those 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 our control, that could cause results to differ materially from those expected by management. Such risks and uncertainties include, but are not limited to, weather, political, economic and market conditions, including a decline in the price and market demand for products, the timing and success of business development efforts and other uncertainties. Those and other applicable uncertainties, factors and risks that may affect those forward-looking statements are described more fully in our Annual Report on Form 10-K for the year ended December 31, 2018 filed with the Securities and Exchange Commission and other filings, including our Current Reports on Form 8-K and Quarterly Reports on Form 10-Q. We undertake no obligation to publicly update or revise any forward-looking statement.

NON-GAAP MEASURES

This press release and the accompanying schedules include non-generally accepted accounting principle (non-GAAP) financial measures of Adjusted EBITDA and total Available Cash before Reserves. In this press release, we also present total Segment Margin as if it were a non-GAAP measure. Our Non-GAAP measures may not be comparable to similarly titled measures of other companies because such measures may include or exclude other specified items. The accompanying schedules provide reconciliations of these non-GAAP financial measures to their most directly comparable financial measures calculated in accordance with generally accepted accounting principles in the United States of America (GAAP). Our non-GAAP financial measures should not be considered (i) as alternatives to GAAP measures of liquidity or financial performance or (ii) as being singularly important in any particular context; they should be considered in a broad context with other quantitative and qualitative information. Our Available Cash before Reserves, Adjusted EBITDA and total Segment Margin measures are just three of the relevant data points considered from time to time.

When evaluating our performance and making decisions regarding our future direction and actions (including making discretionary payments, such as quarterly distributions) our board of directors and management team have access to a wide range of historical and forecasted qualitative and quantitative information, such as our financial statements; operational information; various non-GAAP measures; internal forecasts; credit metrics; analyst opinions; performance, liquidity and similar measures; income; cash flow; and expectations for us, and certain information regarding some of our peers. Additionally, our board of directors and management team analyze, and place different weight on, various factors from time to time. We believe that investors benefit from having access to the same financial measures being utilized by management, lenders, analysts and other market participants. We attempt to provide adequate information to allow each individual investor and other external user to reach her/his own conclusions regarding our actions without providing so much information as to overwhelm or confuse such investor or other external user.

AVAILABLE CASH BEFORE RESERVES

Purposes, Uses and Definition

Available Cash before Reserves, also referred to as distributable cash flow, is a quantitative standard used throughout the investment community with respect to publicly traded partnerships and is commonly used as a supplemental financial measure by management and by external users of financial statements such as investors, commercial banks, research analysts and rating agencies, to aid in assessing, among other things:

(1) the financial performance of our assets;

(2) our operating performance;

(3) the viability of potential projects, including our cash and overall return on alternative capital investments as compared to those of other companies in the midstream energy industry;

(4) the ability of our assets to generate cash sufficient to satisfy certain non-discretionary cash requirements, including interest payments and certain maintenance capital requirements; and

(5) our ability to make certain discretionary payments, such as distributions on our preferred and common units, growth capital expenditures, certain maintenance capital expenditures and early payments of indebtedness.

We define Available Cash before Reserves ("Available Cash before Reserves") as Adjusted EBITDA as adjusted for certain items, the most significant of which in the relevant reporting periods have been the sum of maintenance capital utilized, net cash interest expense, cash tax expense, and cash distributions paid to our Class A convertible preferred unitholders.

Disclosure Format Relating to Maintenance Capital

We use a modified format relating to maintenance capital requirements because our maintenance capital expenditures vary materially in nature (discretionary vs. non-discretionary), timing and amount from time to time. We believe that, without such modified disclosure, such changes in our maintenance capital expenditures could be confusing and potentially misleading to users of our financial information, particularly in the context of the nature and purposes of our Available Cash before Reserves measure. Our modified disclosure format provides those users with information in the form of our maintenance capital utilized measure (which we deduct to arrive at Available Cash before Reserves). Our maintenance capital utilized measure constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period.

Maintenance Capital Requirements

Maintenance Capital Expenditures

Maintenance capital expenditures are capitalized costs that are necessary to maintain the service capability of our existing assets, including the replacement of any system component or equipment which is worn out or obsolete. Maintenance capital expenditures can be discretionary or non-discretionary, depending on the facts and circumstances.

Initially, substantially all of our maintenance capital expenditures were (a) related to our pipeline assets and similar infrastructure, (b) non-discretionary in nature and (c) immaterial in amount as compared to our Available Cash before Reserves measure. Those historical expenditures were non-discretionary (or mandatory) in nature because we had very little (if any) discretion as to whether or when we incurred them. We had to incur them in order to continue to operate the related pipelines in a safe and reliable manner and consistently with past practices. If we had not made those expenditures, we would not have been able to continue to operate all or portions of those pipelines, which would not have been economically feasible. An example of a non-discretionary (or mandatory) maintenance capital expenditure would be replacing a segment of an old pipeline because one can no longer operate that pipeline safely, legally and/or economically in the absence of such replacement.

As we exist today, a substantial amount of our maintenance capital expenditures from time to time will be (a) related to our assets other than pipelines, such as our marine vessels, trucks and similar assets, (b) discretionary in nature and (c) potentially material in amount as compared to our Available Cash before Reserves measure. Those expenditures will be discretionary (or non-mandatory) in nature because we will have significant discretion as to whether or when we incur them. We will not be forced to incur them in order to continue to operate the related assets in a safe and reliable manner. If we chose not make those expenditures, we would be able to continue to operate those assets economically, although in lieu of maintenance capital expenditures, we would incur increased operating expenses, including maintenance expenses. An example of a discretionary (or non-mandatory) maintenance capital expenditure would be replacing an older marine vessel with a new marine vessel with substantially similar specifications, even though one could continue to economically operate the older vessel in spite of its increasing maintenance and other operating expenses.

