UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC  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): July 30, 2024

ENTERPRISE PRODUCTS PARTNERS L.P.
(Exact Name of Registrant as Specified in Charter)


Delaware
1-14323
76-0568219
(State or Other Jurisdiction of
(Commission File Number)
(IRS Employer
Incorporation)
 
Identification No.)

1100 Louisiana Street, 10th Floor, Houston, Texas
77002
(Address of Principal Executive Offices)
(Zip Code)

Registrant’s telephone number, including area code:  (713) 381-6500

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:

Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Securities Exchange Act of 1934:

Title of Each Class
Trading Symbol(s)
Name of Each Exchange On Which Registered
Common Units
EPD
New York Stock Exchange

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

   Emerging growth company 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.   



Item 2.02.  Results of Operations and Financial Condition.

On July 30, 2024, Enterprise Products Partners L.P. (“Enterprise” or the “Partnership”) (NYSE:EPD) issued a press release announcing its financial and operating results for the three months ended June 30, 2024, and will hold a webcast conference call discussing those results.  A copy of the earnings press release is furnished as Exhibit 99.1 to this Current Report, which is hereby incorporated by reference into this Item 2.02.

Item 8.01.  Other Events.

The information presented in this Item 8.01 has not been reviewed by our independent auditors and is subject to revision as we prepare our consolidated financial statements as of and for the three and six months ended June 30, 2024.  This information is not a comprehensive statement of our financial results for the quarterly period ended June 30, 2024, and our actual results may differ materially from these estimates as a result of the completion of our financial closing process, final adjustments (if any) and other developments arising between now and the time that our financial results for the three and six months ended June 30, 2024 are finalized.

Unless the context requires otherwise, references to “we,” “us” or “our” within this Item 8.01 are intended to mean the business and operations of the Partnership and its consolidated subsidiaries.

Forward-Looking Statements

Certain matters discussed in this Current Report are forward-looking statements that involve certain risks and uncertainties, such as Enterprise’s expectations regarding future results, capital expenditures, project completions, liquidity and financial market conditions.  These risks and uncertainties include, among other things, insufficient cash from operations, adverse market conditions, governmental regulations and other factors discussed in Enterprise’s filings with the U.S. Securities and Exchange Commission.  If any of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results or outcomes may vary materially from those expected.  Enterprise disclaims any intention or obligation to update publicly or reverse such statements, whether as a result of new information, future events or otherwise.

1

Condensed Consolidated Financial Highlights — Second Quarter 2024 Results (Unaudited)

On July 30, 2024, the Partnership announced its consolidated financial results for the three and six months ended June 30, 2024. The following table presents condensed consolidated financial highlights for the periods and at the dates indicated (dollars in millions, except per unit amounts):

   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
 
   
(Unaudited)
   
(Unaudited)
 
Selected Income Statement Data:
                       
   Revenues
 
$
13,483
   
$
10,651
   
$
28,243
   
$
23,095
 
   Costs and expenses
   
(11,819
)
   
(9,193
)
   
(24,859
)
   
(20,007
)
   Equity in income of unconsolidated affiliates
   
101
     
121
     
203
     
225
 
   Operating income
   
1,765
     
1,579
     
3,587
     
3,313
 
   Interest expense
   
(332
)
   
(302
)
   
(663
)
   
(616
)
   Other, net
   
4
     
19
     
17
     
31
 
   Income before income taxes
   
1,437
     
1,296
     
2,941
     
2,728
 
   Provision for income taxes
   
(15
)
   
(13
)
   
(36
)
   
(23
)
   Net income
   
1,422
     
1,283
     
2,905
     
2,705
 
   Net income attributable to noncontrolling interests
   
(16
)
   
(29
)
   
(42
)
   
(60
)
   Net income attributable to preferred units
   
(1
)
   
(1
)
   
(2
)
   
(2
)
   Net income attributable to common unitholders
 
$
1,405
   
$
1,253
   
$
2,861
   
$
2,643
 
   Earnings per unit, fully diluted
 
$
0.64
   
$
0.57
   
$
1.30
   
$
1.20
 
 
                               
  Gross Operating Margin by Segment:
                               
   NGL Pipelines & Services
 
$
1,325
   
$
1,110
   
$
2,665
   
$
2,322
 
   Crude Oil Pipelines & Services
   
417
     
422
     
828
     
819
 
   Natural Gas Pipelines & Services
   
293
     
238
     
605
     
552
 
   Petrochemical & Refined Products Services
   
392
     
383
     
836
     
802
 
   Total segment gross operating margin (1)
   
2,427
     
2,153
     
4,934
     
4,495
 
   Net adjustment for shipper make-up rights (2)
   
(15
)
   
28
     
(32
)
   
21
 
   Non-GAAP total gross operating margin
 
$
2,412
   
$
2,181
   
$
4,902
   
$
4,516
 
                                 
   
June 30,
   
December 31,
                 
   
2024
   
2023
                 
   
(Unaudited)
                         
Selected Balance Sheet Data:
                               
   Cash and cash equivalents (unrestricted)
 
$
138
   
$
180
                 
   Total assets
   
73,561
     
70,982
                 
   Total debt principal outstanding, including
      current maturities
   
30,621
     
29,021
                 
   Partners’ equity
   
27,989
     
27,673
                 
   Noncontrolling interests
   
808
     
1,086
                 

(1)
Within the context of this table, total segment gross operating margin represents a subtotal and corresponds to measures similarly titled within the financial statement footnotes provided in the Partnership’s quarterly and annual filings with the U.S. Securities and Exchange Commission (“SEC”).
(2)
Gross operating margin by segment for NGL Pipelines & Services and Crude Oil Pipelines & Services reflects adjustments for non-refundable deferred transportation revenues relating to the make-up rights of committed shippers on certain major pipeline projects. These adjustments are included in management’s evaluation of segment results. However, these adjustments are excluded from non-GAAP total gross operating margin in compliance with guidance from the SEC.
For the second quarter of 2024, depreciation, amortization and accretion expenses totaled $611 million and cash distributions received from unconsolidated affiliates were $131 million. In addition, for the second quarter of 2024, total capital investments were approximately $1.3 billion, which includes $245 million of sustaining capital expenditures.
2

Highlights of Second Quarter of 2024 Segment ResultsNet income attributable to common unitholders of the Partnership for the second quarter of 2024 was $1.4 billion compared to $1.3 billion for the second quarter of 2023. On a fully diluted basis, net income attributable to common unitholders for the second quarter of 2024 was $0.64 per unit compared to $0.57 per unit for the second quarter of 2023. The Partnership reported total gross operating margin of $2.4 billion for the second quarter of 2024 compared to $2.2 billion for the second quarter of 2023.
Below is a review of each business segment’s performance for the second quarter of 2024.
NGL Pipelines & Services – Gross operating margin from the NGL Pipelines & Services segment was $1.3 billion for the second quarter of 2024 compared to $1.1 billion for the second quarter of 2023.

Gross operating margin from the natural gas processing business and related natural gas liquids ("NGL”) marketing activities was $386 million for the second quarter of 2024, an increase of 25 percent compared to $310 million for the second quarter of 2023. Total fee-based natural gas processing volumes increased 837 million cubic feet per day (“MMcf/d”), or 15 percent, to a record 6.5 billion cubic feet per day (“Bcf/d”) in the second quarter of 2024, compared to the second quarter of 2023. Total equity NGL-equivalent production volumes were 217 thousand barrels per day (“MBPD”) and 173 MBPD in the second quarters of 2024 and 2023, respectively. The following highlights summarize selected variances within this business, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from Permian natural gas processing facilities, including the Midland and Delaware Basin assets, increased $81 million primarily attributable to the addition of four natural gas processing plants that went into service during the last twelve months. These plants contributed to higher fee-based processing volumes and higher equity NGL-equivalent volumes for the Midland and Delaware Basin assets. These assets also benefited from higher average processing margins, primarily due to the impact of hedging. Midland Basin fee-based processing volumes increased 342 MMcf/d stemming from the addition of the Poseidon and Leonidas natural gas processing trains, which were placed in service in July 2023 and late March 2024, respectively. Midland Basin equity NGL-equivalent production volumes increased 23 MBPD. Delaware Basin fee-based processing volumes increased 359 MMcf/d benefiting from the addition of the Mentone 2 and Mentone 3 processing trains, which were placed in service in October 2023 and late March 2024, respectively. Delaware Basin equity NGL-equivalent production volumes increased 3 MBPD.
Gross operating margin from South Texas natural gas processing facilities increased $16 million primarily due to higher average processing margins, higher fee-based processing volumes, and lower operating costs. South Texas fee-based processing volumes increased 153 MMcf/d. Equity NGL-equivalent production volumes were essentially flat.
Gross operating margin from Rockies natural gas processing facilities increased $6 million primarily due to higher fee-based processing volumes, which increased 256 MMcf/d, and higher equity NGL-equivalent volumes, which increased 9 MBPD.
Gross operating margin from NGL marketing activities decreased $34 million primarily due to lower average sales margins, partially offset by higher sales volumes.