In summary, as we continue to expand certain non-pipeline portions of our business, we are experiencing changes in the nature (discretionary vs. non-discretionary), timing and amount of our maintenance capital expenditures that merit a more detailed review and analysis than was required historically. Management’s recently increasing ability to determine if and when to incur certain maintenance capital expenditures is relevant to the manner in which we analyze aspects of our business relating to discretionary and non-discretionary expenditures. We believe it would be inappropriate to derive our Available Cash before Reserves measure by deducting discretionary maintenance capital expenditures, which we believe are similar in nature in this context to certain other discretionary expenditures, such as growth capital expenditures, distributions/dividends and equity buybacks. Unfortunately, not all maintenance capital expenditures are clearly discretionary or non-discretionary in nature. Therefore, we developed a measure, maintenance capital utilized, that we believe is more useful in the determination of Available Cash before Reserves. Our maintenance capital utilized measure, which is described in more detail below, constitutes a proxy for non-discretionary maintenance capital expenditures and it takes into consideration the relationship among maintenance capital expenditures, operating expenses and depreciation from period to period.

Maintenance Capital Utilized

We believe our maintenance capital utilized measure is the most useful quarterly maintenance capital requirements measure to use to derive our Available Cash before Reserves measure. We define our maintenance capital utilized measure as that portion of the amount of previously incurred maintenance capital expenditures that we utilize during the relevant quarter, which would be equal to the sum of the maintenance capital expenditures we have incurred for each project/component in prior quarters allocated ratably over the useful lives of those projects/components.

Because we did not initially use our maintenance capital utilized measure, our future maintenance capital utilized calculations will reflect the utilization of solely those maintenance capital expenditures incurred since December 31, 2013.

ADJUSTED EBITDA

Purposes, Uses and Definition

Adjusted EBITDA is commonly used as a supplemental financial measure by management and by external users of financial statements such as investors, commercial banks, research analysts and rating agencies, to aid in assessing, among other things:

(1) the financial performance of our assets without regard to financing methods, capital structures or historical cost basis;

(2) our operating performance as compared to those of other companies in the midstream energy industry, without regard to financing and capital structure;

(3) the viability of potential projects, including our cash and overall return on alternative capital investments as compared to those of other companies in the midstream energy industry;

(4) the ability of our assets to generate cash sufficient to satisfy certain non-discretionary cash requirements, including interest payments and certain maintenance capital requirements; and

(5) our ability to make certain discretionary payments, such as distributions on our preferred and common units, growth capital expenditures, certain maintenance capital expenditures and early payments of indebtedness.

We define Adjusted EBITDA (“Adjusted EBITDA”) as earnings before interest, taxes, depreciation and amortization (including impairment, write-offs, accretion and similar items, often referred to as EBITDA) after eliminating other non-cash revenues, expenses, gains, losses and charges (including any loss on asset dispositions), plus or minus certain other select items that we view as not indicative of our core operating results (collectively, "Select Items"). Although, we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results. The most significant Select Items in the relevant reporting periods are set forth below.

The table below includes the Select Items discussed above as applicable to the reconciliation of Adjusted EBITDA and Available Cash before Reserves to net income:

 

 

Three Months Ended
June 30,

 

 

2019

 

2018

I.

Applicable to all Non-GAAP Measures

 

 

 

 

Differences in timing of cash receipts for certain contractual arrangements (1)

$

(9,848

)

 

$

(1,148

)

 

Adjustment regarding direct financing leases (2)

2,079

 

 

1,884

 

 

Certain non-cash items:

 

 

 

 

Unrealized loss on derivative transactions excluding fair value hedges, net of changes in inventory value

9,065

 

 

641

 

 

Adjustment regarding equity investees (3)

5,675

 

 

10,037

 

 

Other

1,947

 

 

(53

)

 

Sub-total Select Items, net (4)

8,918

 

 

11,361

 

II.

Applicable only to Adjusted EBITDA and Available Cash before Reserves

 

 

 

 

Certain transaction costs (5)

341

 

 

2,896

 

 

Equity compensation adjustments

 

 

61

 

 

Other

3,011

 

 

424

 

 

Total Select Items, net (6)

$

12,270

 

 

$

14,742

 

(1)

Includes the difference in timing of cash receipts from customers during the period and the revenue we recognize in accordance with GAAP on our related contracts. For purposes of our Non-GAAP measures, we add those amounts in the period of payment and deduct them in the period in which GAAP recognizes them.

(2)

Represents the net effect of adding cash receipts from direct financing leases and deducting expenses relating to direct financing leases.

(3)

Represents the net effect of adding distributions from equity investees and deducting earnings of equity investees net to us.

(4)

Represents all Select Items applicable to Segment Margin, Adjusted EBITDA and Available Cash before Reserves.

(5)

Represents transaction costs relating to certain merger, acquisition, transition, and financing transactions incurred in acquisition activities.

(6)

Represents Select Items applicable to Adjusted EBITDA and Available Cash before Reserves.

SEGMENT MARGIN

Our chief operating decision maker (our Chief Executive Officer) evaluates segment performance based on a variety of measures including Segment Margin, segment volumes where relevant and capital investment. We define Segment Margin as revenues less product costs, operating expenses, and segment general and administrative expenses, after eliminating gain or loss on sale of assets, plus or minus applicable Select Items. Although, we do not necessarily consider all of our Select Items to be non-recurring, infrequent or unusual, we believe that an understanding of these Select Items is important to the evaluation of our core operating results.

Genesis Energy, L.P.
Ryan Sims
SVP - Finance and Corporate Development
(713) 860-2521


Source: Business Wire (August 6, 2019 - 6:00 AM EDT)

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