Gross operating margin from the NGL pipelines and storage business was $701 million for the second quarter of 2024, an increase of $103 million compared to the second quarter of 2023. Total NGL pipeline transportation volumes were a record 4.3 million barrels per day (“BPD”) in the second quarter of 2024, a 9 percent increase over the second quarter of 2023. Total NGL marine terminal volumes increased 15 percent, or 111 MBPD, to 876 MBPD for the second quarter of 2024, compared to the second quarter in 2023. The following highlights summarize selected variances within this business, with results for the second quarter of 2024 as compared to the second quarter of 2023:
On a combined basis, the pipelines serving the Permian and Rocky Mountain regions reported a $21 million increase in gross operating margin. This includes the Mid-America, Seminole, Shin Oak, and Chaparral NGL pipeline systems. The variance was primarily driven by a 179 MBPD, net to our interest, increase in transportation volumes and higher average transportation fees.
3


Eastern ethane pipelines, which include the ATEX and Aegis pipelines, reported a $21 million increase in gross operating margin largely due to higher transportation revenues. Eastern ethane pipeline volumes decreased 48 MBPD.
Gross operating margin from the Enterprise Hydrocarbons Terminal (“EHT”) increased $18 million primarily due to a 72 MBPD increase in LPG export volumes and higher average loading fees. Gross operating margin from the Morgan’s Point Ethane Export Terminal increased $4 million primarily due to a 39 MBPD increase in export volumes. Gross operating margin from the Houston Ship Channel Pipeline System increased $9 million in connection with a 139 MBPD increase in transportation volumes.
Gross operating margin from the Mont Belvieu area storage complex increased $18 million primarily due to higher storage revenues.

Gross operating margin from the NGL fractionation business was $238 million for the second quarter of 2024 compared to $202 million for the second quarter of 2023. Total NGL fractionation volumes increased 253 MBPD to a record 1.6 million BPD for the second quarter of 2024, compared to the second quarter of 2023. The following highlights summarize selected variances within this business, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from our Mont Belvieu area NGL fractionation complex increased $25 million primarily due to a 216 MBPD, net to our interest, increase in fractionation volumes, partially offset by higher operating costs. The increase in volume and gross operating margin was primarily due to the addition of the 12th NGL fractionator at this facility, which was placed in service in July 2023. Fractionation volumes also benefited from the acquisition of the remaining 25 percent equity interest in EF78 LLC in February 2024.
Crude Oil Pipelines & Services – Gross operating margin from the Crude Oil Pipelines & Services segment was $417 million for the second quarter of 2024 compared to $422 million for the second quarter of 2023. Gross operating margin for the second quarter of 2024 includes non-cash, mark-to-market gains of $8 million related to hedging activities compared to non-cash, mark-to-market losses of $7 million in the second quarter of 2023. Total crude oil pipeline transportation volumes were 2.5 million BPD in the second quarter of 2024 compared to 2.4 million BPD for the second quarter of 2023. Total crude oil marine terminal volumes were 977 MBPD this quarter, a 163 MBPD increase compared to the second quarter of 2023. The following highlights summarize selected variances within this segment, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from crude oil activities at EHT increased $8 million primarily due to higher loading revenues. Crude oil marine terminal volumes increased 138 MBPD.
Gross operating margin from the Midland-to-ECHO system and related business activities increased $4 million. Transportation volumes, net to our interest, increased 153 MBPD primarily due to our acquisition of the remaining 20 percent equity interest in Whitethorn Pipeline Company LLC in February of 2024.
On a combined basis, our Texas in-basin crude oil pipelines, terminals and other marketing activities reported a $23 million decrease in gross operating margin primarily due to lower average sales margins and transportation fees, partially offset by higher sales volumes. Transportation volumes, net to our interest, increased 14 MBPD.

4

Natural Gas Pipelines & Services – Gross operating margin for the Natural Gas Pipelines & Services segment was $293 million for the second quarter of 2024 compared to $238 million for the second quarter of 2023. Total natural gas transportation volumes were 18.3 trillion British thermal units per day (“TBtus/d”) in both the second quarters of 2024 and 2023. The following highlights summarize selected variances within this segment, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from the Texas Intrastate System increased $36 million primarily due to higher capacity reservation and transportation revenues, partially offset by higher operating costs. Transportation volumes decreased 294 billion British thermal units per day (“BBtus/d”).
Gross operating margin from our natural gas marketing business increased $24 million primarily due to higher average sales margins.
Permian natural gas gathering, including Delaware Basin and Midland Basin Gathering Systems, reported a combined $5 million increase in gross operating margin primarily due to an 831 BBtus/d increase in gathering volumes, partially offset by higher operating costs.
Gross operating margin from Haynesville Gathering decreased $11 million primarily due to lower transportation volumes and revenues. Transportation volumes decreased 168 BBtus/d.
Petrochemical & Refined Products Services – Gross operating margin for the Petrochemical & Refined Products Services segment was $392 million for the second quarter of 2024 compared to $383 million for the second quarter of 2023. Total segment pipeline transportation volumes were 946 MBPD in the second quarter 2024 compared to 837 MBPD in the second quarter of 2023. Total marine terminal volumes were 338 MBPD in the second quarter of 2024 compared to 283 MBPD for the second quarter of 2023. The following highlights summarize selected variances within this segment, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from our octane enhancement and related plant operations increased $14 million primarily due to higher sales volumes and revenues.
Propylene production and related activities reported a $6 million increase in gross operating margin. Our propylene production facilities reported higher propylene processing revenues and higher average sales margins that were partially offset by lower propylene sales volumes and higher operating costs. Total propylene and associated by-product production volumes were 96 MBPD, net to our interest, a 12 MBPD increase. This increase was driven by contributions from the propane dehydrogenation (“PDH”) 2 facility, which was placed in service in July 2023, and higher operating rates at our propylene splitters which experienced 57 days of downtime in the second quarter of 2023. The increases were partially offset by lower production at our PDH 1 facility which was down for 79 days during the second quarter of 2024 for planned maintenance.
Gross operating margin from our refined products pipelines and related activities decreased $8 million primarily due to lower average sales margins and lower fee-based revenues at our Beaumont terminal facility.
Capital Expenditures. Total capital spending in the second quarter of 2024 was $1.3 billion, which included $1.0 billion for growth capital projects and $245 million of sustaining capital expenditures. For 2024, the Partnership currently expects to invest approximately $3.5 billion to $3.75 billion for growth capital projects. For 2025, we currently expect to invest approximately $3.25 billion to $3.75 billion for growth capital projects. These amounts do not include capital investments associated with our proposed deep-water offshore crude oil terminal (the Sea Port Oil Terminal, or “SPOT”), which remains subject to a final investment decision. Sustaining capital expenditures are expected to be approximately $600 million in 2024. The approximately $50 million increase in expected sustaining capital expenditures in 2024 is primarily related to higher capital costs associated with the major turnaround at the PDH 1 facility, which was completed in June 2024.
5

Non-GAAP Financial Measure. We evaluate segment performance based on the non-generally accepted accounting principle (“non-GAAP”) financial measure of gross operating margin. Gross operating margin (either in total or by individual segment) is an important performance measure of the core profitability of our operations. This measure forms the basis of our internal financial reporting and is used by our executive management in deciding how to allocate capital resources among business segments. We believe that investors benefit from having access to the same financial measures that our management uses in evaluating segment results. The GAAP financial measure most directly comparable to total segment gross operating margin is operating income. The following table presents a reconciliation of total segment gross operating margin to operating income for the periods indicated (dollars in millions):

Enterprise Products Partners L.P.
     
Gross Operating Margin – UNAUDITED
     
($ in millions)
           
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
 
Total gross operating margin (non-GAAP)
 
$
2,412
   
$
2,181
   
$
4,902
   
$
4,516
 
Adjustments to reconcile total gross operating margin to total operating
    income (addition or subtraction indicated by sign):
                               
   Depreciation, amortization and accretion expense in operating
      costs and expenses (1)
   
(581
)
   
(545
)
   
(1,163
)
   
(1,078
)
   Asset impairment charges in operating costs and expenses
   
(4
)
   
(3
)
   
(24
)
   
(16
)
   Net gains (losses) attributable to asset sales and related matters in operating costs and expenses
   
(5
)
   
2
     
(5
)
   
4
 
   General and administrative costs
   
(57
)
   
(56
)
   
(123
)
   
(113
)
Total operating income (GAAP)
 
$
1,765
   
$
1,579
   
$
3,587
   
$
3,313
 

(1)
Excludes amortization of major maintenance costs for reaction-based plants, which are a component of gross operating margin.

Total gross operating margin includes equity in the earnings of unconsolidated affiliates, but is exclusive of other income and expense transactions, income taxes, the cumulative effect of changes in accounting principles and extraordinary charges.  Total gross operating margin is presented on a 100% basis before any allocation of earnings to noncontrolling interests.

Enterprise to Expand LPG Export Capacity at EHT

In July 2024, we announced plans to move forward with the construction of a fourth refrigeration train at our Enterprise Hydrocarbon Terminal (“EHT”).  The addition of a fourth refrigeration train (“Ref 4”), which is expected to be placed into service by the end of 2026, will increase our propane and butane export capabilities by approximately 300 MBPD.  In addition to providing incremental liquefied petroleum gas (“LPG”) export capacity, Ref 4 will increase the instantaneous loading rates for propane and butane at EHT, while also making additional capacity available for propylene exports.

Enterprise Begins Initial Service on TW Products System

In March 2024, we placed into service the first phase of our Texas Western Products System (“TW Products System”) and began truck loading operations at our new Permian terminal in Gaines County, Texas.  This facility features approximately 900,000 barrels of storage for gasoline and diesel, and truck loading capacity of 10 MBPD.  Additionally, we placed into service and began truck loading operations at our Jal and Moriarty Terminals located in New Mexico during the second quarter of 2024.  We expect the Grand Junction Terminal located in Utah to be placed into service in the third quarter of 2024.

Item 9.01.  Financial Statements and Exhibits.

(d)  Exhibits.

Exhibit No.
Description
99.1
104
Cover Page Interactive Data File–the cover page interactive data file does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
6

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 hereunto duly authorized.

   
ENTERPRISE PRODUCTS PARTNERS L.P.
   
By:
Enterprise Products Holdings LLC,
   its General Partner
     
     
Date: July 30, 2024
 
By:
/s/ R. Daniel Boss
   
Name:
R. Daniel Boss
   
Title:
Executive Vice President and Chief Financial Officer of Enterprise Products Holdings LLC










7
 
Exhibit 99.1
Enterprise Reports Results for Second Quarter 2024

Houston, Texas (Tuesday, July 30, 2024) – Enterprise Products Partners L.P. (“Enterprise”) (NYSE: EPD) today announced its financial results for the three and six months ended June 30, 2024.

Enterprise reported net income attributable to common unitholders of $1.4 billion, or $0.64 per unit on a fully diluted basis, for the second quarter of 2024, a 12 percent increase compared to $1.3 billion, or $0.57 per unit on a fully diluted basis, for the second quarter of 2023.

Distributable Cash Flow (“DCF”) was $1.8 billion for the second quarter of 2024, compared to $1.7 billion for the second quarter of 2023. Distributions declared with respect to the second quarter of 2024 increased 5 percent to $0.525 per common unit, or $2.10 per common unit annualized, compared to distributions declared for the second quarter of 2023. DCF provided 1.6 times coverage of the distribution declared for the second quarter of this year, and Enterprise retained $661 million of DCF.

Enterprise repurchased approximately $40 million of its common units on the open market in the second quarter of 2024. Including these purchases, the partnership has utilized 50 percent of its authorized $2.0 billion common unit buyback program.

Adjusted cash flow from operations (“Adjusted CFFO”) was $2.1 billion for the second quarter of 2024, compared to $1.9 billion for the second quarter of 2023. Adjusted CFFO was $8.4 billion for the twelve months ended June 30, 2024. Enterprise’s payout ratio, comprised of distributions to common unitholders and partnership common unit buybacks, for the twelve months ended June 30, 2024, was 55 percent of Adjusted CFFO.

Total capital investments were $1.3 billion in the second quarter of 2024, which included $1.0 billion for growth capital projects and $245 million of sustaining capital expenditures. Organic growth capital investments are expected to be in the range of $3.5 billion to $3.75 billion in 2024 and $3.25 billion to $3.75 billion in 2025. Sustaining capital expenditures are expected to be approximately $600 million in 2024. The approximately $50 million increase in expected sustaining capital expenditures for 2024 is primarily related to higher capital costs associated with the major turnaround at the PDH 1 facility, which was completed in June 2024.



Total debt principal outstanding at June 30, 2024 was $30.6 billion, including $2.3 billion of junior subordinated notes to which the debt rating agencies ascribe partial equity content. At June 30, 2024, Enterprise had consolidated liquidity of approximately $3.4 billion, comprised of available borrowing capacity under its revolving credit facilities and unrestricted cash on hand.

Conference Call to Discuss Second Quarter 2024 Earnings

Enterprise will host a conference call today to discuss second quarter 2024 earnings. The call will be webcast live beginning at 9:00 a.m. CT and may be accessed by visiting the partnership’s website at www.enterpriseproducts.com.

 Second Quarter 2024 Financial Highlights
   
Three Months Ended
June 30,
 
   
2024
   
2023
 
($ in millions, except per unit amounts)
           
Operating income (1)
 
$
1,765
   
$
1,579
 
Net income (1) (2)  
 
$
1,422
   
$
1,283
 
Fully diluted earnings per common unit (2)
 
$
0.64
   
$
0.57
 
Total gross operating margin (1) (3)
 
$
2,412
   
$
2,181
 
Adjusted EBITDA (3)
 
$
2,389
   
$
2,171
 
Adjusted CFFO (3)
 
$
2,065
   
$
1,866
 
Adjusted FCF (3)
 
$
814
   
$
1,073
 
DCF (3)
 
$
1,812
   
$
1,735
 
Operational DCF (3)
 
$
1,808
   
$
1,731
 

(1)
Operating income, net income, and gross operating margin include non-cash, mark-to-market (“MTM”) gains on financial instruments used in our commodity hedging activities of $12 million for the second quarter of 2024 compared to losses of $7 million for the second quarter of 2023.
(2)
Net income for the second quarters of 2024 and 2023 includes non-cash, asset impairment charges of approximately $4 million and $3 million, respectively, with negligible impacts to fully diluted earnings per common unit for each period.
(3)
Total gross operating margin, adjusted earnings before interest, taxes, depreciation and amortization (“Adjusted EBITDA”), Adjusted CFFO, adjusted free cash flow (“Adjusted FCF”), DCF and Operational Distributable Cash Flow (“Operational DCF”) are non-generally accepted accounting principle (“non-GAAP”) financial measures that are defined and reconciled later in this press release.

2


Second Quarter 2024 Volume Highlights
 
Three Months Ended
June 30,
 
   
2024
   
2023
 
Equivalent pipeline transportation volumes (million BPD) (1)
   
12.6
     
11.9
 
NGL, crude oil, refined products & petrochemical pipeline volumes
   (million BPD)
   
7.7
     
7.1
 
Marine terminal volumes (million BPD)
   
2.2
     
1.9
 
Natural gas pipeline volumes (TBtus/d)
   
18.3
     
18.3
 
NGL fractionation volumes (MBPD)
   
1,629
     
1,376
 
Propylene plant production volumes (MBPD)
   
96
     
84
 
Fee-based natural gas processing volumes (Bcf/d)
   
6.5
     
5.7
 
Equity NGL-equivalent production volumes (MBPD)
   
217
     
173
 

(1)
Represents total NGL, crude oil, refined products and petrochemical transportation volumes plus equivalent energy volumes where 3.8 million British thermal units (“MMBtus”) of natural gas transportation volumes are equivalent to one barrel of NGLs transported.

As used in this press release, “NGL” means natural gas liquids, “LPG” means liquefied petroleum gas, “BPD” means barrels per day, “MBPD” means thousand barrels per day, “MMcf/d” means million cubic feet per day, “Bcf/d” means billion cubic feet per day, “BBtus/d” means billion British thermal units per day and “TBtus/d” means trillion British thermal units per day.

“Enterprise reported a solid second quarter in terms of both volumes and cash flow generated by our integrated midstream system,” said A. J. “Jim” Teague, co-chief executive officer of Enterprise’s general partner. “Even though the second quarter is typically our seasonally weakest quarter, the partnership handled a near record 12.6 million BPD of equivalent pipeline volumes and 2.2 million BPD of marine terminal volumes, as well as record fee-based natural gas processing, NGL pipeline and NGL fractionation volumes. Our total equivalent pipeline volumes and marine terminal volumes increased by 5 percent and 18 percent, respectively, compared to the second quarter of 2023.”

“Our investments in infrastructure to support growth in the Permian Basin were visible both volumetrically and financially in our NGL Pipeline & Services segment during the second quarter. This segment reported a 19 percent increase in gross operating margin compared to the second quarter of last year primarily attributable to four new natural gas processing plants in the Permian Basin and our 12th NGL fractionator at our Mont Belvieu area complex that began operations over the past twelve months. In addition, we benefited from improvements in natural gas processing margins compared to last year. Our Natural Gas Pipelines & Services segment reported a 23 percent increase in gross operating margin versus the same quarter in 2023 largely due to higher transportation revenues and marketing margins associated with the wider price spreads between the Waha hub and other market hubs,” said Teague.

This operating performance led to a 12 percent increase in earnings per common unit on a fully diluted basis, an 11 percent increase in adjusted cash flow from operations and a 5 percent increase in our cash distribution per unit for the second quarter of 2024, compared to the second quarter of 2023. The year 2024 will mark our 26th consecutive year of distribution growth. In addition, the partnership has $6.7 billion of fee-based growth projects under construction that provide visibility to future earnings and cash flow growth,said Teague.
3


“We completed a comprehensive turnaround of our PDH 1 plant during the second quarter. We expect this work will result in greater reliability and higher utilization rates. Since PDH 1 returned to service in late June, it has operated above its nameplate capacity. Upon completion of the PDH 1 turnaround, we elected to promptly begin the planned turnaround of PDH 2 given scheduling efficiencies and availability of manpower and equipment. We expect PDH 2 to return to service in August. I would like to thank our Mont Belvieu team and supporting service providers for their efforts on these turnarounds,” said Teague.

Review of Second Quarter 2024 Results

Total gross operating margin was $2.4 billion for the second quarter of 2024, an 11 percent increase compared to $2.2 billion for the second quarter of 2023.

NGL Pipelines & Services – Gross operating margin from the NGL Pipelines & Services segment was $1.3 billion for the second quarter of 2024 compared to $1.1 billion for the second quarter of 2023.

Gross operating margin from the natural gas processing business and related NGL marketing activities was $386 million for the second quarter of 2024, an increase of 25 percent compared to $310 million for the second quarter of 2023. Total fee-based natural gas processing volumes increased 837 MMcf/d, or 15 percent, to a record 6.5 Bcf/d in the second quarter of 2024, compared to the second quarter of 2023. Total equity NGL-equivalent production volumes were 217 MBPD and 173 MBPD in the second quarters of 2024 and 2023, respectively. The following highlights summarize selected variances within this business, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from Permian natural gas processing facilities, including the Midland and Delaware Basin assets, increased $81 million primarily attributable to the addition of four natural gas processing plants that went into service during the last twelve months. These plants contributed to higher fee-based processing volumes and higher equity NGL-equivalent volumes for the Midland and Delaware Basin assets. These assets also benefited from higher average processing margins, primarily due to the impact of hedging. Midland Basin fee-based processing volumes increased 342 MMcf/d stemming from the addition of the Poseidon and Leonidas natural gas processing trains, which were placed in service in July 2023 and late March 2024, respectively. Midland Basin equity NGL-equivalent production volumes increased 23 MBPD. Delaware Basin fee-based processing volumes increased 359 MMcf/d benefiting from the addition of the Mentone 2 and Mentone 3 processing trains, which were placed in service in October 2023 and late March 2024, respectively. Delaware Basin equity NGL-equivalent production volumes increased 3 MBPD.

4


Gross operating margin from South Texas natural gas processing facilities increased $16 million primarily due to higher average processing margins, higher fee-based processing volumes, and lower operating costs. South Texas fee-based processing volumes increased 153 MMcf/d. Equity NGL-equivalent production volumes were essentially flat.
Gross operating margin from Rockies natural gas processing facilities increased $6 million primarily due to higher fee-based processing volumes, which increased 256 MMcf/d, and higher equity NGL-equivalent volumes, which increased 9 MBPD.
Gross operating margin from NGL marketing activities decreased $34 million primarily due to lower average sales margins, partially offset by higher sales volumes.

Gross operating margin from the NGL pipelines and storage business was $701 million for the second quarter of 2024, an increase of $103 million compared to the second quarter of 2023. Total NGL pipeline transportation volumes were a record 4.3 million BPD in the second quarter of 2024, a 9 percent increase over the second quarter of 2023. Total NGL marine terminal volumes increased 15 percent, or 111 MBPD, to 876 MBPD for the second quarter of 2024, compared to the second quarter in 2023. The following highlights summarize selected variances within this business, with results for the second quarter of 2024 as compared to the second quarter of 2023:
On a combined basis, the pipelines serving the Permian and Rocky Mountain regions reported a $21 million increase in gross operating margin. This includes the Mid-America, Seminole, Shin Oak, and Chaparral NGL pipeline systems. The variance was primarily driven by a 179 MBPD, net to our interest, increase in transportation volumes and higher average transportation fees.
Eastern ethane pipelines, which include the ATEX and Aegis pipelines, reported a $21 million increase in gross operating margin largely due to higher transportation revenues. Eastern ethane pipeline volumes decreased 48 MBPD.
Gross operating margin from the Enterprise Hydrocarbons Terminal (“EHT”) increased $18 million primarily due to a 72 MBPD increase in LPG export volumes and higher average loading fees. Gross operating margin from the Morgan’s Point Ethane Export Terminal increased $4 million primarily due to a 39 MBPD increase in export volumes. Gross operating margin from the Houston Ship Channel Pipeline System increased $9 million in connection with a 139 MBPD increase in transportation volumes.
Gross operating margin from the Mont Belvieu area storage complex increased $18 million primarily due to higher storage revenues.


5


Gross operating margin from the NGL fractionation business was $238 million for the second quarter of 2024 compared to $202 million for the second quarter of 2023. Total NGL fractionation volumes increased 253 MBPD to a record 1.6 million BPD for the second quarter of 2024, compared to the second quarter of 2023. The following highlights summarize selected variances within this business, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from our Mont Belvieu area NGL fractionation complex increased $25 million primarily due to a 216 MBPD, net to our interest, increase in fractionation volumes, partially offset by higher operating costs. The increase in volume and gross operating margin was primarily due to the addition of the 12th NGL fractionator at this facility, which was placed in service in July 2023. Fractionation volumes also benefited from the acquisition of the remaining 25 percent equity interest in EF78 LLC in February 2024.

Crude Oil Pipelines & Services – Gross operating margin from the Crude Oil Pipelines & Services segment was $417 million for the second quarter of 2024 compared to $422 million for the second quarter of 2023. Gross operating margin for the second quarter of 2024 includes non-cash, MTM gains of $8 million related to hedging activities compared to non-cash, MTM losses of $7 million in the second quarter of 2023. Total crude oil pipeline transportation volumes were 2.5 million BPD in the second quarter of 2024 compared to 2.4 million BPD for the second quarter of 2023. Total crude oil marine terminal volumes were 977 MBPD this quarter, a 163 MBPD increase compared to the second quarter of 2023. The following highlights summarize selected variances within this segment, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from crude oil activities at EHT increased $8 million primarily due to higher loading revenues. Crude oil marine terminal volumes increased 138 MBPD.
Gross operating margin from the Midland-to-ECHO system and related business activities increased $4 million. Transportation volumes, net to our interest, increased 153 MBPD primarily due to our acquisition of the remaining 20 percent equity interest in Whitethorn Pipeline Company LLC in February of 2024.
On a combined basis, our Texas in-basin crude oil pipelines, terminals and other marketing activities reported a $23 million decrease in gross operating margin primarily due to lower average sales margins and transportation fees, partially offset by higher sales volumes. Transportation volumes, net to our interest, increased 14 MBPD.


6


Natural Gas Pipelines & Services – Gross operating margin for the Natural Gas Pipelines & Services segment was $293 million for the second quarter of 2024 compared to $238 million for the second quarter of 2023. Total natural gas transportation volumes were 18.3 TBtus/d in both the second quarters of 2024 and 2023. The following highlights summarize selected variances within this segment, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from the Texas Intrastate System increased $36 million primarily due to higher capacity reservation and transportation revenues, partially offset by higher operating costs. Transportation volumes decreased 294 BBtus/d.
Gross operating margin from our natural gas marketing business increased $24 million primarily due to higher average sales margins.
Permian natural gas gathering, including Delaware Basin and Midland Basin Gathering Systems, reported a combined $5 million increase in gross operating margin primarily due to an 831 BBtus/d increase in gathering volumes, partially offset by higher operating costs.
Gross operating margin from Haynesville Gathering decreased $11 million primarily due to lower transportation volumes and revenues. Transportation volumes decreased 168 BBtus/d.

Petrochemical & Refined Products Services – Gross operating margin for the Petrochemical & Refined Products Services segment was $392 million for the second quarter of 2024 compared to $383 million for the second quarter of 2023. Total segment pipeline transportation volumes were 946 MBPD in the second quarter 2024 compared to 837 MBPD in the second quarter of 2023. Total marine terminal volumes were 338 MBPD in the second quarter of 2024 compared to 283 MBPD for the second quarter of 2023. The following highlights summarize selected variances within this segment, with results for the second quarter of 2024 as compared to the second quarter of 2023:
Gross operating margin from our octane enhancement and related plant operations increased $14 million primarily due to higher sales volumes and revenues.
Propylene production and related activities reported a $6 million increase in gross operating margin. Our propylene production facilities reported higher propylene processing revenues and higher average sales margins that were partially offset by lower propylene sales volumes and higher operating costs. Total propylene and associated by-product production volumes were 96 MBPD, net to our interest, a 12 MBPD increase. This increase was driven by contributions from the PDH 2 facility, which was placed in service in July 2023, and higher operating rates at our propylene splitters which experienced 57 days of downtime in the second quarter of 2023. The increases were partially offset by lower production at our PDH 1 facility which was down for 79 days during the second quarter of 2024 for planned maintenance.
Gross operating margin from our refined products pipelines and related activities decreased $8 million primarily due to lower average sales margins and lower fee-based revenues at our Beaumont terminal facility.

7


Use of Non-GAAP Financial Measures

This press release and accompanying schedules include the non-GAAP financial measures of total gross operating margin, Adjusted CFFO, FCF, Adjusted FCF, DCF, Operational DCF and Adjusted EBITDA. The accompanying schedules provide definitions of these non-GAAP financial measures and reconciliations to their most directly comparable financial measure calculated and presented in accordance with GAAP. Our non-GAAP financial measures should not be considered as alternatives to GAAP measures such as net income, operating income, net cash flow provided by operating activities or any other measure of financial performance calculated and presented in accordance with GAAP. Our non-GAAP financial measures may not be comparable to similarly titled measures of other companies because they may not calculate such measures in the same manner as we do.

Company Information and Use of Forward-Looking Statements

Enterprise Products Partners L.P. is one of the largest publicly traded partnerships and a leading North American provider of midstream energy services to producers and consumers of natural gas, NGLs, crude oil, refined products and petrochemicals. Services include: natural gas gathering, treating, processing, transportation and storage; NGL transportation, fractionation, storage and marine terminals; crude oil gathering, transportation, storage and marine terminals; petrochemical and refined products transportation, storage and marine terminals; and a marine transportation business that operates on key U.S. inland and intracoastal waterway systems. The partnership’s assets currently include more than 50,000 miles of pipelines; over 300 million barrels of storage capacity for NGLs, crude oil, petrochemicals and refined products; and 14 billion cubic feet of natural gas storage capacity.

This press release includes forward-looking statements. Except for the historical information contained herein, the matters discussed in this press release are forward-looking statements that involve certain risks and uncertainties, such as the partnership’s expectations regarding future results, capital expenditures, project completions, liquidity and financial market conditions. These risks and uncertainties include, among other things, insufficient cash from operations, adverse market conditions, governmental regulations and other factors discussed in Enterprise’s filings with the U.S. Securities and Exchange Commission. If any of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results or outcomes may vary materially from those expected. The partnership disclaims any intention or obligation to update publicly or reverse such statements, whether as a result of new information, future events or otherwise.

Contacts:  Libby Strait, Senior Director, Investor Relations, (713) 381-4754
Rick Rainey, Vice President, Media Relations, (713) 381-3635
8

Enterprise Products Partners L.P.
 
Exhibit A
 
Condensed Statements of Consolidated Operations – UNAUDITED
     
($ in millions, except per unit amounts)
                 
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
   
For the Twelve
Months Ended
June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
 
Revenues
 
$
13,483
   
$
10,651
   
$
28,243
   
$
23,095
   
$
54,863
 
Costs and expenses:
                                       
Operating costs and expenses
   
11,762
     
9,137
     
24,736
     
19,894
     
47,859
 
General and administrative costs
   
57
     
56
     
123
     
113
     
241
 
Total costs and expenses
   
11,819
     
9,193
     
24,859
     
20,007
     
48,100
 
Equity in income of unconsolidated affiliates
   
101
     
121
     
203
     
225
     
440
 
Operating income
   
1,765
     
1,579
     
3,587
     
3,313
     
7,203
 
Other income (expense):
                                       
Interest expense
   
(332
)
   
(302
)
   
(663
)
   
(616
)
   
(1,316
)
Other, net
   
4
     
19
     
17
     
31
     
27
 
Total other expense, net
   
(328
)
   
(283
)
   
(646
)
   
(585
)
   
(1,289
)
Income before income taxes
   
1,437
     
1,296
     
2,941
     
2,728
     
5,914
 
Provision for income taxes
   
(15
)
   
(13
)
   
(36
)
   
(23
)
   
(57
)
Net income
   
1,422
     
1,283
     
2,905
     
2,705
     
5,857
 
Net income attributable to noncontrolling interests
   
(16
)
   
(29
)
   
(42
)
   
(60
)
   
(107
)
Net income attributable to preferred units
   
(1
)
   
(1
)
   
(2
)
   
(2
)
   
(3
)
Net income attributable to common unitholders
 
$
1,405
   
$
1,253
   
$
2,861
   
$
2,643
   
$
5,747
 
Per common unit data (fully diluted):
                                       
Earnings per common unit
 
$
0.64
   
$
0.57
   
$
1.30
   
$
1.20
   
$
2.62
 
Average common units outstanding (in millions)
   
2,194
     
2,196
     
2,194
     
2,195
     
2,193
 
                                         
Supplemental financial data:
                                       
Net cash flow provided by operating activities
 
$
1,574
   
$
1,902
   
$
3,685
   
$
3,485
   
$
7,769
 
Net cash flow used in investing activities
 
$
1,243
   
$
765
   
$
2,281
   
$
1,402
   
$
4,076
 
Net cash flow used in financing activities
 
$
281
   
$
1,136
   
$
1,290
   
$
2,012
   
$
3,536
 
Total debt principal outstanding at end of period
 
$
30,621
   
$
28,926
   
$
30,621
   
$
28,926
   
$
30,621
 
                                         
Non-GAAP Distributable Cash Flow (1)
 
$
1,812
   
$
1,735
   
$
3,727
   
$
3,673
   
$
7,655
 
Non-GAAP Operational Distributable Cash Flow (1)
 
$
1,808
   
$
1,731
   
$
3,750
   
$
3,646
   
$
7,642
 
Non-GAAP Adjusted EBITDA (2)
 
$
2,389
   
$
2,171
   
$
4,858
   
$
4,492
   
$
9,684
 
Non-GAAP Adjusted Cash flow from operations (3)
 
$
2,065
   
$
1,866
   
$
4,212
   
$
3,888
   
$
8,448
 
Non-GAAP Free Cash Flow (4)
 
$
323
   
$
1,109
   
$
1,366
   
$
2,017
   
$
3,605
 
Non-GAAP Adjusted Free Cash Flow (4)
 
$
814
   
$
1,073
   
$
1,893
   
$
2,420
   
$
4,284
 
Gross operating margin by segment:
                                       
NGL Pipelines & Services
 
$
1,325
   
$
1,110
   
$
2,665
   
$
2,322
   
$
5,241
 
Crude Oil Pipelines & Services
   
417
     
422
     
828
     
819
     
1,716
 
Natural Gas Pipelines & Services
   
293
     
238
     
605
     
552
     
1,130
 
Petrochemical & Refined Products Services
   
392
     
383
     
836
     
802
     
1,728
 
Total segment gross operating margin (5)
   
2,427
     
2,153
     
4,934
     
4,495
     
9,815
 
Net adjustment for shipper make-up rights (6)
   
(15
)
   
28
     
(32
)
   
21
     
(34
)
Non-GAAP total gross operating margin (7)
 
$
2,412
   
$
2,181
   
$
4,902
   
$
4,516
   
$
9,781
 

(1)
See Exhibit F for reconciliation to GAAP net cash flow provided by operating activities.
(2)
See Exhibit G for reconciliation to GAAP net cash flow provided by operating activities.
(3)
See Exhibit E for reconciliation to GAAP net cash flow provided by operating activities.
(4)
See Exhibit D for reconciliation to GAAP net cash flow provided by operating activities.
(5)
Within the context of this table, total segment gross operating margin represents a subtotal and corresponds to measures similarly titled within the financial statement footnotes provided in our quarterly and annual filings with the U.S. Securities and Exchange Commission (“SEC”).
(6)
Gross operating margin by segment for NGL Pipelines & Services and Crude Oil Pipelines & Services reflects adjustments for non-refundable deferred transportation revenues relating to the make-up rights of committed shippers on certain major pipeline projects.  These adjustments are included in managements’ evaluation of segment results.  However, these adjustments are excluded from non-GAAP total gross operating margin in compliance with guidance from the SEC.
(7)
See Exhibit H for reconciliation to GAAP total operating income.
9


Enterprise Products Partners L.P.
 
Exhibit B
 
Selected Operating Data – UNAUDITED
 
                   
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
   
For the Twelve
Months Ended
June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
 
Selected operating data: (1)
                             
NGL Pipelines & Services, net:
                             
NGL pipeline transportation volumes (MBPD)
   
4,264
     
3,910
     
4,213
     
3,944
     
4,166
 
NGL marine terminal volumes (MBPD)
   
876
     
765
     
886
     
794
     
866
 
NGL fractionation volumes (MBPD)
   
1,629
     
1,376
     
1,593
     
1,373
     
1,575
 
Equity NGL-equivalent production volumes (MBPD) (2)
   
217
     
173
     
201
     
169
     
192
 
Fee-based natural gas processing volumes (MMcf/d) (3,4)
   
6,514
     
5,677
     
6,438
     
5,609
     
6,261
 
Crude Oil Pipelines & Services, net:
                                       
Crude oil pipeline transportation volumes (MBPD)
   
2,528
     
2,366
     
2,454
     
2,332
     
2,520
 
Crude oil marine terminal volumes (MBPD)
   
977
     
814
     
1,035
     
829
     
1,014
 
Natural Gas Pipelines & Services, net:
                                       
Natural gas pipeline transportation volumes (BBtus/d) (5)
   
18,344
     
18,264
     
18,479
     
18,145
     
18,531
 
Petrochemical & Refined Products Services, net:
                                       
Propylene production volumes (MBPD)
   
96
     
84
     
97
     
90
     
100
 
Butane isomerization volumes (MBPD)
   
119
     
120
     
118
     
109
     
116
 
Standalone DIB processing volumes (MBPD)
   
211
     
174
     
204
     
163
     
196
 
Octane enhancement and related plant sales volumes (MBPD) (6)
   
39
     
37
     
37
     
31
     
39
 
Pipeline transportation volumes, primarily refined products
and petrochemicals (MBPD)
   
946
     
837
     
903
     
812
     
893
 
Refined products and petrochemicals marine terminal volumes (MBPD) (7)
   
338
     
283
     
334
     
303
     
336
 
Total, net:
                                       
NGL, crude oil, petrochemical and refined products
pipeline transportation volumes (MBPD)
   
7,738
     
7,113
     
7,570
     
7,088
     
7,579
 
Natural gas pipeline transportation volumes (BBtus/d)
   
18,344
     
18,264
     
18,479
     
18,145
     
18,531
 
Equivalent pipeline transportation volumes (MBPD) (8)
   
12,565
     
11,919
     
12,433
     
11,863
     
12,456
 
NGL, crude oil, refined products and petrochemical
marine terminal volumes (MBPD)
   
2,191
     
1,862
     
2,255
     
1,926
     
2,216
 

(1)
Operating rates are reported on a net basis, which take into account our ownership interests in certain joint ventures and include volumes for newly constructed assets from the related in-service dates and for recently purchased assets from the related acquisition dates.
(2)
Primarily represents the NGL and condensate volumes we earn and take title to in connection with our processing activities.  The total equity NGL-equivalent production volumes also include residue natural gas volumes from our natural gas processing business.
(3)
Volumes reported correspond to the revenue streams earned by our gas plants. “MMcf/d” means million cubic feet per day.
(4)
Fee-based natural gas processing volumes are measured at either the wellhead or plant inlet in MMcf/d.
(5)
“BBtus/d” means billion British thermal units per day.
(6)
Reflects aggregate sales volumes for our octane enhancement and isobutane dehydrogenation (“iBDH”) facilities located at our Mont Belvieu area complex and our high-purity isobutylene production facility located adjacent to the Houston Ship Channel.
(7)
In addition to exports of refined products, these amounts include loading volumes at our ethylene export terminal.
(8)
Represents total NGL, crude oil, refined products and petrochemical transportation volumes plus equivalent energy volumes where 3.8 million British thermal units (“MMBtus”) of natural gas transportation volumes are equivalent to one barrel of NGLs transported.

10


Enterprise Products Partners L.P.
 
Exhibit C
Selected Commodity Price Information – UNAUDITED
   

                                       
Polymer
   
Refinery
 
   
Natural
               
Normal
         
Natural
   
Grade
   
Grade
 
   
Gas,
   
Ethane,
   
Propane,
   
Butane,
   
Isobutane,
   
Gasoline,
   
Propylene,
   
Propylene,
 
   
$/MMBtu (1)
   
$/gallon (2)
   
$/gallon (2)
   
$/gallon (2)
   
$/gallon (2)
   
$/gallon (2)
   
$/pound (3)
   
$/pound (3)
 
2023 by quarter:
                                               
First Quarter
 
$
3.44
   
$
0.25
   
$
0.82
   
$
1.11
   
$
1.16
   
$
1.62
   
$
0.50
   
$
0.22
 
Second Quarter
 
$
2.09
   
$
0.21
   
$
0.67
   
$
0.78
   
$
0.84
   
$
1.44
   
$
0.40
   
$
0.21
 
Third Quarter
 
$
2.54
   
$
0.30
   
$
0.68
   
$
0.83
   
$
0.94
   
$
1.55
   
$
0.36
   
$
0.15
 
Fourth Quarter
 
$
2.88
   
$
0.23
   
$
0.67
   
$
0.91
   
$
1.07
   
$
1.48
   
$
0.46
   
$
0.17
 
2023 Averages
 
$
2.74
   
$
0.25
   
$
0.71
   
$
0.91
   
$
1.00
   
$
1.52
   
$
0.43
   
$
0.19
 
                                                                 
2024 by quarter:
                                                               
First Quarter
 
$
2.25
   
$
0.19
   
$
0.84
   
$
1.03
   
$
1.14
   
$
1.54
   
$
0.55
   
$
0.18
 
Second Quarter
 
$
1.89
   
$
0.19
   
$
0.75
   
$
0.90
   
$
1.26
   
$
1.55
   
$
0.47
   
$
0.21
 
2024 Averages
 
$
2.07
   
$
0.19
   
$
0.80
   
$
0.97
   
$
1.20
   
$
1.55
   
$
0.51
   
$
0.20
 

(1)
Natural gas prices are based on Henry-Hub Inside FERC commercial index prices as reported by Platts, which is a division of S&P Global, Inc.
(2)
NGL prices for ethane, propane, normal butane, isobutane and natural gasoline are based on Mont Belvieu Non-TET commercial index prices as reported by Oil Price Information Service, which is a division of Dow Jones.
(3)
Polymer grade propylene prices represent average contract pricing for such product as reported by IHS Markit ("IHS”), which is a division of S&P Global, Inc.  Refinery grade propylene prices represent weighted-average spot prices for such product as reported by IHS.

   
WTI
   
Midland
   
Houston
   
LLS
 
   
Crude Oil,
   
Crude Oil,
   
Crude Oil
   
Crude Oil,
 
   
$/barrel (1)
   
$/barrel (2)
   
$/barrel (2)
   
$/barrel (3)
 
2023 by quarter:
                       
First Quarter
 
$
76.13
   
$
77.50
   
$
77.74
   
$
79.00
 
Second Quarter
 
$
73.78
   
$
74.48
   
$
74.68
   
$
75.87
 
Third Quarter
 
$
82.26
   
$
83.85
   
$
84.02
   
$
84.72
 
Fourth Quarter
 
$
78.32
   
$
79.62
   
$
79.89
   
$
80.93
 
2023 Averages
 
$
77.62
   
$
78.86
   
$
79.08
   
$
80.13
 
                                 
2024 by quarter:
                               
First Quarter
 
$
76.96
   
$
78.55
   
$
78.85
   
$
79.75
 
Second Quarter
 
$
80.57
   
$
81.73
   
$
82.33
   
$
83.60
 
2024 Averages
 
$
78.77
   
$
80.14
   
$
80.59
   
$
81.68
 

(1)
West Texas Intermediate (“WTI”) prices are based on commercial index prices at Cushing, Oklahoma as measured by the NYMEX.
(2)
Midland and Houston crude oil prices are based on commercial index prices as reported by Argus.
(3)
Light Louisiana Sweet (“LLS”) prices are based on commercial index prices as reported by Platts.

The weighted-average indicative market price for NGLs (based on prices for such products at Mont Belvieu, Texas, which is the primary industry hub for domestic NGL production) was $0.59 per gallon during the second quarter of 2024 versus $0.55 per gallon during the second quarter of 2023.  Fluctuations in our consolidated revenues and cost of sales amounts are explained in large part by changes in energy commodity prices.  An increase in our consolidated marketing revenues due to higher energy commodity sales prices may not result in an increase in gross operating margin or cash available for distribution, since our consolidated cost of sales amounts would also be expected to increase due to comparable increases in the purchase prices of the underlying energy commodities.  The same type of relationship would be true in the case of lower energy commodity sales prices and purchase costs.
11


Enterprise Products Partners L.P.
 
Exhibit D
 
Free Cash Flow and Adjusted Free Cash Flow – UNAUDITED
 
($ in millions)
           
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
 
Free Cash Flow (“FCF”) and Adjusted FCF
                       
Net cash flow provided by operating activities (GAAP)
 
$
1,574
   
$
1,902
   
$
3,685
   
$
3,485
 
Adjustments to reconcile net cash flow provided by operating activities to FCF and
   Adjusted FCF (addition or subtraction indicated by sign):
                               
   Net cash flow used in investing activities
   
(1,243
)
   
(765
)
   
(2,281
)
   
(1,402
)
   Cash contributions from noncontrolling interests
   
17
     
11
     
25
     
15
 
   Cash distributions paid to noncontrolling interests
   
(25
)
   
(39
)
   
(63
)
   
(81
)
FCF (non-GAAP)
 
$
323
   
$
1,109
   
$
1,366
   
$
2,017
 
   Net effect of changes in operating accounts, as applicable
   
491
     
(36
)
   
527
     
403
 
Adjusted FCF (non-GAAP)
 
$
814
   
$
1,073
   
$
1,893
   
$
2,420
 
                                 
                                 
   
For the Twelve Months
Ended June 30,
                 

 
2024
   
2023
                 
Net cash flow provided by operating activities (GAAP)
 
$
7,769
   
$
7,260
                 
Adjustments to reconcile net cash flow provided by operating activities to FCF and
   Adjusted FCF (addition or subtraction indicated by sign):
                               
   Net cash flow used in investing activities
   
(4,076
)
   
(2,488
)
               
   Cash contributions from noncontrolling interests
   
54
     
18
                 
   Cash distributions paid to noncontrolling interests
   
(142
)
   
(162
)
               
FCF (non-GAAP)
 
$
3,605
   
$
4,628
                 
   Net effect of changes in operating accounts, as applicable
   
679
     
675
                 
Adjusted FCF (non-GAAP)
 
$
4,284
   
$
5,303
                 

FCF is a non-GAAP measure of how much cash a business generates after accounting for capital expenditures such as plants or pipelines.  Additionally, Adjusted FCF is a non-GAAP measure of how much cash a business generates, excluding the net effect of changes in operating accounts, after accounting for capital expenditures.  We believe that FCF is important to traditional investors since it reflects the amount of cash available for reducing debt, investing in additional capital projects and/or paying distributions.  We believe that Adjusted FCF is also important to traditional investors for the same reasons as FCF, without regard for fluctuations caused by timing of when amounts earned or incurred were collected, received or paid from period to period. Since we partner with other companies to fund certain capital projects of our consolidated subsidiaries, our determination of FCF and Adjusted FCF appropriately reflect the amount of cash contributed from and distributed to noncontrolling interests.

12


Enterprise Products Partners L.P.
 
Exhibit E
 
Adjusted Cash flow from operations – UNAUDITED
 
($ in millions)
                 
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
   
For the Twelve Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
   
2023
 
Adjusted Cash flow from operations (“Adjusted CFFO”)
                                   
Net cash flow provided by operating activities (GAAP)
 
$
1,574
   
$
1,902
   
$
3,685
   
$
3,485
   
$
7,769
   
$
7,260
 
Adjustments to reconcile net cash flow provided by operating activities to
Adjusted Cash flow from operations (addition or subtraction indicated by sign):
                                               
  Net effect of changes in operating accounts, as applicable
   
491
     
(36
)
   
527
     
403
     
679
     
675
 
Adjusted CFFO (non-GAAP)
 
$
2,065
   
$
1,866
   
$
4,212
   
$
3,888
   
$
8,448
   
$
7,935
 

Adjusted CFFO is a non-GAAP measure that represents net cash flow provided by operating activities before the net effect of changes in operating accounts. We believe that it is important to consider this non-GAAP measure as it can often be a better way to measure the amount of cash generated from our operations that can be used to fund our capital investments or return value to our investors through cash distributions and buybacks, without regard for fluctuations caused by timing of when amounts earned or incurred were collected, received or paid from period to period.

13


Enterprise Products Partners L.P.
 
Exhibit F
 
Distributable Cash Flow and Operational Distributable Cash Flow – UNAUDITED
 
($ in millions)
                 
               
For the Twelve
Months Ended
June 30,
 
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
 
Distributable Cash Flow (“DCF”) and Operational DCF
                             
Net income attributable to common unitholders (GAAP)
 
$
1,405
   
$
1,253
   
$
2,861
   
$
2,643
   
$
5,747
 
Adjustments to net income attributable to common
    unitholders to derive DCF (addition or subtraction indicated by sign):
                                       
   Depreciation, amortization and accretion expenses
   
611
     
576
     
1,227
     
1,143
     
2,427
 
   Cash distributions received from unconsolidated affiliates
   
131
     
128
     
243
     
247
     
484
 
   Equity in income of unconsolidated affiliates
   
(101
)
   
(121
)
   
(203
)
   
(225
)
   
(440
)
   Asset impairment charges
   
4
     
3
     
24
     
16
     
40
 
   Change in fair market value of derivative instruments
   
(12
)
   
7
     
(8
)
   
10
     
15
 
   Deferred income tax expense (benefit)
   
5
     
(11
)
   
14
     
(8
)
   
34
 
   Sustaining capital expenditures (1)
   
(245
)
   
(101
)
   
(425
)
   
(185
)
   
(653
)
   Other, net
   
10
     
(3
)
   
17
     
5
     
(12
)
Operational DCF (non-GAAP)
   
1,808
     
1,731
     
3,750
     
3,646
     
7,642
 
   Proceeds from asset sales and other matters
   
4
     
4
     
6
     
6
     
42
 
   Monetization of interest rate derivative instruments accounted
      for as cash flow hedges
   
     
     
(29
)
   
21
     
(29
)
DCF (non-GAAP)
 
$
1,812
   
$
1,735
   
$
3,727
   
$
3,673
   
$
7,655
 
Adjustments to reconcile DCF with net cash flow provided by operating
   activities (addition or subtraction indicated by sign):
                                       
   Net effect of changes in operating accounts, as applicable
   
(491
)
   
36
     
(527
)
   
(403
)
   
(679
)
   Sustaining capital expenditures
   
245
     
101
     
425
     
185
     
653
 
   Other, net
   
8
     
30
     
60
     
30
     
140
 
Net cash flow provided by operating activities (GAAP)
 
$
1,574
   
$
1,902
   
$
3,685
   
$
3,485
   
$
7,769
 

(1)
Sustaining capital expenditures are capital expenditures (as defined by GAAP) resulting from improvements to and major renewals of existing assets.  Such expenditures serve to maintain existing operations but do not generate additional revenues.

DCF is an important non-GAAP liquidity measure for our common unitholders since it serves as an indicator of our success in providing a cash return on investment.  Specifically, this liquidity measure indicates to investors whether or not we are generating cash flows at a level that can sustain or support an increase in our quarterly cash distributions.  DCF is also a quantitative standard used by the investment community with respect to publicly traded partnerships because the value of a partnership unit is, in part, measured by its yield, which is based on the amount of cash distributions a partnership can pay to a common unitholder.

Operational DCF, which is defined as DCF excluding the impact of proceeds from asset sales and other matters and monetization of interest rate derivative instruments, is a supplemental non-GAAP liquidity measure that quantifies the portion of cash available for distribution to common unitholders that was generated from our normal operations.  We believe that it is important to consider this non-GAAP measure as it provides an enhanced perspective of our assets’ ability to generate cash flows without regard for certain items that do not reflect our core operations.

The GAAP measure most directly comparable to DCF and Operational DCF is net cash flow provided by operating activities.








14


Enterprise Products Partners L.P.
 
Exhibit G
 
Adjusted EBITDA - UNAUDITED
     
($ in millions)
                 
               
For the Twelve
Months Ended
June 30,
 
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
 
Net income (GAAP)
 
$
1,422
   
$
1,283
   
$
2,905
   
$
2,705
   
$
5,857
 
Adjustments to net income to derive Adjusted EBITDA
   (addition or subtraction indicated by sign):
                                       
   Depreciation, amortization and accretion in costs and expenses (1)
   
593
     
558
     
1,193
     
1,104
     
2,356
 
   Interest expense, including related amortization
   
332
     
302
     
663
     
616
     
1,316
 
   Cash distributions received from unconsolidated affiliates
   
131
     
128
     
243
     
247
     
484
 
   Equity in income of unconsolidated affiliates
   
(101
)
   
(121
)
   
(203
)
   
(225
)
   
(440
)
   Asset impairment charges
   
4
     
3
     
24
     
16
     
40
 
   Provision for income taxes
   
15
     
13
     
36
     
23
     
57
 
   Change in fair market value of commodity derivative instruments
   
(12
)
   
7
     
(8
)
   
10
     
15
 
   Other, net
   
5
     
(2
)
   
5
     
(4
)
   
(1
)
Adjusted EBITDA (non-GAAP)
   
2,389
     
2,171
     
4,858
     
4,492
     
9,684
 
Adjustments to reconcile Adjusted EBITDA to net cash flow provided by
    operating activities (addition or subtraction indicated by sign):
                                       
   Interest expense, including related amortization
   
(332
)
   
(302
)
   
(663
)
   
(616
)
   
(1,316
)
   Deferred income tax expense (benefit)
   
5
     
(11
)
   
14
     
(8
)
   
34
 
   Provision for income taxes
   
(15
)
   
(13
)
   
(36
)
   
(23
)
   
(57
)
   Net effect of changes in operating accounts, as applicable
   
(491
)
   
36
     
(527
)
   
(403
)
   
(679
)
   Other, net
   
18
     
21
     
39
     
43
     
103
 
Net cash flow provided by operating activities (GAAP)
 
$
1,574
   
$
1,902
   
$
3,685
   
$
3,485
   
$
7,769
 

(1)
Excludes amortization of major maintenance costs for reaction-based plants, which are a component of Adjusted EBITDA.

Adjusted EBITDA is commonly used as a supplemental financial measure by our management and external users of our financial statements, such as investors, commercial banks, research analysts and rating agencies, to assess the financial performance of our assets without regard to financing methods, capital structures or historical cost basis; the ability of our assets to generate cash sufficient to pay interest and support our indebtedness; and the viability of projects and the overall rates of return on alternative investment opportunities.

Since Adjusted EBITDA excludes some, but not all, items that affect net income or loss and because these measures may vary among other companies, the Adjusted EBITDA data presented in this press release may not be comparable to similarly titled measures of other companies.  The GAAP measure most directly comparable to Adjusted EBITDA is net cash flow provided by operating activities.













15


Enterprise Products Partners L.P.
 
Exhibit H
 
Gross Operating Margin – UNAUDITED
     
($ in millions)
                 
               
For the Twelve
Months Ended
June 30,
 
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
 
Total gross operating margin (non-GAAP)
 
$
2,412
   
$
2,181
   
$
4,902
   
$
4,516
   
$
9,781
 
Adjustments to reconcile total gross operating margin to total operating
    income (addition or subtraction indicated by sign):
                                       
   Depreciation, amortization and accretion expense in operating
      costs and expenses (1)
   
(581
)
   
(545
)
   
(1,163
)
   
(1,078
)
   
(2,300
)
   Asset impairment charges in operating costs and expenses
   
(4
)
   
(3
)
   
(24
)
   
(16
)
   
(38
)
   Net gains (losses) attributable to asset sales and related matters in operating
      costs and expenses
   
(5
)
   
2
     
(5
)
   
4
     
1
 
   General and administrative costs
   
(57
)
   
(56
)
   
(123
)
   
(113
)
   
(241
)
Total operating income (GAAP)
 
$
1,765
   
$
1,579
   
$
3,587
   
$
3,313
   
$
7,203
 

(1)
Excludes amortization of major maintenance costs for reaction-based plants, which are a component of gross operating margin.

We evaluate segment performance based on our financial measure of gross operating margin.  Gross operating margin is an important performance measure of the core profitability of our operations and forms the basis of our internal financial reporting.  We believe that investors benefit from having access to the same financial measures that our management uses in evaluating segment results. 

The term “total gross operating margin” represents GAAP operating income exclusive of (i) depreciation, amortization and accretion expenses (excluding amortization of major maintenance costs for reaction-based plants), (ii) impairment charges, (iii) gains and losses attributable to asset sales and related matters, and (iv) general and administrative costs.  Total gross operating margin includes equity in the earnings of unconsolidated affiliates, but is exclusive of other income and expense transactions, income taxes, the cumulative effect of changes in accounting principles and extraordinary charges.  Total gross operating margin is presented on a 100 percent basis before any allocation of earnings to noncontrolling interests.  The GAAP financial measure most directly comparable to total gross operating margin is operating income.

Total gross operating margin excludes amounts attributable to shipper make-up rights as described in footnote (6) to Exhibit A of this press release.
















16



Enterprise Products Partners L.P.
 
Exhibit I
 
Other Information – UNAUDITED
     
($ in millions)
                 
               
For the Twelve
Months Ended
June 30,
 
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
 
Capital investments:
                             
Capital expenditures
 
$
1,264
   
$
780
   
$
2,311
   
$
1,433
   
$
4,144
 
Investments in unconsolidated affiliates
   
     
     
     
     
2
 
Other investing activities
   
7
     
4
     
15
     
5
     
23
 
Total capital investments
 
$
1,271
   
$
784
   
$
2,326
   
$
1,438
   
$
4,169
 

The following table summarizes the non-cash mark-to-market gains (losses) for the periods indicated:
                   
   
For the Three Months
Ended June 30,
   
For the Six Months
Ended June 30,
   
For the Twelve
Months Ended
June 30,
 
   
2024
   
2023
   
2024
   
2023
   
2024
 
Mark-to-market gains (losses) in gross operating margin:
                             
NGL Pipelines & Services
 
$
   
$
(5
)
 
$
(7
)
 
$
(19
)
 
$
(13
)
Crude Oil Pipelines & Services
   
8
     
(7
)
   
12
     
6
     
1
 
Natural Gas Pipelines & Services
   
3
     
4
     
1
     
2
     
(2
)
Petrochemical & Refined Products Services
   
1
     
1
     
2
     
1
     
(1
)
Total mark-to-market impact on gross operating margin
 
$
12
   
$
(7
)
 
$
8
   
$
(10
)
 
$
(15
)











17